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200-117
T R A N S M I T T A LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – CRU DATE: 12/19/2023 Transmitted: North Slope, Colville River Unit Colville CD1-01A 50-103-20299-01 212099_CD1-01A_PERF_23Jul22 212099_CD1-01A_WFL_23May2022 CD1-04 50-103-20346-00 200117_CD1-04_PLUG_27Aug2022 CD1-33 50-103-20357-00 222105_CD1-33_Puncher_21Sep2022 CD1-48A 50-103-20592-01 212004_CD1-48A_LDL_28Jul2022 CD2-02 50-103-20513-00 205109_CD2-02_LDL_11Oct2022 205109_CD2-02_LDL_12Jul2022 205109_CD2-02_Patch_07Nov2022 205109_CD2-02_PLUG_23Aug2022 CD2-15 50-103-20386-00 201159_CD2-15_LDL_06Oct23 CD2-310 50-103-20826-00 220028_CD2-310_DHSIT_10Aug2022 220028_CD2-310_USIT_25Apr2022 CD2-404 50-103-20530-00 206054_CD2-404_Patch_30Dec2021 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38291 T38292 T38293 T38294 T38295 T39296 T38297 T38734 200-212 CD1-04 50-103-20346-00 200117_CD1-04_PLUG_27Aug2022 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:54:09 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-02-24_22076_CRU_CD1-04_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 22076 CRU CD1-04 50-103-20346-00 Caliper Survey w/ Log Data 24-Feb-23 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 ______________________________ ______________________________________ 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 From:Smith, Travis T To:Loepp, Victoria T (OGC) Cc:Earhart, Will C Subject:CRU CD1-04 (PTD#200-117) High IA Pressure Date:Thursday, November 4, 2021 5:06:34 PM Attachments:CD1-04.pdf CD1-04 90-day TIO.pdf Victoria— CRU producer well CD1-04 (PTD#200-117) has exhibited elevated IA pressure in excess of 2000 psi. The well is currently shut-in awaiting intervention work to address the problem. The IA pressure reached approximately 2,100 psi but has been bled back down below DNE. The production casing is 7” 26# L80 with a burst rating of 7240 psi. Our plan is to troubleshoot the issue with slickline and repair if possible. A 90-day TIO and well schematic are attached. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com Annular Communication Surveillance 6-Aug-2021Well Name:CD1-04 Start Date:6-Aug-2021 4-Nov-2021Days:90 End Date:4-Nov-2021 50 60 70 80 90 100 110 120 130 140 150 0 500 1000 1500 2000 2500 6-Aug-219-Aug-2112-Aug-2115-Aug-2118-Aug-2121-Aug-2124-Aug-2127-Aug-2130-Aug-212-Sep-215-Sep-218-Sep-2111-Sep-2114-Sep-2117-Sep-2120-Sep-2123-Sep-2126-Sep-2129-Sep-212-Oct-215-Oct-218-Oct-2111-Oct-2114-Oct-2117-Oct-2120-Oct-2123-Oct-2126-Oct-2129-Oct-211-Nov-214-Nov-21Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 500 1000 1500 2000 2500 3000 6-Aug-21Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 9,157.0 7/2/2008 CD1-04 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Subsidence Drift 6/26/2020 CD1-04 claytg Casing Strings Casing Description CONDUCTOR Insulated 42" OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 36.3 Set Depth (ftKB) 2,727.3 Set Depth (TVD) … 2,376.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC-MOD Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.7 Set Depth (ftKB) 9,444.9 Set Depth (TVD) … 6,880.8 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description OPEN HOLE OD (in) 6 1/8 ID (in) Top (ftKB) 9,444.8 Set Depth (ftKB) 13,977.0 Set Depth (TVD) … 6,897.1 Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 32.6 Set Depth (ft… 9,082.6 Set Depth (TVD) (… 6,785.8 Wt (lb/ft) Grade Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.6 32.6 0.00 HANGER FMC TUBING HANGER 4.500 1,796.2 1,697.1 34.37 NIPPLE CAMCO BAL-O NIPPLE 3.812 8,939.8 6,707.9 53.36 NIPPLE HES "X" NIPPLE 3.813 8,994.0 6,739.3 55.84 PACKER BAKER S-3 PACKER 3.875 9,070.5 6,779.9 60.28 NIPPLE HES "XN" NIPPLE 3.725 9,081.4 6,785.2 61.18 WLEG BAKER WIRELINE ENTRY GUIDE 4.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 1,796.2 1,697.2 34.37 WRDP 4.5" WRDP ON 3.812" DB-6 LOCK / OAL=104.5" 6/25/2020 2.125 HRS-64 9,069.0 6,779.2 60.16 FISH 2.31"x7" JET NOZZLE - SITTING ON TOP OF PXN PLUG BODY 9/14/2009 0.000 9,070.5 6,779.9 60.28 PLUG PXN PLUG BODY STILL SITTING IN NIPPLE w/JET NOZZLE ON TOP OF PLUG BODY 8/11/2009 0.000 9,161.0 6,819.6 67.41 PLUG BAKER 3" IBP w/1.75" FISHING NECK 8/1/2008 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,041.0 9,056.0 6,764.8 6,772.6 8/4/2008 6.0 IPERF 2 7/8" PJ Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 4,176.1 3,387.6 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 7/31/2008 2 6,758.5 5,202.7 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 9/16/2008 3 8,878.4 6,670.2 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/21/2001 Notes: General & Safety End Date Annotation 9/7/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 CD1-04, 6/27/2020 5:18:56 AM Vertical schematic (actual) OPEN HOLE; 9,444.8-13,977.0 PRODUCTION; 35.7-9,444.8 PLUG; 9,161.0 WLEG; 9,081.4 PLUG; 9,070.5 NIPPLE; 9,070.5 FISH; 9,069.0 IPERF; 9,041.0-9,056.0 PACKER; 8,994.0 NIPPLE; 8,939.8 GAS LIFT; 8,878.4 GAS LIFT; 6,758.5 GAS LIFT; 4,176.1 SURFACE; 36.3-2,727.3 WRDP; 1,796.2 NIPPLE; 1,796.2 CONDUCTOR Insulated 42"; 36.0-114.0 HANGER; 32.6 WNS PROD KB-Grd (ft) 42.61 Rig Release Date 11/8/2000 CD1-04 ... TD Act Btm (ftKB) 13,977.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032034600 Wellbore Status PROD Max Angle & MD Incl (°) 91.37 MD (ftKB) 11,481.00 WELLNAME WELLBORECD1-04 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP TATE OF ALASKA ALASKA OIL AN S CONSERVATION COMMISSION i REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other Scale Inhibition Alter Casing P Tubing Treatment , g �"" g � "` F�rforate New Pool r Waive r Time Extens "- Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r • 200 - 117 3. Address: 6. API Number: Stratigraphic I— Service j-" P. O. Box 100360, Anchorage, Alaska 99510 50 - 103 - 20346 - ® p 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25557 L;3S-8 f 265* 3 Il \ii - CD1 - 04 9. Field /Pool(s): Colville River Field / Alpine Oil Pool N AN --4 Oi i l'eRrk 10. Present Well Condition Summary: Total Depth measured 13977 feet Plugs (measured) 9071', 9161' true vertical 6897 feet Junk (measured) 9069' Effective Depth measured 9140 feet Packer (measured) 8994 true vertical 6811 feet (true vertucal) 6739 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 2691 9.625 2727 2377 PRODUCTION 9409 7 9445 6881 R ECEIVEn Perforation depth: Measured depth: 9041' - 9056' NOV True Vertical Depth: 6765' - 6773' 0 8 fa Alaka Oil & 685 C ons. Cori Tubing (size, grade, MD, and TVD) 4.5, L -80, 9083 MD, 6786 TVD 1iniSS10111 �f~tCf3C3Pirgo Packers & SSSV (type, MD, and TVD) PACKER - BAKER S - PACKER @ 8994 MD and 6739 TVD NIPPLE - CAMCO BAL -O NIPPLE @ 1796 MD and 1697 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 9041' -9056' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 296 923 2112 -- 253 Subsequent to operation 165 232 604 -- 569 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development Io - Service r Stratigraphic r 15. Well Status after work: , Oil f Gas r VVDSPL I Daily Report of Well Operations XXX GSTOR r WINJ r WAG E GINJ V SUSP r SPLUG E 16. 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 Mike Dammeyer (7a. 265 -6548 Printed Name Mike Dammeyer Title Senior Production Engineer Signature Phone: 265-6548 Date 1-- t o /f/i Rf3DMS Nov o 9 /7q/r Form 10 -404 Revised 10/2010 i ► ,i� Submit Original Only �� IONS NS ! CD1 -04 ConoCoPhiiil tl ps -w A Well Attributes Max Angle & MD TD • ' 2 Wellborn APUUWI IF Id Name Well Status Intl (°) IMO (ftKB) Act Ban (ftKB) 501032034600 ALPINE IPROD 9137 11,481.00 13,9770 • c�41r V "" , Comment H2S (ppm) Date Annotation End Date , KB - Grd (ft) Rig Release Date ty�1S,gatw.,rGpT - 41{, 1 V2517010 I SSSV. WRDP I _ - Last W0_ 42.61 11/8/2000 "' ' "" ` "' . SchrMt6 AcauaI Annotation Depth (ftKB) End Date Annotation Last Mod ...End Date Last Tag_ 9,157.0_ 7/2/2008 Rev Reason- FORMAT UPDATE 9 0 J Imosbor 9/7/2010 Casing Strings ' ". Casing Description String 0... String ID... Top (ftKB Set Depth Set Depth TVD Siring Wt... String Top Thrd HANGER, 33 � • "• `. '.- 9 P ron 9 9 P 1 f ( - -- P (TVD)... 9 9 ... 9 P CONDUCTOR 16 15.062 360 114.0 114.0 62.58 H WELDED 4INK _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (i... Set Depth (ND) ... String WI... Siring - -- String Top Thrd SURFACE 95/8 8.697 36.3 2,727.3 2,376.9 36.00 J - 55 BTC - MOD ' Casing Description String 0... String ID... Top (fNCB) Set Depth (f..- Set Depth ( -,- String Wt - -- String . -- String Top Thrd ' PRODUCTION 7 6 151 35.7 9 8 _ 6 26 L - BTCM - - Casing Description String 0... String ID Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String - -- String Top Thrd OPEN HOLE 6 1/8 6.125 9,444.0 73 977.0 6,897.1 Tubing Strings Tubing Description String 0... String ID Top (ftKB) Set Depth (f Set Depth (TVD) . String Wt. IStr ng String Top Thrd TUBING 4 1/2 I_ 3 958 I 32.6 I 9,082.6 I_ 6,785 8 I IBTM Completion Details Top Depth CONDUO ` -), (TVD) Top Intl Nomi... Top (MB) (91(8) 1 ") Item Description Comment ID (in) ^" 32.6 32.6 -0.69 HANGER FMC TUBING HANGER 4.500 I 1,7962 1 34.37 NIPPLE CAMCO BAL -O NIPPLE - -- 3.812 NIPPLE, 1,796 - _ . , '.- 8,939.8 6,7 07.5 52.83 NIPPLE HES "X" NIPPLE 3.813 8,994.0 6,739.3 55.84 PACKER BAKER S -3 PACKER 3.875 9,070.5 6,779.7 60.36 NIPPLE HES "XN" NIPPLE 3.725 V I M , °- ,— - -- --- -� - - -- --- -_ - -- �,. 9,081.4 6,7852 611 .22 WLEG BAKER WIRELINE ENTRY GUIDE 4.500 _Ober In Hole (Wireline retrievabie_plugs, valves,_ pugps, fish, etc.) T Top Depth I, ,, (T1/c! Top (Hirai (ftKB) D) Top (•) In ()ascription Comment Run Date ID (in) 9,069 6,778.9 60.24 FISH 2.31 "xT JET NOZZLE - SITTING ON TOP OF PXN PLUG 9/14/2069 0.000 BODY SURFACE, 36 - 9,071 6,779.760.36 PLUG PXN PLUG BODY STILL SITTING IN NIPPLE w /JET 8/11 /2009 0.000 NOZZLE ON TOP OF PLUG BODY µ 9,161 6,819.6 67.41 PLUG BAKER 3" IBP w/1.75" FISHING NECK 8/1/2008 0.000 GAS LIFT._ 11 Perforations & Slots 4,176 .... Shot I Top (TVD) Mtn (TVD) Dens Top (ftK8) Bon (ftKB) (RKB) (RKB) Zone Date (oh. -- Type Comment 9,041 9,056 6,764.5 6,772.6 KUPC, CD1 -04 8/4/2008 6.0 IPERF 2 7/8" PJ Notes: General 8 Safety • End Date Annotation GAS LIFT 9/7/2010 [ NOTE - VIEW SCHEMATIC w /Alaska Schematic9 - 0 6159 -' GASLIFT _.. 8,878 '. NIPPLE, 8,940 _- : - -- PACKER, 8,994 - -- IPERF,_' j 9,041 -9,056 !;- FISH, 9,069 � , NIPPLE, 9 -� PLUG,9,07 ` AC .V - WLEG, 9,081— a j &. .. ,.. .,, -. - - __T-- ._ ..._ -,r_ Mandrel Details e,,.l: ' .. ,. Top Depth Top (TVD) Inc! OD Valve Latch SI. TRO Run Stn Top (ftKB (ftKB) ( ") Make Model 5n) Sery Type Type (in) (psi) Run Dab Cam... 1 4,176.1 3,387.6 44.96 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 7/31/2008 2 6,758.5 5,202.8 46.17 CAMCO KBG2 1 GAS LIFT OV BK 0.250 0.0 9/16/2008 3 8,878.4 6,670.1 51.10 CAMCO KBG2 1 GAS LIFT DMY BK 0.000 0.0 3/21/2001 PRODUCTION. 369,445 OPEN HOLE, 9,444-13,977 �_ TD, 13.977 - ...... • • Scale Inhibition Treatment CD1 -04, 10/25/2011: Scale Inhibition Treatment: Initial pressure TBG /IA /OA- 1600/350/900; Facility pumped 50 bbls SW preflush; LRS pumped 2.8 bbls WAW5206 (118 gal) at 0.3 bpm and facility pumped 54 bbls SW, 1440/350/900; LRS pumped 28.8 bbls SCW3001WC (1210 gal) at 0.4 bpm and facility pumped 334 bbls of SW, 1500/325/850; LRS pumped 2.8 bbls WAW5206 (118gal) at 0.35 bpm and facility pumped 54 bbls SW, 1500/325/850; facility pumped 1 80 1 bbls of SW over - displacement. • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnlcen 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: CDl-04 Run Date: 8/10/2009 November 10, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1-04 Digital Data in LAS format, Digital Log Image file 1 CD Roan 50-103-20346-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNIivG AND RETL~~iII~TG A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Att17: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99S 18 Office: 907-273-327 Fax: 907-273-3535 rafael. bai-reto@hal libtirton.com Date: 2~U~ ~~ ~ ~ 1~~~ ` / ~ ~ ~ Signed: ~`' / /~t~' Tc Change of Scope of Approved 10-403 Notification Page 1 of 1 ~ • Maunder, Thomas E (DOA) From: Barreda, Brian B [Brian.B.Barreda@conocophillips.com] Sent: Tuesday, September 22, 2009 1:39 PM To: Maunder, Thomas E (DOA) Subjeat: RE: CD1-04 (200-117) Tom, The decision was made to have CT perform a FCO to remove ~ 9' of sand/fili from the tbg given that we ~ere wanting to pull the XN plug. We v~ere not able to pu91 the plug with CT after the the FCO. We have kept the well Si given our current gas handling restraints. We will start to flow the well when our gas handling capacity increases during the winter. Tom, yaur records are correct. There should be oniy 11 days o# allocated production from January 2008 - Ju1y 2009. Sorry for the delay. i was in training all of last week. Brian f, _ ;;.;'y From: Maunder, Thomas E (QOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, September 14, 2009 3:35 PM To; Barreda, Brian B Subject: CD1-04 (2~0-117) Brian, I am reviewing the 404 submitted fo~ the recent stim tube "perforation" and cleanout on this well. It is indicated that bailing work was suspended on 8/21 and the well placed in production. Is there a plan to do additional work? Also, our production records only show this well to have been produced 19 days since January 2008 - July 2009. Is that correct? Thanks in advance. Tom Maunder, PE AOGCC 9l22/2009 , '`'j;~ ~ ;.. ~ ~~... ~ ~" ~ - ~ : ~ ~ ~ ~.~ }~ :~ ~~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION , ~ ,-; . ~ `%n~``.,~>~'b REPORT OF SUNDRY WELL OPERATIONS~ ~~~~;, 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate Q Other ~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development 0 Explorarory ^ 200-117 /'' 3. Address: Stratigraphic ^ S~N~~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20346-00 , 7. KB Elevation (ft): 9. Well Name and Number: RKB 56' CD1-04 ~ 8. Property Designation: 10. Field/Pool(s): ADL 25557 Colville River Field / Undefined Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 13977' feet true vertical 6897' feet Plugs (measured) 9161' Effective Depth measured 13977' feet Junk (measured) true vertical 6897' feet Casing Length Size MD ND Burst Collapse Structural CONDCUTOR 114' 16" 114' 114' SURFACE 2727' 9-5/8" 2727' 2377' PRODUCTION 9444' 7" 9444' 6881' OPEN HOLE 4533' 6.125" 13977' 6897' Perforation depth: Measured depth: 9041'-9056' true vertical depth: 6765'-6770' Tubing (size, grade, and measured depth) 4.5", L-80, 9083' Packers 8~ SSSV (type & measured depth) Baker S-3 pkr @ 8ssa~ Camco WRDP-2 SSSV @ 1796' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 9041'-9056' Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 670 3048 6849 -- 1311 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. F~cempt: 308-454 contact Brian Barreda @ 265-6036 Printed Name rian Barreda Title WNS Production Engineerd~ Signature _-_ / wn~. Phone: 265-6036 Date 1/~ l.Zd~ ~ Pre red b Sharon All -Drake 263-4612 C/ Form 10-404 Revised 04/2006 ~~ ~ ~~~ ~ `~ ~ ° ?~~~ ~~~-~ Submit Original Only ~ ~ ~~ CD1-04 Well Events Summary DATE SUMMARY 7/24/09 PULLED WRDP FROM 1796' R . ENCOUNTERED SCALE IN 4-1/2" TBG~M 9022' TO 9050' SLM. ABLE TO WORK 2.5" BAILER THROUGH. TAGGED FILL (a~ 9131' SLM, EST. 10' FILL ON CEMENT. IN PROGRESS. 7/25/09 MEASURED BHP . 9100' RKB: 4216 PSI. WORKED BROACHES IN TBG UNTIL TBG GAUGED TO 3.66" TO XN @ 9070' RKB. IN PROGRESS. 7/27/09 BROACHED SCALE FROM 8500' TO XN NIPPLE @ 9070' RKB; TBG OPEN 3.80" TO XN NIPPLE. OPEN TO 2.70" THROUGH XN NIPPLE. DRIFTED TBG WITH 3.5" DUMP BAILER, UNABLE TO WORK PAST OBSTRUCTION IN CASING Cc~ 9106' RKB. IN PROGRESS. 7/28/09 TAG D FILL AB~VE .FM NT P 1(~ A116' RKB W/ 3.0" BAILER. REGOVERED. BAILER FULL OF CEMENT SCALE AND FORMATION SAND. IN PROGRESS. 7/29/09 BRUSHED TUBING TO XN NIPPLE @ 9070' RKB. SET 3 725" PXN PLUG BODY na 9070', RKB. UNABLE TO GET CONFIRMATION W/ CHECK SET DUE TO FORMATION SAND. BAILED ~ 1/2 GALLON OF SAND FROM PLUG BODY. IN PROGRESS. 7/30/09 BAILED FORMATION SAND AND SCALE FROM PXN PLUG BODY @ 9070' RKB. SET PRONG IN PLUG BODY. WELL IS READY FOR E-LINE. 8/10/09 RIH WITH STIM TUBE (1 11/16") FIRE STIM TUBE ACROSS PERFORATED INTERVA~ AT 9044-9053'. WELL READY FOR SLICK LINE. 8/11/09 PERFORMED INJ TEST: 1 BPM (a~ 1950 PSI (5 BBL DSLI. BAILED FORMATION SAND & SCALE FROM TOP OF PXN PLUG Ca~ 9070' RKB. PULLED PRONG FROM XN PLUG (a~ 9070' RKB. IN PROGRESS. 8/12/09 BAILED SCALE & STIM TUBE DEBRIS FROM XN PLUG Ca~ 9070' RKB. ATTEMPTED PULL XN PLUG BODY FROM XN NIPPLE @ 9070' RKB WITHOUT SUCCES~r DIFFICULT SHEARING/RELEASING PULLING TOOL. IN PROGRESS. 8/13/09 BAILED TRACE AMT SCALE FROM XN PLUG @ 9070' RKB. ATTEMPTED PULL XN PLUG WITH NO SUCCESS. GAUGED TBG TO 3.855" TO BAL-O NIPPLE @ 1796' RKB. SET 3.812 WRDP-2 (S/N: HSS-125) Ca) 1796' RKB. CLOSURE TEST FAILED, IN PROGRESS. 8/14/09 PULLED 3.812 WRDP FROM BAL-O NIPPLE @ 1796' RKB. BRUSHED NIPPLE. SET 3.812 WRDP-2 Cc~ 1796' RKB (S/N: HRS-2771. CLOSURE TESTED. GOO[~, COMPLETE. 8/19/09 DRIFTED TBG TO 3.855" TO WRDP @ 1796' RKB; PULLED SAME. ATTEMPTED PULL XN PLUG BODY Ca~ 9070' RKB, SAT DOWN ~ 7' HIGH. RAN 2.5" DRIVE DOWN BAILER TO 9047' SLM, RECOVERED 1 QT FORMATION SAND. IN PROGRESS. 8/20/09 BAILED ~ 1 QUART FORMATION SAND FROM PXN PLUG BODY @ 9049' SLM. IN PROGRESS. 8/21/09 BAILED ~ 1/2 GALLON FORMATION SAND FROM 9050' SLM; NO METAL MARKS ON BAILER. JOB SUSPENDED FOR HIGHER PRIORITY. „ („~(~fl~()~~'~~t~]~, Y "~~-~'-" ~.--•--- ~ I ! Well Attributes ~ WellboreAPVUWI Fi~ ~ SG10~2034600 IAI co~omen~ . . .SSSV: WRDP . __-_Y~4~c ~ -&47aa 5r,erzu _ __ .Shcemeut Acw _ tieasr„se ~~~a al ~Annobtion 'Dapih~ftKB) Last Tao~ 9.157 0 ata I,p~~otation IEnd Date i Last WO: rtation Reason- RESET WRDP, GLV C!O ~ Set Depth ' Set Dapth (TVD) P (RKB) , (kK6) (RKB) 0.0 114.0~ 114.0 - 0 0- -- 2.727.0' ---2.376J OAI 9,444 0 6,881.0 9444.0~ 13,977.0 6,897.1 fUBING I 41/2I 3.9S8I 00'I 9083.OI 6.786.0 Other In Hole (All Jewelr~r: Tubin~ Run & Retrievable, Fis~etc.~ Top(kK6) _ Dascription ~Ganment 7J96.0 NIPPLE CAMCO BAL-0 LANDING NIPPLE 1,796.0 SSSV SSSV: WRDP CAMCO WRDP-2 SSSV (SER 4,1760 GASLIFT CAMCO/KBG-2/1/DMY/BK///CommentSTAI 6,759.0 GAS LIFT CAMCO/KBG-2/7/OV/BK/25/! Comment: STA 2 8,878.O GASLIFT CAMCO/KBG2/t/DMY/BK///CommenT.STA3 8,940A NIPPIE HES'X' NIPPLE ~ 8,994.OI PACKER BAKER'S-3'PACKER ~ ~ 9,070A~' NIPPLE HES'XN'NIPPLE 9,083.O~ WLEG BAKERWIRELINEREENTRYGUIDE 9,761.0 PWG BAKER 3" IBP w117S' FISHING NECK CD1-04 KB) ITotal Depth (fiKB) 1,4R7.00 13,977.0 d (%) IRig Release Data 7118/2000 I End Data 9/18/2008 11/72000 Change of Scope of Approved 10-403 Notification Page 1 of 1 ~ • Maunde~r, Thornas E (~QA) From: Maunder, Thomas E {p0A) Senfi: l'hursday, July Q9, 2049 12:35 P11~ T~: 'Barrsda, Brian B' Subject: RE: Cp't-Q4 (2Q0-117) - Chanc~e of Scape of Appreved 1Q-4Q3 Neti~eatican From: B~rreda, ~rian B [mailt~:Brian.S.Barr~da~c~nocflpF~+i(lip~.com] Settt; Thursday, ]uly 09, 2Q~9 11:45 AM To: Maunder, Thomas E (DQA} Subj+e~t: Chan~e of Scc~{~ of Approved 10-403 N~tification Tom, We are planning on changing the scope of an existing approved 14-4~3 to s~imulate. Do I need te~ submit for a n~w Sundry? VVhat is the prQtocai for revisions of exi~ting Sundries? I endosed the originat ~cope of work ~nd the revi~ion. The stimul~tion tool will be deploy~l via e-1ir~~ in~t~~ci 4f sii~kine #v incr~~se tie-in ~ccuracy with the existing perforatior~s. Also, w~ are p~ar~ning ~r+ cutting the #bg just abc~ve the perfaratipn to increas~ the penetr~tion of the sfiir~ulatiqn. Thanks Brian Barreda WNS Prpduction Ertgineer 2Fi3~F'i036 ~,~~~~~~' v~~ ~v ~W ~~~~ <CCQ1-Q4 S~imTube [?ee.17.2QQ8.dQC» «CD1-0~ Approvsd 1Q-403 to stirr~uiate 1~-08.pdf~> «CQ9,f14 ~fiimTu~e ~cQpe R~vision July.Q8.20Q9.doc» '7/9/20~9 i • JOB SCOPE (Revision) The Alpine C sand interval was plugged and abandoned allowing for the Kuparuk C sand intenral to be perforated in August of 2008. The Kuparuk interval has not been abfe to sustain a produc~ble rate possibly due to poor rock quality and has been shut-in since initially being brought on-line. A StimTube (solid mold of propellant) detonated by Halliburton's ETD tool is recommended to try to stimulate the well. The job will use a 9' section of 1 11/16" StimTube Tool. The perforated interval is between 9,041 - 9,056 (E-line MD). Procedure 1. MIRU.Slickline 2. Gauge tubing to WRDP @ 1796' RKB 3. RIH and pull WRDP. 4. MIRU E-line 5. Cut tbg ~ 30' RKB below packer at 9025' RKB 6. MIRU Slickline 7. ~Confirm that tbg has fallen below targeted stimulation interval 8. MIRU E-line 9. Tie - in perforations previous GR log 10. Detonate StimTube • • a d 1 r 4 t~ -~ ~._.~r ,,,,.,, ~ ~ ~ , ~ ~ k t SARAH PAL/N GOV ~1-7i)•[~ OIL AI~TD (~iA,S r~ 333 W. 7th AVENUE, SUITE 100 COI~TSER~'ATIOH COr`II-IISSIOI~T ~! ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Brian Barreda PE ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 ~ ~ ~'~~~~~ ` ~ i ~ `- ~ ~~~8 Re: Colville River Field, Undefined Kuparuk Oil Pool, CD 1-04 Sundry Number: 308-454 Dear Mr. Barreda: a~i~7 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Comnussion an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, a Cathy P. Focrster Commissioner DATED this ~ day of December, 2008 Encl. STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION - ~'~~ APPLICATION FOR SUNDRY APPROVAL.. `~ 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^/ • Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 200-117 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20346-00 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 ^ NO ^~ CD1-04 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~~rJ ~ vF?C ADL 25557 % AKL 372095 RKB 56' Colville River Field / A1~Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY ~ ~ Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13977' 6897' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2727 9-5/8" 2727' PRODUCTION 9444 7" 9444' OPEN HOLE 4533 6-1/8" 13977' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9041' - 9056' 6765' -6770' 4-1/2" L-80 9083' Packers and SSSV Type: Packers and SSSV MD (ft) Baker S-3 Packer Packer = 8994' Camco Bal-O SSSV SSSV = 1796' 13. Attachments: Description Summary of Proposal Q ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 12/20/08 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brian Barreda Printed Name lan Bar a Title: Production Engineer F. i Si nature ```~ ,~ ~ Z'' g ~,.~,. = Phone 265-6036 j Date 1 ~ Commission Use Only Conditions of a roval: Notif Commission so that a re resentative ma witness Sundry Number: ,^ 2 '~ pp y p y ~L J Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. Subsequent Form Required: ~f0 ~~ ~, ~~~3 1;~,(~ ~ ~Q~~ APPROVED BY ~~ " ( ' ~~ Approved by: OMMISSIONER THE COMMISSION Date: r O Form 10-403 Revj~ed 06/2006 L Submit in Duplicate JOB SCOPE The Alpine C sand interval was plugged and abandoned allowing for the Kuparuk C sand interval to be perforated in August of 2008. The Kuparuk interval has not been able to sustain a producible rate possibly due to poor rock quality and has been shut-in since initially being brought on-line. A StimTube (solid mold of propellant) detonated by Halliburton's ETD tool is , recommended to try to stimulate the well. The job will use a 9' section of 1 11/16" StimTube Tool. The perforated interval is between 9,041 - 9,056 (E-.line MD). Procedure 1. MIRU. 2. Gauge tubing to WRDP @ 1796' RKB 3. RIH and pull WRDP. 4. RIH with tbg tail locator. 5. Flag line at end of tbg 6. RU Halliburton ETD and StimTube assembly. 7. Tie - in perforations with tbg tail locator and previous GR log Page 1 of 1 Maunder, Thomas E (DOA) From: Walker, Jack A [Jack.A.Walker@conocophitlips.com] Sent: Friday, October 10, 2008 11:11 AM To: Maunder, Thomas E (DOA) Cc: Davies, Stephen F (DOA); Haas, Jeanne L Subject: RE: CD1-04 (200-117) Kuparuk 407 Tom, I apologize for the error. The CD1-04 10-407 in our files also had an incorrect 2nd sheet of the 10-407 (for a different well, CD1-17, PTD 200-145). The correct geologic markers for CD1-04 are: MD (ft) ND (ft) Kuparuk C 9088 6788 Alpine D 9242 6792 Alpine C 9288 6804 ~ ~ r r~ .. L . . Sk- Jack 265-6268 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, October 09, 2008 9:54 AM To: Walker, Jack A Cc: Davies, Stephen F (DOA) Subject: CD1-04 (200-117) Kuparuk 407 Jack, I am reviewing the 407 submitted to document pertorating the Kuparuk interval in this well. On page 2 of the 407, geologic marker (formation top) is entered in block 28. The information on this new form is not the same as provided with the original 407 filed in January 2001. In particu{ar on this new form, the mds are significantly "deeper" for the Alpine as provided on the original. Could you check this out? Call or message with any questions. Tom Maunder, PE AOGCC 10/10/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~,.~(~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^/ - Gas Plugged ^ Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1 1b. Well Class: ~,o Development O Explorat~ ~ ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: August 5, 2008 12. Permit to Drill Number: 200-117 / 308-247 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 22, 2000 13. API Number. 50-103-20346-00 • 4a. Location of Well (Governmental Section): 243' FNL, 2551' FWL, Sec. 5, T11N, R5E, UM 7. Date TD Reached: November 6, 2000 14. Well Name and Number. CD1-04 Top of Productive Horizon: 1841' FNL, 3987' FEL, Sec. 33, T12N, R5E, UM 8. KB (ft above MSL): 56' RKB Ground (ft MSL): 111' AMSL 15. Field/Poof(s): Colville River Unit Total Depth: 833' FNL, 1589' FEL, Sec. 4, T11 N, R5E, UM 9. Plug Back Depth (MD + TVD): 9140' MD / 6811' TVD Undefined Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 385887 y- 5975792 Zone- 4 10. Total Depth (MD + TVD}: 13977' MD / 6897' TVD 16. Property Designation: ADL 25557 TPI: x- 390043 y- 5979505 Zone- 4 Total Depth: x- 398232 y- 5970693 Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 1796' MD / 1697' TVD 17. Land Use Permit: 932106 18. Directional Survey: Yes ~ No ^/ 19. Water Depth, if Offshore: N/A {ft MSL) 20. Thickness of Permafrost (TVD): 1546' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 114' Surf. 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surf. 2727' Surf. 2377' 12.25" 435 sx AS III L & 213 sx Class G 7" 26# L-80 Surf. 9444' Surf. 6881' 8.5" 161 sx Class G 23. Open to production or injection? Yes Q No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 9083' 8994' 9,041' - 9,056' MD 6,765' - 6,773' TVD ~ 2 7/8" PJOMEGA guns @ 6 spf ~~'~~~~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. . ` a$ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~ ~~ ~ . 9140' 50 lbs. CaC03 ,, ~~3~~:~.t .~fa~~ ~` ~' ` 'µ ~~~~~ 6 gallons 15.8# cement 26. PRODUCTION TEST Date First Production August 6, 2008 Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test 8/29/2008 Hours Tested 6.0 Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press.1 ti8 psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL 155 ~ GAS-MCF 85 WATER-BBL 0 OIL GRAVITY -API (corn) 35.6 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^ Sidewall Cores Acquired? Yes ^ No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize Iithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE 4(3I~ Form 10-407 Revised 2/2007 CONTINUED ON REV EE ~t ~~~ ~, pa'd' 28. GEOLOGIC MARKERS (List all fonmations and markers encountered}: 29. FORMATION TESTS NAME MD TVD Well tested? Yes Q No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1570' 1556' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 12498' 6667' Alpine C 13057' 6870' N/A Formation at total depth: 30. LIST OF ATTACHMENTS Summary of Daily Operations, Revised Wellbore Drawing 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker @ 265-6268 Printed Name Jack Walk ~~~ Title: Production Engineer ~$ ~ ' Z ~' Y 4 ~ Signatur / / ~ /4 , Phone 2(,v $ - (o, $ S ~ Date ` INSTRUCTIONS Jeanne L. Haas 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain}. Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~~~~ • STATE OF ALASKA •~: F ~ ~ ~ 2~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ fl~} FC~C'a ~_ WELL COMPLETION OR RECOMPLETI®it~`~"~.~?-~ BOG 1a. Well Status: Oil ^ - Gas Plugged Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. ofCompletions:1 1b. WeIf~Class: Development ^/ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: August 5, 2008 12. Permit to Drill Number. 200-117 / 308-247 p $ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 22, 2000 13. API Number: X03 ' 50- -20346-00 4a. Location of Well (Governmental Section): 243' FNL, 2551' FWL, Sec. 5, T11N, R5E, UM 7. Date TD Reached: November 6, 2000 14. Well Name and Number. CD1-04 Top of Productive Horizon: 1841' FNL, 3987' FEL, Sec. 33, T12N, R5E, UM 8. KB (ft above MSL): 56' RKB Ground (ft MSL): 111' AMSL ~ 15. Field/Pool(s): Colville River Unit Total Depth: 833' FNL, 1589' FEL, Sec. 4, T11 N, R5E, UM 9. Plug Back Depth (MD + ND): 9140' MD / 6811' ND Undefined Kuparuk Oil Pool ~ 4b. Location of Welt (State Base Plane Coordinates): Surface: x- 385887 y- 5975792 Zone- 4 10. Total Depth (MD + ND): 13977' MD ! 6897' TVD - 16. Property Designation: ADL 25557 ' TPI: x- 390043 y- 5979505 Zone- 4 Total Depth: x- 398232 - 5970693 Zone- 4 11. SSSV Depth (MD + ND): nipple @ 1796' MD / 1697' TVD 17. Land Use Permit: 932106 18. Directional Survey: Yes ^ No ^ 19. Water Depth, if Offshore: N/A (ft MSL} 20. Thickness of Permafrost (ND}: 1546' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 114' Surf. 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surf. 2727' Surf. 2377' 12.25" 435 sx AS III L & 213 sx Class G 7" 26# L-80 Surf. 9444' Surf. 6881' 8.5" 161 sx Class G 23. Open to production or injection? Yes Q No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 9083' 8994' 9,041' - 9,056' MD 6,765' - 6,773' TVD 2 7/8" PJOMEGA guns @ 6 spf _ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED slap' S01bs.CaC03 ~,;ioc.~:~~er.C G-+-i/~ 6 gallons 15.8# cement t ~J 26. PRODUCTION TEST Date First Production August 6, 2008 Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test 8!29/2008 Hours Tested 6.0 Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press.168 psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF 155 85 WATER-BBL 0 OIL GRAVITY -API (corr) 35.6 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ ,. Sidewall Cores Acquired? Yes ^ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water C\ Submit se ante sheets with this form, if needed Submit detailed descri lions, core chi s ~~, ~~ ( p ). p ' p ,photographs and laboratory analytigl results per 20 AAC 25.071. ~, J - t~• NONE ~ - ~ ~ S•~ ~:~:.~. Form 10-407 Revised 2!2007 '~_~; CONTINUED ON REVERSE SIDE ._:.~ = ,~-~/~~~ 28. GEOLOGIC MARKERS (List all formations and ma encountered): 29. FORMATION TESTS NAME MD ND Well tested? ~ Yes ~ No ~ If yes, list intervals and formations tested, Pem7afrost -Top ground Surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1570' 1556' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C ! 1 6~ Alpine C ~ ~~ - ~ 70"~U~ ` N/A ~0~~ l~ Formation at total depth: 30. LIST OF ATTACHMENTS Summary of Daily Operations, Revised Wellbore Drawing 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker @ 265-6268 Printed Name Jack Walker Title: Production Engineer p Signature Phone 2 ~ ~ r j ~ /~ Date ~ ~ ~ ~~O "-2Z~a t./ INSTRUCTIONS Jeanne L. Haas 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion}, so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analyticat laboratory information required by 20 AAC 25.071. Forrn 10-407 Revised 2/2007 ;WSR -Well Service Report ~ • Page 1 of 1 Well Service Report Well Sob Scope CPf1I Rep CDl-04 Drilling Support -Capital Turtle, Joe Date Daily Work. [Jnit Number 8!5/2008 2145 Network # Daily Cost Cum Cost Compang= Unit Supervisor 10227705 $21,209 $21,209 ~ SLB-Eline WIBLE Initial & INITIAL Final T/I/0=1700/1600/700 FINAL Field: ALPINE Pressures: T/U0=2100/1600/700 PERFORATED WITH 2 7/8" POWERJET OMEGA LOADED 6 SPF FROM ~ UBING PRESSURE UNCHANGED AT 200 PSI BEFORE AND 24 br. Summary AFTER PERFORATING. TUBING PRESSURE INCREASED TO 750 PSI WHEN TOOLS RETURNED TO SURFACE. TUBING PRESSURE IS 2100 PSI BEFORE LEAVING LOCATION WITH UNIT. 5TARTTIME QPERATICSN 06:00 AM MEET WITH PE. REVIEW PROCEDURE. MOBILIZE TO CDl-04. 07:15 AM SPOT EQUIPMENT AND SUPPORT EQUIPMENT ON CD1-04. HOLD PJSM. RE-HEAD ELINE. 08:00 AM RIG UP ELINE. 08:30 AM PRESSURE TEST LUBRICATOR TO 3000 PSI HIGH AND 500 PSI LOW FOR 5 MINUTES. 09:00 AM UNSTAB AND ARM 2 7/8" POWERJET OMEGA GUN. RIH WITH 15' OF LOADED 2 7/8" POWERJET OMEGA, 6 SPF. TOTAL TOOLSTRING LENGTH= 33.1'. MAX OD=2.875". TOOLSTRING: MH-22, AH- 38, 1 11!16" WEIGHT BAR, SECURE FIRING HEAD, 20' 2 7/8" GUN CARRIER LOADED 15', BOTTOM NOSE. RIH AND CONTINUE TO SEASON CABLE. TIE INTO RST LOG DATED Ol-AUG-2008. SIT DOWN TWICE WITH BOTTOM OF 09:45 AM GUN AT 9092'. EMAIL TO TOWN ENGINEER FOR DEPTH CONFIRMATION. LOG ADDITIONAL COLLAR CHECK PASS. PULL INTO POSITION FROM 9065' TO CCL STOP DEPTH OF 9032.5'. FIRE PERFORATING GUN WITH 200 PSI ON TUBING. NO IlVIMEDIATE PRESSURE RESPONSE NOTED. POOH WITH ELINE. T__UBING PRESSURE AT 750 PSI WHEN CLOSING SWAB AND 2100 PSI BEFORE LEAVIN THE PAD. Ol :15 PM RIG DOWN ELINE. 02:00 PM PERFORM POST ALPINE TRIP MAINTENANCE ON UNIT AND EQUIPMENT. Fluid Type Ta Nell From Well Non- recoverable Vote DIESEL 1 WHE PT. http://anc402/weq/worklog.aspx?Wellname=CD 1-04&Date=08/05!2008&ID=E25FD215A5... 8/6/2008 WSR -Well Service Report Page 1 of 1 ~• ~ Well Service Report Well Job Scope CPAI Rep CD1-04 Drilling Support -Capital Senden, Ty Date Daily Work Unit Number 8/5/2008 770 Network # Daily Cost Cum Cost Company Unit Supervisor 10227705 $3,523 $3,523 HES PECK Initial & INITIAL T/U0= Final 2200/1850/750 FINAL Field: ALPINE Pressures: T/U0= 2200/1850/750 MEAS D BHP OF 4522 PSI 9050' RKB. ATTEMPTED TO PULL DV 24 hr. Summary FROM 8878' RKB. UNABLE TO ACCESS MANDREL DUE TO SCALE (03/28/07). IN PROGRESS. STARTTIME OPERATION 03:00 PM RIG UP ON CD1-07. DECISION MADE TO RIG DOWN FOR CD1-04 WORK. RIG DOWN. SPOT EQUIPMENT ON CD 1-04. 04:15 PM INSPECT LOCAITON, TGSM. R/U .108 WIRE AND 1.875" ROLLER STEM (2.6" WHEELS, NEW PINS). RS, QC, 8', QC, KJ, LSS, QC. PT LUB W/ GAS. 10 MIN. LUB STOP. RIH W/ 2.65" CENT, SOFT SET, AND DUAL HES 05:15 PM SAPPHIRE GAUGES. 30 MIN. SURVEY STOP @ 9032' SLM (9050' RKB). 10 MIN. GRADIENT STOP @ 8872' SLM (8890' RKB). POOH. 10 MIN. LUB STOP. RIH W/ KNUCKLED 4 1/2" OM-K AND 1 1/4" JDC. BEGIN TO SEE SCALE @ 07:45 PM 8650'. S/D @ 8840' SLM. WORK DOWN TO 8863' SLM. UNABLE TO WORK THROUGH. UNABLE TO ACCESS MANDREL. POOH. SMALL AMOUNT OF CEMENT AND HARD SCALE IN KOT. 09:00 PM BEGIN LDFN. INSPECT LOCATION, PJSM. NOTIFY DSO OF WELL STATUS. IN PROGRESS. 09:30 PM TRAVEL TO OFFICE, DOWNLOAD. END TICKET. Fluid Type To Well From Well Non- recoverable Note http://anc402/weq/worklog.aspx?Wellname=CD 1-04&Date=08/05/2008&ID=3717C 17ED7... 8/6/2008 ~t~ WNS ~ CD1-04 ConocoPhillip s ~, Well Attributes :11,{tik~l h i I Wallbore API/UWI Field Neme Well Statue Inclination (°) MD (RKe) Total Depth (RKB) 501032034600 ALPINE PROD 91.37 11,481.00 13,977.0 ~I -' Comment SSSV: WRDP H25 (ppm) Deb Mnotetion End Dete KB-Ord (R) Rlp Rekese Data Last WO: 11/82000 wen coon : -coc oa esaoce - Schsmellc- ACWei - Anno[atlon Depth (RKB) End Data Mnotatlon Entl Dete Last Tag: 9,157.0 722008 Rev Reason: RESET WRDP 9/32008 Casin Strin s Casing Description OD (In) ID (In) Top (RKB) Set Depth (RK8) Set DepM (ND) (RKB) Wt (IbsM) Ontla Top Thead ^~ I CONDCUTOR 16 15.062 0.0 114.0 114.0 62.58 H-40 WELDED SURFACE 95/8 8.697 0.0 2,727.0 2,376.7 36.00 J-55 BTGMOD coNOCUroR, 11e i PRODUCTION 7 6.151 0.0 9,444.0 6,881.0 26.00 L-80 BTCM ~ `~ OPEN HOLE 6 iB 6.125 9,444.0 13,977.0 6,897.1 Tubin Strin s Tubing Description OD (inl ID (In) Top (RK8) Set Depth (RKB) Sat Depth (ND) (RKB) Wt (IbelR) Orede Top Thread NIPPLE, 1,]98 sssv t~9e ~ TUBING 4 1/2 3.958 0.0 9,083.0 6,786.0 12.60 L-80 IBTM , Other In Hole All Jewel :Tubin Run & Retrievable Fish etc. Top (ftKH) Description Comment Run Date ID (In) 1,796.0 NIPPLE CAMCO BAL-0LANDING NIPPLE 11/7/2000 3.812 1,796.0 SSSV SSSV: WRDP CAMCO WRDP-2 SSSV (SER# HVS•269) 8/6/2009 2.125 suRFACE, z,]n 4,176.0 GAS LIFT CAMCOIKBG-2IIIDMYBK/// Comment: STA 1 7/31/2008 3.938 6,759.0 GAS LIFT CAMCO/KBG-2/1/OVBK/.25//Comment: STA2 8/6/2008 3.938 8,878.0 GAS LIFT CAMCO/KBG-2/1/DMYBK/// Comment: STA 3 31732001 3.938 8,940.0 NIPPLE HES'X' NIPPLE 11!72000 3.813 GAS LIFT 8.994.0 PACKER BAKER'S-3'PACKER 11/7/2000 3.875 , a,17s 9,070.0 NIPPLE HES'XN' NIPPLE 11!72000 3.725 9,083.0 WLEG BAKER WIRELINE REENTRY GUIDE 11/7/2000 3.875 9,161.0 PLUG BAKER 3" IBP w/1.75" FISHING NECK 8112008 0.000 Perforat ions GAS LIFT 8759 Top (RKB) Btm (RKB) Top (ND) (RKB) Btm (ND) (RKB) T Pe Zone Shot De is Is Deb Comment 9,041.0 9,056.0 6,764. 5 6,772.6 IPERF KUPC, CD1-04 6.0 8/4/2008 2 7/8" PJ GAS LIFT, 8,878 NIPPLE, 5,800 PACKER, 8,990 IPERF. 9,a7-0.088 NIPPLE. 9,0]0 LEG, 9,093 ~ k }, I ~~ \ / J ~`y \ \`. ~ \ \~\ V~\ 111F_ ` V /~ ~~~ RUG, 9,181 PRODUCTION, 9,440 OPEN HOLE, 13,877 TD, 13,977 - ~ ° - - \ ~ ~ ham/ \~~~c->, 1~p ~ '°L. `~~ V ~.J~ ~1 L `~\~`~ r~r ` ~ - - • • R~" c . ~,; STATE OF ALASKA ` ALASKA OIL AND GAS CONSERVATION COMMISSION ~dBS~~ ~~~ REPORT OF SUNDRY WELL OPERATIONS R; 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 200-117 , 3. Address: Stratigraphic ^ Service ^ 6. APi Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20346-00' 7. KB Elevation (ft): 9. Well Name and Number: RKB = 56' CD1-04 ' 8. Property Designation: 10. Field/Pool(s): ADL 25557 / ALK 372095 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 13977. feet true vertical 6894' feet Plugs (measured) 9140' Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDCUTOR 114' 16" 114' SURFACE 2727' 9-5/8" 2727' PRODUCTION 9444' 7" 9444' OPEN HOLE 4533' 6-1/4" 13977' ~y ~y Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4.1/2" , L-80, 9083' MD. Packers &SSSV (type & measured depth) PKR = Baker'S3' Packer @ 8994' SSSV = WRDP-2 ~ 1796' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-BW Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run ` Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Plugged Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.O. Exempt: 308-248 contact Jack Walker ,1'a ~ , Printed Name Jack Walker ~ Title `~ Production Engineer 6c'J~~ S `' ~ Signature ~ , }r ~ Phone 265-6268 ,-~ 0 !~ Date. `~~- P (/ Pre aced 6 Jean L. aas 263-4470 - ~'~ Asa s•iy. ~ s Form 10-404 Revised 04!2006 7r,.~ ~ ~ L~~~ ., ~ f ~~ ~ Submit Originally ~~ j~ WSR -Well Service Report • • Page 1 of 2 Well Service Report t~'eil Job Scope CPAI Rep CD 1-04 Drilling Support -Capital Brake, Jared .Date Ilaily 4'~'ork L7nit Number 8/1/2008 8305 Network # Daily Cost Cum Cost -~ Company Unit Supet-~~isor 10227705 $83,800 $83,800 SLB-Eline WIBLE Initial & INITIAL Final T/U0=2200/1900/750 FINAL Field: ALPINE Pressures: T/I/0=2200/1900/750 SET 3" BAKER IBP AT 9160.55'. BOTTOM OF TOOL AT 9166'. TOP OF FISHING NECK AT 9154'. 9166' (BOTTOM OF TOOL) WAS DEEPEST 24 hr. DEPTH ATTEMPTED. IBP WAS STUCK WITH 700# OF OVERPULL AT summary THIS DEPTH. PUNCH TUBING WITH 2' LOADED "SMALL" PUNCHER FROM 9002-9004'. RECORD RST LOG REFERENCING OPEN HOLE POROSITY TO TUBING COLLARS. ST ARTTIlVIE OPERATION 06:00 AM MEET WITH PE. REVIEW PROCEDURE. SYNC FOR JOB. 06:30 AM MOBILIZE TO CD1-04. SPOT EQUIPMENT AND SUPPORT EQUIPMENT. CALL LOADER TO SPOT BOP BASKET. 07:15 AM STANDBY FOR THIRD PARTY CRANE. CRANE ARRIVES ON LOCATION. HOLD PJSM. STANDBY FOR ELINE JARS 08:15 AM TO ARRIVE ON CHARTED 207.ORDERED ELINE JARS AFTER REPORTS OF SLICKLINE LOOSING JAR ACTION. RIG UP ELINE. OPCHECK IBP STRING. 09:45 AM PRESSURE TEST LUBRICATOR TO 3000 PSI HIGH AND S00 PSI LOW FOR 5 MINUTES. RIH WITH 3" IBP. TOTAL TOOLSTRING LENGTH=46.2'. MAX OD=3". TOOLSTRING: MH-22, AH-38, 1 11/16" WEIGHT BAR, 2.65" ROLLER, ELINE JARS, 2.65" ROLLER, GO ADAPTER, CCL, ELECTRIC WIRELIKE SETTING TOOL, TEST PRESSURE EQUALIZING VALVE, PRESSURE EXTENDER, BELLVILLE PULL DISCONNECT, HYDRAULIC RUNNING TOOL, RETRIEVABLE BRIDGE PLUG. RIH AT 120 FPM PER BAKER 10:15 AM RECOMMENDATION. PICKUP 100' EVERY 2000' TO SEASON CABLE. RIH TO BOTTOM OF TOOL DEPTH=9158'. PICKUP CLEANLY AND LOG TUBING TAIL 5' SHALLOW. ADD 5' AND RUN BACK IN HOLE TO 9166' BOTTOM OF TOOL DEPTH. CONSULT WITH PE AND DECIDE TO SET IBP AT THIS DEPTH WHICH IS 9138' CCL DEPTH. CCL TO MID ELEMENT=22.55'. SET MID-ELEMENT AT 9160.55'. THERE IS A CASING COLLAR AT 9115'. NEXT CASING COLLAR SHOULD BE BETWEEN 9155' AND 91ST. BEGIN SETTING IBP. IBP SET IN 75 MINUTES. NO OVERPULL PULLING OFF PLUG. PRESSURE TEST IBP TO 1000 PSI OVER TUBING PRESSURE 3200 PSI . 02:45 PM PLUG HELD STEADY FOR 15 MINUTES. BLEED PRESSURE BACK TO 2200 PSI. RIG DOWN IBP. RIG UP 2 AND ARM 2' LOADED OF 1.56" TUBING PUNCHER LOADED WITH "SMALL" CHARGES FOR 4.5" TUBING. FILL LUBRICATOR http ://anc402/weq/worklog. aspx?ID=OCE052178B6A46F891 E602E278E754C 0&Date=8/ 1 /... 9/9/2008 ,WSR -Well Service Report . ~ Page 2 of 2 ~rc.~ ~~~~ WITH DIESEL BEFORE OPENING SWAB TO PREVENT BLEEDING OFF ON IBP. RIH WITH UPCT (GAMMA RAY, CCL) AND Z' OF LOADED "SMALL" TUBING PUNCHER. TOOLSTRING: MH-22, SWIVEL, 3 x 1 1 I /I6" WEIGHT BARS, UPCT, TUBING PUNCHER HEAD, TUBING PUNCHER, BOWSPRING 03:15 PM ECCENTRALIZER. TOTAL TOOLSTRING LENGTH=3I.7'. MAX OD=1 11/16". CORRELATE TO TUBING TALLY DATED 11/07/2000'. UNABLE TO ,~ ~ 9~ CORRELATE TO GAMMA RAY DUE TO SCALE. PLAN TO PUNCH FOR RST `~'"~~ ~ ` LOG. PUNCH TUBING WITH 2' "SMALL" PUNCHER FROM ' ~ BELOW THE PACKER. CCL-TS=b.3'. STOP AT 8995.7. POOH WITH ELINE. 07:15 PM RIG DOWN TUBING PUNCHER. RIG UP AND OP-CHECK RST-C. RIH WITH RST TO CORRELATE TO OPEN HOLE MWD. TOTAL TOOLSTRING LENGTH=47'. MAX OD= 1 11/16". TOOLSTRING: MH-22, 08:00 PM SWIVEL, 2 x 1 11/16" WEIGHT BARS, PBMS, RST-C, BOTTOM NOSE. LOG UP AND DOWN PASSES AT 60 FPM FROM 8850-9125'. REPEAT 4 PASSES UP AND DOWN. VERIFY DATA QUALITY. POOH WITH RST. 10:30 PM RIG DOWN ELINE. 11:30 PM MOBILIZE TO CAMP. Fluid Type To From ' Nan- Nate Well 1~ ell recoverable DIESEL 1 WHE PT. DIESEL 2 LRS TESTS PLUG TO 3200# DIESEL 2 EQUALIZE WELL X2 http://anc402/weq/worklog.aspx?ID=0CE052178B6A46F891 E602E278E754C0&Date=8/ 1 /... 9/9/2008 .WSR -Well Service Report . • Page 1 of 1 Well Service Report WeIl Sob Scope CFAI Rep CD1-0~ Drilling Support -Capital Brake, Jared Date Daily Z'~'ork Unit Number 8/3/2008 770 Network # Daily Cost Cum Cost Company Unit Supe~~s•isor 10227705 $10,127 $10,127 1 HES ~ PECK Initial & INITIAL T/U0= Final 2200/800/750 FINAL T/I/0= Field: ALPINE Pressures: 2200/800/75 0 24 hr. DUMPED 50 LBS OF CaC03, AND ~ 6 GALLONS OF CEMENT ON IBP @ Summary 9140' SLM. COMPLETE. S1:~RTTIME OPERATION 06:00 AM OBTAIN WELL FILE FROM OFFICE, CONFER W/ CWG REP. TRAVEL TO CDl-04 VIA MI SHOP FOR CEMENT. 07:00 AM INSPECT LOCATION, TGSM. R/U .125 WIRE AND 1.875" ROLLER STEM (2.6" WHEELS, NEW PINS) RS, QC, 8', QC, KJ, LSS, QC. LRS PT LUB TO 2500 PSI. 08:45 AM RIH W/ 5' x 2.125" STEM AND 3.5" CENT. TAG IBP @ 9139' SLM. POOH. RIH W/ 10' x 2.5" DUMP BAILER FULL OF CaC03. FALLING ERRATICALLY 10:00 AM DUE TO STICKY RESIDUE ON WIRE FROM CDl-07. DUMP CaCo ON IBP Cad 9140' SLM. POOH. 11:45 AM LAY DOWN AND RE-PACK. 12:15 PM RIH W/ SAME. DUMP CaC03 ON IBP 9140' SLM. POOH. 02:00 PM MIX CEMENT. RIH W/ 10' x 2.5" DUMP BAILER FULL OF CEMENT. ATTEMPT TO DUMP 02:15 PM CEMENT ON IBP @ 9140' SLM. POOH. CEMENT HAD STARTED TO SET UP IN BAILER. RFCOVFRF.D BAt ..R F L OF CEMENT. RE-MIX CEMENT. 04:00 PM RIH W/ SAME. DUMP CEMENT ON IBP 9140' SLM. POOH. RIH W/ SAME. ATTEMPT TO DUMP CEMENT ON IBP @ 9140' SLM. POOH. 05:30 PM CEMENT BEGAN TO SET UP IN BAILER. RECOVERED FULL BAILER. RE- MIX CEMENT. 07:00 PM RIH W/ SAME. DUMP CEMENT ON IBP 9140' SLM. POOH. 08:30 PM BEGIN RIGGING DOWN. INSPECT LOCATION, PJSM. NOTIFY DSO OF WELL STATUS. JOB COMPLETE. 09:15 PM TRAVEL TO OFFICE, DOWNLOAD. END TICKET. Fluid Type To R'ell From Well Non- recoverable Note DIESEL 5 TUBING http://anc402/weq/worklog.aspx?ID=E43AAA21 C 12641 E7AFEB2600A98B82E0&Date=8... 9/9/2008 -WSR -Well Service Report ~ ~ Page 1 of 1 Well Service Report i~'ell Job Scope C:Pr~i Rep CD 1-04 Drilling Support -Capital Brake, Jared Date Daily !Fork Unit :Number 8/4/2008 ~- 770 Network # Daily Cost Cum Cost Company Urut Supervisor 10227705 $5,585 $5,585 HES ~ PECK Initial & INITIAL T/U0= Final 2000/1800/775 FINAL Field: ALPINE Pressures: T/I/0= 2000/1800/750 24 hr. MITT TO 3000 PSI PASSED. DRAW-DOWN TEST TO 500 PSI PASSED. Summary TAGGED CEMENT @ 9142' SLM. COMPLETE. START`I'.I1~~iE OPERATION 01:00 PM ARRIVE FROM CD2-S6. STAND-BY FOR SUPER SUCKER TO EVACUATE WATER FROM WELL ROW. 03:00 PM INSPECT LOCATION, TGSM. R/U .108 WIRE AND 1.875" ROLLER STEM (2.6" WHEELS) RS, QC, 8', QC, KJ, LSS, QC. LRS PT LUB TO 3500 PSI. BEGIN MITT. INITIAL T/U0= 2000/1800/775. LRS TO PRESSURE TUBING: 04:30 PM 3000/1850/775. AFTER 1S MINS: 2925/1850/775. AFTER 30 MINS: 2925/1850/775. MITT PASSED. DRAW TUBING DOWN TO 500 PSI AND MONITOR FOR 30 MINS: UNCHANGED. RIH W/ 3.S" CENT, TEL, AND SAMPLE BAILER. ATTEMPT TO LOCATE TTL. TOOLS HANG UP @ 9080' SLM. ABLE TO MOVE DOWNWARD. ATTEMPT OS:30 PM TO LOCATE TTL AGAIN, AND HANG UP @ 9080' SLM. TAG CEMENT 9142' SLM. PUH AND HANG UP @ 9080' SLM. SPANG UP A RESSIVELY FOR ~ 30' AND PULL FREELY OUT OF HOLE. RECOVERED SAMPLE OF CEMENT. SUSPECT TEL WAS HANGING UP. 07:1 S PM RIH W/ 10' x 3" DD BAILER. FALL FREELY TO TOP OF CEMENT @ 9142' SLM. POOH. RECOVERED SAMPLE OF CEMENT. 08:45 PM BEGIN RIGGING DOWN. INSPECT LOCATION, PJSM. NOTIFY DSO. JOB COMPLETE. 09:30 PM TRAVEL TO OFFICE, DOWNLOAD. END TICKET. Fluid Type To Well From ti'Vell Non- recoverable No#e DIESEL S TUBING http://anc402/weq/worklog.aspx?ID=20B9EBD426DE441 E83394DBAEE6B9B31 &Date=8... 9/9/2008 "~~a~[~ O~a~~G~ DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS SAR~4H PAL/N, GOVERNOR 550 WEST 7rH AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (90fi) 269<8800__ FAX. (907) 269=8938 August 5, 2008 Dora I. Soria Senior Landman ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 ~~NN~~ ~~ G ~ :~. 200$ Subject: Request to Produce the Kuparuk Formation in CD1-04 via Fax (263-4966) and Mail Dear Ms. Soria: ~ S' ~ ~ ~ ~ ~-~ The CD1-04 Well has been producing from the Alpine interval. The shallower Kuparuk Sand interval was found in the immediate section of the well. By letter, dated July 28, 2008, ConocoPhillips Alaska, Inc. (ConocoPhillips) applied for tract operations approval to produce the shallower Kuparuk Sand interval within the CD1-04 wellbore. The Kuparuk Sand interval of the proposed tract operation is within the Colville River Unit (CRU) and CRU Tract 30 (ADL 25557), but not encompassed within any participating area. The plan is to isolate the Alpine interval, and perforate and produce the Kuparuk interval in the intermediate-hole section of the CD 1-04 wellbore. I approve your plan to produce the Kuparuk interval within the CD 1-04 wellbore and commingle the Kuparuk production with other CRU production in the Alpine Production Facility subject to the following terms and conditions: 1) This approval is for a period of approximately 3 months, that is, until October 24, 2008, the same period as the CD1-17 Kuparuk Tract Operation. ConocoPhillips shall notify the Division, in writing, of the start date of Kuparuk production from the well. At the end of the tract operation period, ConocoPhillips shall provide a status report of the activities conducted under the CD 1-04 Kuparuk interval Tract Operation, as well as the CD 1-17 Kuparuk Tract Operation, and outline the plans forward for the Kuparuk Formation in the area. 2) All CD 1-04 Kuparuk interval produced fluids shall be allocated to CRU Tract 30 (ADL 25557), and Accounting Unit Code "CR17" is assigned to the Kuparuk interval fluids allocated to the CDl-04 Tract Operation. ConocoPhillips, as the CRU Operator, shall separately account for the Kuparuk production allocated to CD1-04 on the monthly CRU production report. "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans. " r i Ms. Dora I. Soria CD 1-04 Kuparuk Formation Tract Operation August 5, 2008 Page 2 3) Finally, this approval is only for the general CDl -04 Kuparuk Tract Operation plan. Specific on-site operations may require additional approvals. Sincerely, Kevin R. Banks Acting Director cc: AOGCC Jack Walker, CPAI CRU CD1-04_Kuparuk Tract Operation.doc r: AI,ASS-A OIL Ai~TD GAS CO1~T5ERQATIOI~T COMt-IISSIOI~T Jack Walker Production Engineer ConocoPhillips Alaska Inc. PO Box 100360 ~'~%~~~° JUL ~. ~ 2008 Anchorage, AK 99510 Re: Colville River Feld, Alpine Oil Pool, CD 1-04 Sundry Number: 308-248 Dear Mr. Walker: • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~~"7 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend . A person may .not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this % sday of July, 2008 Encl. ~ ~ ~ ~ ~ I ~, ~ STATE OF ALASKA (ts ~~~ ~ ~ 2Q0~ ALASKA OIL AND GAS CONSERVATION COMMISSION M~ APPLICATION FOR SUNDRY APPRI4~L~c~ ~ ~~ ~~~~,, C:Ornia~~~sl0n 20 AAC 25.280 ,~1f`v; <'-~l'B~~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ After casing ^ Repair well ^ Plug Perforations ~ ~ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Curcent Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ . Exploratory ^ 200-117 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20346-00 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 ^ NO Q CD1-04 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25557 / ALK 372095 RKB 56' Colville River Field /Alpine Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth Mo (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13977' 6897' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2727 9-5/8" 2727 PRODUCTION 9444' 7" 9444' OPEN HOLE 4533' 6-1/4" 13977' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1 /2" L-80 9083' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER'S-3' PACKER pkr= 8994' SSSV= WRDP-2 SSSV= 1796' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: July 18, 2008 Oil ^ Gas ^ Plugged^ ~ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker Printed Name Jack W al ker Title: Production Engineer ' / Signature ~'G~-' ~l Phone 265-6268 Date /~-~Zt.Q-Zes~ ~ Commission Use Onl Sundry Number: , Conditions of approval: Notify Commission so that a representative may witness .. ~ ~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: JUL 1 6 2DD8 Subsequent Form Required: ~~ .. _...._.___. APPROVED BY > / ~s' Approved by OMMISSIONER THE COMMISSION Date: / ` ` Form 10-403 Revised 06/2006 ~ ~{ ~ ~ I ~ Y ~ t Submit in Duplicate ~ T /5~b ' ` Y i.~ r`'~%f' ConocoPhillips • Jack Walker Production Engineer ConocoPhillips Alaska, Inc. P:O. Box 100360, ATO 1740 Anchorage, AK 99510-0360 phone 907 265-6268 "" July 10, 2008 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ,~~~. ~ ~ ~~~~7 Re: Request for Sundry Approvals Colville River Field, Alpine Oil Pool, well CD1-04 Permit to Drill 200-117 Dear Chairman Seamount: ConocoPhillips Alaska, Inc. as operator of the Colville River Unit requests approval to plug the Alpine Oil ~ Pool in well CD1-04, and perforate the Kuparuk interval in an undefined oil pool in the same well. A sundry request form 10-403 for each operation (Plug/Alpine Oil Pool and Perforate New Pool/Undefined Kuparuk Oil Pool) are attached and submitted in duplicate. Well CD1-04 was completed in 2000 in the Alpine Oil Pool as a development oil well and produced more than 13,000,000 STBO before watering out in 2007. The Kuparuk interval was logged in the intermediate hole and cemented behind production casing in 2000. The CD1-04 Kuparuk bottomhole location is 1843' FNL and 3985'FEL, Section 33, T12N, R5E. There is no ownership change within 500 feet of the CD1-04 bottomhole location. / Commingling of production of the Alpine Oil Pool with the undefined oil pool within the CD1-04 wellbore is ~/ not proposed. We would like to begin these CD1-04 operations on July 18, 2008. Please call me at 265-6268 if you have any questions. ck Walker Production Engineer ConocoPhillips Alaska Inc. ~~ ~l~P ~/ `~ ~ `, ~t F /a, - /~ x ~,~~~~,~ ~~~.5 ~~~L'~ ~l P ~ / R L~ % ''~' ~ JP `'•°__~.~-r/'ee'/' G?~~'T' (~:n~ lrvQv(~/ fl~f 4 /-'+!F`X'~~ `~, ~/ .-°'G`C~f ?` ter''. a ,!~ mfr' `~' 9... ~. ii z ~. .~ • J ~~ s c~ .° J ! ;~ ~ ~.r , ~ ~ ~: ~tc.+ ~ ~ /rroc~~j CD 1-04 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska, Inc. Colville River Field Well CD1-04 (PTD 200-117) Sundry Notice 10-403 Request Plug Alpine Oil Pool and Perforate New Oil Pool /Kuparuk Undefined July 10, 2008 Purpose: This Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc. intent to plug the Alpine oil pool in CD1-04 and perforate the Kuparuk interval, an undefined pool. History: CD1-04 was completed with an openhole completion in the Alpine Oil Pool in October, 2000 and produced more than 13,000,000 STBO until being shut-in in July 2007 with a watercut of 99.8%. The Kuparuk interval was logged in October, 2000 in the CD1-04 intermediate hole. Production casing was cemented across the Kuparuk interval. Proposed Operations: 1. Set inflatable bridge plug above the Alpine openhole completion at 9150'MD±. 2. Set sand plug with cement cap on IBP. 3. Run tie-in CNL. 4. Perforate Kuparuk interval at 9041'-9056'MD reference CD1-04 Array Resistivity log 22-Oct-2000. 5. Measure static pressure and put on production. 6. Test twice per month or more frequently. ~/ ~ t ~ ~/• . ;~ ~L?•it(~ ,, / ,~ ~ . ,~o~ /~~i" :-- `qtr, 9 ~ r l ~. ~~r~~~ v~f~N~ ~U ~~~f ~' .`/" . ,~ ~riP L ~r ~ Cc~`'i.~'/),~/`C TOE ~ ~I/^,~ l~i/~!'~f i I ~1~? ~V'~?l( U4L~~ /,~~~~~~:~/i/(~ ~2f~r ~Y3~-'T!/Cf t ~111~,G~t 1t~'~. U'~`~ ~','v~G~:t.~~ ~;~~ ~~ ~'~ h~.~r ~re."~~~~/~%1`f~'~' ,>'~d~~' ~j/~ /~1 ~ ~,1 e. s~~{~ ti J!fC° ~l}//~f ~ C~'~~lj.t~/ /~/rjs~/ ~/ L~~ r%i ~L~~ G~. ~r~ f /f ~/J~', ~~~ ~P / ~/1/1~1 'C.!/;" f /!~~ ~/ ~ /r'~~G~~f~l'~ ~fl~ !L'~!1~ / N~'~,//l s f/~ ~ ~ cl";~„Y-' ' A .(~` f'~ y V i~' / /~r,r ~ fy/f 7~r~~I LM~1. f / /~~~fJr '~CJL"~ f'" ~/ ~ ,Y /? /7~~e U~./'~ ""'" "~ f ~~ ~ `~/~yf W' v F_ ~ ~ ~~ F ~ P'D lRP t` ,?LZ Grp,--, ~~ ' ~,H ~, G'c,t; vr..! ~Cle/~e~i v'~-c=i' ~,*- .I~1/~.;,t' i ~y,'r,' ~'-P,O,/ ~ ~~ . •' ' ~ 'L"~%'G° ~/ ~i LLB ~~ ~~ , '.~ ~!',~ ~' -t cr ,~ ` ~~~~ ~~ ,~~y~~v: ~s \s ~~~~~~~d~ -~~ v.x~\\ Q~~~.nc~ w c3.S ~ ~ ~\ ~ ~ c0 ~. ~~.~~~ ~~~~,~ • ~' 4 ~ ~ ~ t i L R r ~ 1 ~', ; "~ 1 di i r . ~ .. ~ ~ ~ .. ~ ALASKA OIL A1~TD GA5 COATSERQATI011T COMl-IISSIOIQ Jack Walker Production Engineer ConocoPhillips Alaska Inc. PO Box 100360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Anchorage, AK 99510 ©o-It~ Re: Colville River Field, Kuparuk Undefined Oil Pool, CD 1-04 Sundry Number: 308-247 ~~~N JUL ~. ~ 2D0~ Dear Mr. Walker: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair sf~ DATED tYus ~ day of July, 2008 Encl. ,,,~~ • ~ 17 ALASKA OIL AND GAS CONSERVAT ON COMMISSION ~~ ~~~~ ~ ~ ~~ ~!~ c~ ~~ APPLICATION FOR SUNDRY APPRC~~ ~~~~~. C~i~t`~ivss=~n 20 AAC 25.280 ~t)~=~~~~;~, 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool^ ' Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development Q - Exploratory ^ 200-117 ` 3. Address: Stratigraphic ^ Service ^ 6. APt Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20346-00 7. If perforating, Gosest 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 ^ NO Q Dl~~~•t,~•p$ CD1-04 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25557 ~ RKB 56' ~ Colville River Field /Undefined Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth M~ (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13977' - 6897' Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 272T 9-5/8" 2727 PRODUCTION 9444' 7" 9444' OPEN HOLE 4533' 6-1/4" 13977' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 9083' Packers and SSSV Type: Packers and SSSV MD (ft) pkr-- BAKER'S-3' PACKER pkr= 8994' SSSV= WRDP-2 SSSV= 1796' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: July 18, 2008 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker Printed Name Jack Walker Title: Production Engineer Signature G~~ 4 Phone 265-6268 Date // .- -~ a a~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: S ~~ JUG ~ ~i 2DD6 Subsequent Form Required: ~~~ ' `"' -r~""w""'""' ...~.-~ APPROVED BY ~~ Approved by: OMMISSIONER THE COMMISSION Dater Form 10-403 Rev sed 06/2006 ~ ~ ~ v ~' ~ H ~,,,, Submit in Du irate o~ Sri/cam /~ 7• ~ OS • ConocoPhillips July 10, 2008 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501. I~ Jack Walker Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360, ATO 1740 Anchorage, AK 99510-0360 phone 907 265-6268 ~L~~' V JUL 1 1 2008 Alaska Oil & Gas ions. ~om~nis~ian Anchorage Re: Request for Sundry Approvals Colville River Field, Alpine Oil Pool, well CD1-04 Permit to Drill 200-117 Dear Chairman Seamount: ConocoPhillips Alaska, Inc. as operator of the Colville River Unit requests approval to plug the Alpine Oil Pool in well CD1-04, and perforate the Kuparuk interval in an undefined oil pool in the same well. A sundry request form 10-403 for each operation (Plug/Alpine Oil Pool and Perforate New Pool/Undefined Kuparuk Oil Pool) are attached and submitted in duplicate. Well CD1-04 was completed in 2000 in the Alpine Oil Pool as a development oil well and produced more than 13,000,000 STBO before watering out in 2007. The Kuparuk interval was logged in the intermediate hole and cemented behind production casing in 2000. The CD1-04 Kuparuk bottomhole location is 1843' FNL and 3985'FEL, Section 33, T12N, R5E. There is no ownership change within 500 feet of the CD1-04 bottomhole location. Commingling of production of the Alpine Oil Pool with the undefined oil pool within the CD1-04 wellbore is not proposed. We would like to begin these CD1-04 operations on July 18, 2008 Please call me at 265-6268 if you have any questions. ck Walker Production Engineer ConocoPhillips Alaska Inc. '~ CD1-04 w DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska, Inc. Colville River Field Well CD1-04 (PTD 200-117) Sundry Notice 10-403 Request Plug Alpine Oil Pool and Perforate New Oil Pool /Kuparuk Undefined July 10, 2008 Purpose: This Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc. intent to plug the Alpine oil pool in CD1-04 and perforate the Kuparuk interval, an undefined pool History: CD1-04 was completed with an openhole completion in the Alpine Oil Pool in October, 2000 and produced more than 13,000,000 STBO until being shut-in in July 2007 with a watercut of 99.8%. The Kuparuk interval was logged in October, 2000 in the CD1-04 intermediate hole. Production casing was cemented across the Kuparuk interval. Proposed Operations: 1. Set inflatable bridge plug above the Alpine openhole completion at 9150'MD±. 2. Set sand plug with cement cap on IBP. 3. Run tie-in CNL. 4. Perforate Kuparuk interval at 9041'-9056'MD reference CD1-04 Array Resistivity log 22-Oct-2000 5. Measure static pressure and put on production. 6. Test twice per month or more frequently. . . Conoc~hillips Alaska þ"PR P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 & March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ;)00 - \ 17 5GANNED APR 0 9 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, £~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 /CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 . If' CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 ?!16!200? Alpine Field March 31,2007 ~~... ,.. ... :t...· I. MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Q 0 ó '- t I ¿Sing Detail 95/8" Surface Casing .PHILLlPS Alaska, Inc. GD I~OLf Well: CD1-04 Date: 10/23/00 A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.30 FMC Gen V Hanger 2.34 36.30 Jts 3 to 64 62 Jts 9-5/8" 36# J-55 BTC Csg 2607.10 38.64 Davis Lynch Float Collar 1.53 2645.74 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 78.30 2647.27 Davis Lynch Float Shoe 1.75 2725.57 9 5/8" S , 2727.32 TD 12 1/4" Surface Hole 2740.00 RUN TOTAL 35 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1, #2 & #3) and over collars on jts# 14,16,18,20,22,24,26,28 \ 30,32,34,36,38,40,42,44,48,50,52,54,56,58,60. ¡ Use Best-a-Life 2000 pipe dope Remarks: Up Wt -155k On Wt -145K Block Wt - 70k Supervisor: DON MICKEY ~(;A~~~E~) FED ~6 ~ 20Dt~, Phillips Alaska Drilling Well Name: C01-G4 Rig Name: 00 on 19 Casing Size 95/8 :Centi'allzers èQmments: (~5)12114" x 9 Sl8' t;ft,Î.td èòhïmènts: Hole Diameter: 12.25 Angle thru KRU: Report Date: 10/2512000 AFC No.: 998C11 Shoe Depth: 2727 Cementing Details Report Number: 4 Field: State type used. intervals covered and spacing Ran 1 bowsprlng centralizer per Joint on #'51.12, every other Joint on #'5 14~0. LC Depth: 2646 % washout: Weight: 9.6 Gels before: 30/60/69 PV(prior cond): 25 Gels after: 5/21/27 PV(after cond): 14 Total Volume Circulated: 800 BBlS YP(prior cond): 39 YP(after cond): 16 Type: Water Mix wtr temp: 70 Volume: 40 bbls with Blozan and nutplug for marlter Volume: 50 BBlS No. of Sacks: 435 Additives: 30'/0 0153, 0.6% 0046,1.5% 0079; 1.5% SOO1, 50% 0124. 9.0% BWOW 0044 Mix wtr temp: No. of Sacks: 70 213 Calculated top of cement: Surface Additives: 0.2% 0046, 0.3°,{, 0065, 1.00/. SOO1 . Rate(before tail at shoe): 8.5 BPM Theoretical Displacement: 205 BBlS Rate(tail around shoe): 6BPM Reciprocation speed: 10 fpm CP: Date:10/25/00 Tlme:1300 hrs. Remarks:Full returns throughout, had 48 bbls of 10.7 ppg cement returns to surface. Actual Displacement: 202.7 BBlS Bumped plug: Yes Cement Company: Dowell Rig Contractor: DOYON Weight: 8.4 PPG Weight: 10.5 PPG Weight: 10.7 PPG Yield: 4.44 Weight: 15.8 Yield: 1.17 Str. WI. Up: 155 Str. WI. Down: 135 Str. WI. in mud: Floats held: Yes Approved By: D. Burley AFC No. 888C11 I?ate 110125/2000 Phillips Alaska Drilling RptNo 4 Daily Drilling Report Well: CD1-G4 Depth (MDITVD) Contractor: DOYON Dally Cost $ 293258 Ria Name: Doyon 19 Last Csg: 9 5/8"1!i! 2727' Operation At 0600: Slip and cut drilling line. Upcoming Operations: Test csg., clean out cement, LOT, Drill 8.1/2" hole. I :R19 Accept. hrs Days Since AccepVEst: 3.23 12.9 10l22l2000 06:30:00 PM 2740/2385 Prev Depth MD: 2740 Cum Cost $ 594859 Next Csg: 7" @ 9474' MUD TYPE LSND , ' ':rA\~'~:\~-,"'., , , DEPTH WEIGHT ROT WT 8.5DDa VISCOSITY PUWT 4Csqc PVIYP SOWT 11/ 24 GELS AVG DRAG 14/18 /20 APIWL MAX DRAG 8.6 HTHP WL TRQ BTM mll30 min SOLIDS TRQ OFF 4.5% HOLE VOLUME PUMP PRES 175bbl 350 III MBT PUMP NO 2.5 11211 ph LINER SZ 9.0 5.51611 (GS SPM 1 0.3% III PIT VOL GPM2 450 III DAILY MUD $8761 SPS 1 III TOTAL MUD $22517 COMPANY MI SPP 1 III MUD wr III , ATA~.;' '\,:\1>',',': "':', : ,,:"',!BIT'I'ATA/',; BIT NO. BIT NO. 2 :'~: ",,',' ',:,Et.I&S , ' ' ACCIDENT (non-spill) N SIZE SIZE EMPLOYER 8.5 MAKE MAKE SPILL HYC N TYPE TYPE TYPE DS70FNPV SERIAL NO SERIAL NO VOLUME (gallons) 23368 DEPTH OUT DEPTH OUT LAST SAFETY MTG 10/25/2000 DEPTH IN DEPTH IN ,:'::,;:'ï~~éthl()¡F FOOTAGE FOOTAGE INJECTION WELL CD1-45 ADT/AST ADT/AST SOURCE WELL " / / CD1004 WOB2 WOB2 RATE (bpm) . 3.5 RPM 1 RPM 1 PRESSURE (psi) - 1189 TFA TFA INJECTION FLUIDS .557 Water Base Muds 1497 JETS JETS Cement 11111111111111 11111 48 111 Other 150 BIT COST BIT COST Diesel 100 0 DULL DULL TOTAL VOL (bbl) III III 1795 GRADE GRADE TOT FOR WELL (bbl) III III 28635 Rig Relase . hrs: Progress: 0 Est Cost To Date $ 550000 Shoe Test: Pending :' ,:";;\ ,\?::,;\.',,: ','" ,:,:",D,RlI.:lS, , ~Qp.,:'ÐATA\f;o'S~]v!~' ,~{"'::;::ii-:~:' LAST BOPIDIVERT LAST BOP/DRILL TST 10/14/2000 10/2212000 LAST H2S DRILL 10/0912000 LAST CONFINED SPACE 06/21/2000 ~':i,:\;":':'" :: '.', FUEL USED LAST FIRE DRILL 10/23/2000 LAST SPILL DRILL 10/24/2000 " ,tlJE~ ~"VI~!~~:;:j"r.:::':: "}(: ~1:,{H(: 2400 DRILL WATER USED- BBLS POTABLE WATER USED. BBLS ',.J;: ":'~Ê¡ijW~f[~~Ç~,":;,'.'~ TEMP of 980 100 ':':!":'«,::: ':, ,"~,:~\r:,: 18 WIND SPEED 10 WIND DIRECTION 70° CHILL FACTOR of 1.20 PHILLIPS 1 PERSONNEL CONTRACTOR 25 PERSONNEL MiSe PERSONNEL 5 SERVICE 14 PERSONNEL BBe.~ÐESQ8IP.T.IP ,l.l..!.(~;'~ " TOTAL ,',/ ./:;.~'I Bit. M1XL@1.2, NMSTAB, PONY, PONY, MWD, NMSTAB, 3 NMCSDC, XO, 3 HWDP, JARS, 26 HWDP ,",.:~.,:.; ":-~~~>~~~;J~~~,~~ LAI..~~':;:1~.i~:~':}~~:;:'~,,:/t.{:, : ,;. ",::' "" :" ,:~ '~" ~:,.~.. ,.; "", ':::: D,RI~,L~IP~:¡P~1¡, ~:~\:;~..,:i.,:~~, ~.t{~.,.;~~ \,. :~.:' ,:~".~X;>";:ii~ ;~:'.: ;",:,:~r() ~~,~~.(:'t~ i:'.~;"~~~;!Ý¡:~:~~.::;:'~if:¡~';',1,h~~,.. ,OD ,.:,ID, WEIGHT GRADE,' 'CONNECTIO l : CLASS2, , , ::I;.EN,ßTH': 5 4.281 19.5 G.105 4.1/2 IF Prem BHA NO BHA LENGTH DATE LAST INSPECTED: I HOURS ON JARS: ~IME'~;h":,;i?'END,:>"1 ' 12:00 AM 01 :00 AM 3 1 081.33 81.31 ,HOURS ",OPS CODE,' I' 'J 'HOLE SECT,' 1.00 PRB_HOLE SURF 01:00 AM 02:30 AM 1.50 PRB_HOLE SURF 02:30 AM 06:00 AM 3.50 RUN_CSG SURF 06:00 AM 08:00 AM 2.00 PRB_CSG SURF 08:00 AM 09:30 AM 1.50 RUN_CSG SURF 09:30 AM 10:00 AM 0.50 RUN_CSG SURF 10:00 AM 11:00 AM 1.00 CIRC SURF 11:00 AM 01 :00 PM 2.00 CEMENT SURF 01:00 PM 03:30 PM 2.50 OTHER SURF Daily Drilling Report: CD1-04 10/25/2000 IPHASE,OPS " Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing 45 , r. " ',OPERATlONS'PROM ,0000 ~ OO.O"Q,~,' POH, no problems. . '. \1, ,,<: ,;~ ~'r. Stand back HWDP, laid down BHA, clear tools from floor. Rig up to run casing, PJSM. Run 9.5/8" casing to 1450'. Wash and push casing from 1450' to 1510'. Run casing to 2727' and establish circulation. LD fill up tool and MU cement head. Clrc and cond mud for cementing, PJSM. Pumped 40 bbls of Blozan spacer with nut plug marker and 50 bbls of 10.5 ppg spacer. Cemented casIng with 435 sxs of lead and 213 sxs of tall slurry. Displaced with 20 bbls of FW and 187.2 bbls of mud, bumped plugs, CIP @ 1300 hours. Full returns throughout, had 48 bbls of 10.7 ppg cement returns at surface. Ld cement head and landing Jt.. flushed dlvertor and surface equipment. Page 1 03:30 PM 07:00 PM 3.50 NU_ND 07:00 PM 11:30 PM 4.50 BOPE 11:30 PM 12:00 AM 0.50 OTHER 24.00 SURF SURF SURF Supervisor: D. BURLEY Daily Drilling Report: CD1-04 10/25/2000 Casing and Cementing Casing and Cementing Casing and Cementing ND Dlvertor system-tnstall casing head and test MIM seal to 1000 psI. NU BOPE. RU and test BOPE and Choke manifold valves to 250/3500 psi. Annular to 2500 psi. Pull test plug and Install wear bushing. Page 2 Well Name: ..". .~.....~ . -..... "I.'" . "'.'..I~. .'-'.~ II". -......,.. . Date: .--. CD1-04 10/26/00 Supervisor: D. Burley Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/S", 36#, J-55, BTC CSG Casing Setting Depth: Hole Depth: 2,760' TMD 2,3911 TVD 2,727' TMD 2,3771 TVD Mud Weight: 9.6 ppg 33' Length of Open Hole Section: EMW= Leak-off Press. + Mud Weight = 760 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,377'/ \.r EMW for open hole section = 15.7 ppg ./ Used cement unit Ria DUmD used NO #2 Pump output = 0.0997 bps Fluid Pumped = 1.3 bbls Fluid Bled Back = 1.0 bbls 2,800 ps" 2,700 ps 2,600 ps 2,500 ps 2,400 ps 2,300 ps 2,200 ps 2,100 ps 2,000 ps 1,900 ps 1,800 ps 1,700 ps ~ 1,600 ps ;j 1,500 ps fI) 1 ,400 ps ffi 1,300 ps a: 1,200 ps Q. 1,100 ps 1,000 psi 900 ps 800 ps 700 ps 600 ps 500 ps 400 ps' 300 ps 200 ps' 100 psi 0 psi I I i I . ," ," i i ¡¡,I i I I I I I , ; , , , : .~ I ! ~ ' I , ~ I I' .. , I 1.' '~ I f 1', - ---... II II ; '-............... " ~ ITIME LiNE I , lONE MINUiE TICKS I ß , if -- ." - -- I ..... LEAK-OFF TEST - - .4 ~CASING TEST - " - ; -+- LOT SHUT IN TIME - If --.-CASING TEST SHUT IN TIME - ~ - , ~TIME LINE - I I ~ c- "",. 1 ,p ~~ ,~. ~ 1 ß' w'~ """- I ,., -~ 1 .6r ,,., AI L.Iir 0 10 30 STROKES 20 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r-----------l------Ö------r--opsl-¡ [~~~~=~~~----j~~=~~~~~~~~~~~[==~Ë~C~~~J ! ! 2.0 ! 30 psi! r--------------r----:fõ-----r--iõ-õ-psi--l r--------------r---- 4.Õ-----r--ïõõ-psi-l r--------------T---S:-õ----T-ï80 P-ši-l :..--------------~----------~-------..: ! ! 6.0 ! 340 psi! r---------------r--¡:Õ-----r-410 -psi-l r--------------r----- s.õ--T- 4sõ-psil r---------------r-----g:Õ-----T---S-Š-õ-p-ši--l r-----------1----11f.õ----T--610ps¡--1 ¡-------------r---;fiõ---T---6fops¡-1 ¡-------------r---1-i-Õ-----r---72õpsr-l ~~~~~~~~~~~~!~~~~~~~]~~~~] ¡~:~~~~I~~~::l~~:~:::::j t~~~~~~~~~~~~~~~]~~~~~~~~~~=~~~j~~~==~~~~~~~~~j ! ¡ i ¡ L~~~-'-~~~:.J--------------~~~~~-~~~~_~E L--~~9-~~-.J-------------l--~~Q_p~i_-.J ! 1.0 min ! ! 640 psi! 1------------1---------------..---------------1 ! 2.0 min ! ! 5S0 psi! 1------------1--------------"'----------1 ! 3.0 min ! ! 560 psi! 1--------------""'-----------------"-----------'" L-~:9-~i~.J-_----l-- 540 P-:»J.-.J ! 5.0 min ! ! 530 psi! t-------------I---------------Þ------------1 ! 6.0 min ! ! 510 psi! ....-------~------------~-------------... ! 7.0 min ! ! 500 psi! ",-----------",---------------þ--------------1 L- 8. 9-_~~-J---------------L-~~-~-P-!~-.J ! 9.0 min ! ! 480 psi! [~~~q~~~1~-1=~=~~~~~~==I~=~!ë~~~~J >WCPHILLIPS Alaska, Inc. ~ A Slbsldlaly of PHilLIPS PEmOlElM CCMPAN'I' CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ¡---------------r---Õ-štkš--I-----õ-pšT----¡ ¡---------------¡---ï-štkš---l----:¡4õ-pšr--¡ r--------------l---~ïšikš--T--43õpsr--¡ ¡---------------T-lfštkš--T--73Õj)šï-l r---------------¡--lfštks-1--93Õ-psï-l r--------------¡---:¡Õ-šIks-T-1-;ÕiO psTl r---------------r-12sikš-T-i ,270.pšTl r--------------T--:¡4-šIks-T-1-,450 -psfl ¡---------------¡---:¡6-šIks--r-1-;6iopšï-¡ ¡----------T-:¡ifšIks-T-1;ã-jõ-pšTl ¡----------------¡--:ŽÕ-štks--12;1õõ-pšï-1 r--------------T-2ï-štks--r-ï;34Õ-psil ¡~~~~~~~~~~~~~~~~!~~~~~~~!~~1=~~~~~~~p-~I~1 1------------ ----l---------------l-----------------: I I I I ~ : : : t-- ---- -- -- -- ---- ..--------- ------..----_.. ------ -----4 I f I I I I I I 1------------ ----:.----------- ----~---------_.. ------~ : : : : ~----------------~---------- -----:------ ----- ------: I , I I . . I I ~----------------:.---------------:-----------------: 1------------ ----t---------- -----i------- ----------i I . I t ¡ SHUT IN TIME! SHUT IN PRESSURE r-õ~õ-mfñ--T------------r-2:53-õrjsTI r--1-~õ-ñifñ--T-------------l-:i~Š-:žõ-pšïl r-2~õ-ñifñ---r------------T-2;Š-1Õ-pšTl r-3~õmfñ--l--------------T2,5-'¡õ-pšïl r--;Cõmfñ--T--------------rl;51 0 -pšTl r-- 5.õïlifñ--l--------------T-l;5'¡o psTl r-6~õ-mfñ--T-------------l--l,500 psTl ¡---:rõ-ñifñ--l--------------1-l~šõõ-pš-¡-¡ r--ã~õñifñ--T-------------l-l;500 pšTl r-9~õ-ñifñ--T------------l 2,500 pši-¡ ¡--:fÖ.-Õ-mTñ--¡-------------l-l;šõõpšT¡ ¡---'fŠ:Õ-miñ--r--------------1--2,49Õ-pšT-¡ ¡2'QorTifñ--¡-------------T-i,480 pšTl r-25:Ö-rTiiñl---------------rl,4 jÕ-pšT¡ !~~~~~~~~(~~~I~~~~~~~~~~~~~~~j~~~ð~~~~~~}~~J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY .PHILLlPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Casing Detail 7" Intermediate Casino Well: CD1...04 Date: 10/31/00 \ DEPTH 'Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKS to LDS 34.42 FMC 11" X 7" Hanger 1.69 34.42 Jts 3 to 233 231 Jts 7" 26# L-80 STCM Csg 9322.04 36.11 7" Davis Lynch Float Collar 1.50 9358.15 Jts 1 to 2 2 Jts 7" 26# L-80 STCM Csg 82.20 9359.65 7" Davis Lynch Float Shoe 1.70 9441 .85 9443.55 1 straight blade centralizer per jt #1 - #18 1 straight blade centralizer on #'s 168 & 169 ) and every other jt #171 - #231. I Total - 51 centralizers Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 325k On Wt - 170k Supervisor: David Burley Phillips Alaska Drilling Daily Drilling Report AFC No. I Date RptNo I Rig Accept - hrs Days Since AccepUEst: 9.23/10.1 Rig Relase - hrs: 998C11 10/3112000 10 10/22/200006:30:00 PM Well: CD1-G4 Depth (MDITVD) 9454/6881 Prev Depth MD: 9454 Progress: 0 Contractor: DOYON Dally Cost $ 289452 Cum Cost $ 1526779 Est Cost To Date $ 1706254 Rig Name: Doyon 19 Last Csg: 7H @ 9444' Next Csg: NIA Shoe Test: 15.7 ppg Operation At 0600: MU BHA# 6. Upcoming Operations: RtH, clean out cement, LOT, change over, drill ahead. I~:~MUD DATA DRILLING DATA BIT DATA EH&S ,. "",';",:DRlLLSlBOP. DATA" ',:.: MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-sp'lI) LAST BOPiDIVERT LAST BOP:DRILL LSND 4 N TST 10/27/2000 10/25/2000 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8ppg 6.125 1010912000 10/26/2000 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 41sqc HTC N SPACE 10/29/2000 06121/2000 PVIYP SOWT TYPE TYPE TYPE "t',~'::'~;;:::~::~.;}1~:i:Hl~~M7~~~:~~J.~~?~>';',:;~<:-,ì~;}~;~~1Ù:J:~:: 9/216 STR-386 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2919 6/8/11 1904225 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED. 600 4.8 10/31/2000 BBLS HTHP WL TRO BTM DEPTH IN DEPTH IN POTABLE WATER 95 10.2m1!30 min 9454 INJECTION USED - BBLS SOLIDS TRO OFF FOOTAGE FOOTAGE INJECTION WELL " ,'"WEATHER& " " ,:,::" ~::, 7.5% 0 CD1-42 PERSO'NNEL DÀTA ' HOLE VOLUME rUMP PRES ADT:AST ,'\DT!AST SOURCE WELL TEMP "F .11 358bbl 2600 I I I / / CD1-G4 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 6 19 1121 I - 3.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 1800 9.0 5.51611 - 1100 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of .20.69 4.0% 711711 I 0.69 Water Base Muds 1145 PIT VOL GPM2 JETS JETS Fresh Water PHILLIPS 1 140 250 I 298 I I 15 115115 115 I I I I II I 310 PERSONNEL Diesel 192 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 27 $2920 30140130140 7200 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $119052 350 I 390 I 370 I I I I II I 1647 440 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 18 MI 9.81 I I I II II I 6454 PERSONNEL TOTAL 51 MNP~SCRIP:rIØ~'.:~f}¡~:-:"-"r: <'~:':.I Bit, M1X@1.2, NMSTAB, PONY, MWD, PWD, 3 NMCSDC, 1 HWDP. JARS. 4 HWDP 'W"¡ "::r:~;, ,,/:::;;,:\;,S;,;~;;;- ~;<r:~' :;,~~:¡.;(: /Zi:>iN ;¡ :V';'%' ," ?;,;,''j ":', ,:,:. ':", 'QRIL!.'p'Ip,E'DA TA~:¡:,~,nk'!;\?::::.'!)" \(;;~J:¡¥:: .,~ ~:,>i:,~J¡¡~>::.;'<:'~{,"i\!?3(H) :i:'>~:£.;:?:~'!:,'i':;;¡!t ~~~~;: BHA NO 6 '" OD, ,ID WEIGHT GRADE, " "CONNECTlpN, :,C.L,ASS 2 " " , ." . ,leNGTH:; . . BHA LENGTH 364.68 5 4.281 19.5 G.105 4.1/2 IF Prem DATE LAST INSPECTED: HOURS ON JARS: 0 ,~~';(tME~:""'I">;' END,'.". . ë,HOURS : ,,',:OPS COpe., ,'I' 'HOLE SECT ' .1 PHASE OPS I "Of?ERATIQN ),fROMQOOO,~,.oOOO", " .. 12:00 AM 03:00 AM 3.00 RUN_CSG P1 Casing and Run 7" casing to 4428'. Cementing 03:00 AM 04:00 AM 1.00 CIRC Pi Casing and CBU. Cementing 04:00 AM 06:30 AM 2.50 RUN_CSG P1 Casing and Run casing to 7260'. Cementing 06:30 AM 08:00 AM 1.50 CIRC P1 Casing and Clrc and cond mud. Cementing 08:00 AM 10:00 AM 2.00 RUN_CSG P1 Casing and Run casing to 9444'. Cementing 10:00 AM 12:00 PM 2.00 CIRC Pi Casing and Est. clrc. staged pumps up to 7.5 bpm and cond Cementing mud.PJSM. 12:00 PM 01 :30 PM 1.50 CMT_CSG P1 Casing and Test lines to 3500 psi, pumped 20 bbls of wash, 47 bbls of Cementing 12.5 ppg spacer, and 33 bbls of 15.8 ppg cement. Displaced with rig pumps @ 9.0 bpm, bumped plugs, floats held. CIP @ 13:30 hrs. 01 :30 PM 02:30 PM 1.00 OTHER Pi Casing and LD landing Jt., RD running tools. Cementing 02:30 PM 04:00 PM 1.50 OTHER P1 Casing and Pull wear bushing; Install and test packoff to 5000 psi. Cementing Daily Drilling Report: CD1-04 10/31/2000 Page 1 04:00 PM 05:00 PM 1.00 BOPE Pi Casing and Change top pIpe rams and drive sub on TD. Cementing 05:00 PM 10:30 PM 5.50 BOPE Pi CasIng and Test BOPE-manlfold and surface safety valves 250/3500 Cementing psi. Annular 250/2500 psi. witnessed and approved by Jeff Jones (AOGCC). 10:30 PM 11:00 PM 0.50 OTHER Pi Casing and Install wear bushing. Cementing 11:00 PM 12:00 AM 1.00 BHA PROD Making Hole MU BHA #5. 24.00 Supervisor: D. BURLEY Daily Drilling Report: CD1-04 10/31/2000 Page 2 Well Name: ,...,............'-'..... ~ .....'-". ........... . '-"'. ,....----. . ........ 'II ..... -........ ,.. . CD1-04 Date: 11/1/00 Supervisor: D.Burley Reason(s) for test: 0 Initial Casing Shoe Test ~ Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC X 7" 26# L-BO BTMC Casing Setting Depth: 2,727' TMD 2,377' TVD Mud Weight: 9.7 ppg EMW = Leak-off Press. + Mud Weight 0.052 x TVD Hole Depth: TOC 8,586' TMD 6,399' TVD Length of Open Hole Section: 5,859' = 520 psi 0.052 x 2,377' + 9.7 ppg EMW for open hole section = 13.9 ppg 700 psi 600 psi 500 psi 1 w .1 " 400 pSI ::::I CI) CIJ ~ 300 psi !l. 200 psi 100 psi Pump output = bbls pumped 0 psi 0 10 BARRELS Fluid Pumped = 8.0 bbls Fluid Bled Back = 0.0 bbls ~LEAK-OFF TEST ---CASING TEST -f¡-LOT SHUT IN TIME -.-CASING TEST SHUT IN TIME -+-TIME LINE NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds FOR FOR LOT BBLS PRESSURE CSG TEST STROKES PRESSURE r---------------r-----Õ------r----Õps¡-----¡ r--------------r--õ-s-iks---I-----ö-psr---¡ t---- ------------"'f----------------þ-----------------1 t- ------ --- -----....... -- -- ------ ----..----- ----- -------4 ¡ I 0.5 ! 101 psi i ! ¡ ! i t---------------"------------- --t------------------1 t------- --- ----- -.--_.... ------ ----4 --- - ------- - - - - - - 4 i i 1.0 ! 177 psi! i ¡ i i 1----- -----------1------------- -....----------------""'1 t---------- ------+------------- --4--- -- - ---- -------4 I I 1 5 I 263 . I I I I I L---------------J-------_:.------L------_e~~_~ (J---------------J--------------J-----------------l : : 2.0 : 359 psi - I I : : : r---------------i---------------i------------;--11. ö---------------t---------------i-----------------i : I 2.5 : 399 pSI; I ; : : [~~~~~~~~~~~~]~~~~~~!~~~~~~~I~~~~~~Ë~~~~~~~~~~~~~~~~~~~I~~~~~~~~~~~~~I~~~~~~~~~~~~~~] ¡ ¡ 3.5 ! 520 psi I "'r' ! ¡ ¡ ....---------------"'1--------------- -,..-------------"'1 t---------- ------+--- - - - -- -------4 ------- -------- -- 4 ! i 4.0 ! 510 psi i ! ! ! ¡ 1-----------------1----------------""----------------"'1 t------ ---- ------+- -- - - - -- ---- - --..--- ---- - ---- ----- 4 ¡ : 4.5 i 464 psi ¡ i i i i ....---------------...----------------....----------------.... t--------- ----- -- +------ - --- -- - -- 4- --- ------- ---- -- 4 L--------------L----~:.~------L-_~~_~_e~~_j ¡---------------1--------------j-----------------1 L--------------L----?-:~------L-_~~~_e~~_j L--------------1--------------L---------------1 i i 6.0 i 470 psi; ¡ ¡ ! ! 1----- --- --------...-------------- --....----------------.... t----------- --- --+------ - - - --- --- ..---- -- -- ---- -- ---4 i i 6.5 ! 470 psi! ¡ ! ! ¡ ....---- -----------"1----------------...----------------""'1 t------ --- - - --- -- +- ------ -- ----- -of ---- ---- ---------4 ! i 7.0 i 464 psi i i i i i 1----------------"'-------------- --...-- -------------.... t ----------- -- -- - + - -- - --- -- ------4 --- --- - - -- -------4 ! i 7.5 i 470 psi i ¡ ¡ i i t--- -- --- - -- ------1-------------- --t--- ---------------t t-------------- --+----- -- -- - -- ---4-------------- - --" i i 8.0 i 480 psi i ¡ i ! i I- --- ---- - ------...----------- - ----t---- ---- --------- -t t---- -- - - -- ------+ ---- - --- -- -- ---..---- --- ---- -- -- --1 I I J J I I I I I I 1 I I I I I I I I I I I I I 1-- ------ - -- - -- --...----------- -----....----------- -- ----t t-- - --- -------- -- +----- - -- -- -- - -- 4---- -- ------- -- - - 4 I I I I I I I I I I I I I I I I I I I I I I I I ....- ------- ----- ---1-- - -------------~------- ----- -----t t---- ---- ----- ---+--- -- - -- -- -----4----- -- ------ -- -- 4 I I I I I I I . I I I I I I I I I I I I I I I I 1-- ---------- -- ---1----- --- --------t----- - -- - - -- ------1 ¡ ! ! ! ¡ SHUT IN TIME ¡ SHUT IN PRESSURE 1--------- ---- ----1--- ------ -- - -- --~--- ---- ------ ----1 t-- ----------- ---..- --- --- -- --- -- -..---------- ----- --.. ¡ ¡ ! ¡ ¡ 0.0 min ! ¡ 0 psi: t--------- ---- ---...----------- -- - - -t- - -- - -- - - ---------t t - ---------- -- ---+- -- - --- -- ------4 --- ------- ------ - 4 I I 1 I I 1 0 . I I I : : : :;. mln ; : : 1-----------------1."""...'.".""'"'''''''...1.''.'''""."""""'''''''.''''1.----------------+---------------..-----------------4 : : : : ; 2.0min : : : I I I I I I I I t --------------- -..- -- -- - ------- - - 4--------- ----- - - - 4 i---~:.g_!!!~~-- -1---- - - -- - ------1- -- - ------ -- - ---- j ¡ 4.0min ¡ ¡ ¡ t----------------+----- --- ------- ..---- ----- ---- ----1 ¡ 5.0min ! ! ! ~-----------:-----r ---- ---- -------1--------- ---- ----, : 6.0 mln : : : .. ----------------+---- --- -- ------4 --- - -- - -- -------- 4 L--T-:g-!!!~~--.l---------------1-----------------1 ¡ 8.0min ¡ ! ¡ t --------- -- -- ---+ ---------------of------------- -- -.. ¡---~:g_!!!~~--.l---------------L---------------j L-!.9_:.~_~i_~--L-------------L--------------j ¡ 15.0 min ¡ ¡ ¡ t------------- -- ,.--- ------------ 4------------ - ----.. ! 20.0 min ! ! ¡ t----------------+ ------- -- ------4------ --------- --.. ¡ 25.0 min ¡ ! ! t-------------- - ,.---- ---- -------4---- ----------- -- 4 L_~9_.g_~i_~--L______------j--------------_--1 LEAK-QFF DATA MINUTES 20 L-~~_~!_I~.:I~:.L-------------~}~~~~~-~~~~~.E L_2:9.._~!~---L------------l--~~gJ?~i---J ¡ 1 .0 min ! ! 369 psi! .... ---------------"1--------------- -t------------------'I ¡ 2.0 min ¡ ! 359 psi ¡ [~~~~9-~I~~~~J~~~~~~~=~~~~~~I~~~~~~~~Ë~~~~J L-:!:9..-~!~--L--------------L-_~~_~_e~i__-J L-~:9..-~!~---L-------------L--~~-~_e~~__j L-§:9..-~!~---L--------------L-_~~_~e~~--J ¡ 7.0 min ¡ ¡ 333 psi! ,..--------------...- ---- - ----------t------------------t L-~:9..-~!~---L--------------L-_~~_~_e~~--J ! 9.0 min ¡ ¡ 323 psi! [~~!2~9~~!~~~]~~~~~~~~~~~~~~~I~~~!~~~~Ë~I~~J li'¡?}i\~HILLI~ti AlaSKa, Inc. ~ A Slbsldlary or PHILLIPS PETROlELM COMPANY CASING TEST DATA MINUTES NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ConocOPhiilips Alaska P,O. BOX :100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD 1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16n, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment GANNED APR 5 2003 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS BBLS Cement CD1-1 2.25' 0.3 WI 1.8 CD1-2 4' 0.6 WI 3.6 CD1-3 10' 1.4 MI 8.5 CD1-4 7.33' 1 P 6.0 CD1-5 4' 0.6 MI 3.6 CD1-6 10.42' 1.4 Gl 8.5 CD1-16 14.33' 2 WI 12.1 CD1-17 8.75' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 CD1-22 1.83' 0.3 P 1.8 CD1-23 15.42' 2.1 MI 12.7 CD1-24 2' 0.3 P 1.8 CD1-25 5.66' 0.8 P 4.8 CD1-27 18.83' 2.6 P 15.7 CD1-28 6.75' 1 P 6.0 CD1-32 8.33' 1.2 P 7.2 CD1-34 41.83' 5.7 P 34.4 CD1-36 16.75' 2.3 WI 13.9 CD1-38 3.5' 0.5 P 3.0 CD1-42 5.83' 0.8 MI 4.8 CD2-16 11.66' 1.6 INJ 9.7 CD2-17 18' 2.5 INJ 15.1 CD2-19 11.66' 1.6 P 9.7 CD2-22 13.5' 1.8 INJ 10.9 CD2-25 27.25' 3.7 P 22.3 CD2-26 10.42' 1.4 INJ 8.5 CD2-32 8.5' 1.2 INJ 7.2 CD2-33 --- - 7' 1 P 6.0 CD2-34 4' 0.6 P 3.6 CD2-41 11.83' 1.6 P 9.7 CD2-46 7.42' 1 INJ 6.0 CD2-48 10.33' 1.4 INJ 8.5 CD2-49 9.33' 1.3 INJ 7.8 CD2-50 1.66' 0.25 P 1.5 Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n 1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual 404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this > kind of work. Due to the number of these, is a 10-404 needed on each well? > I don't want to commit the time to doing this if it is not necessary; > 10-404's are time consuming to prepare. Would a list of the jobs suffice, > or something similar? We have the well numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future · submissions of 10-404's for this work. What do you think? Thanks! · Jerry Dethlefs (See attached file: tom_maunder.vcf) 5C;ANNE 5 20133 1 of 2 4/24/2003 7:55 AM __AOGCCALPINE cement top outs 04-16-03.xls Name: AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 IDCement Top Fill AOGCC Letter 04-23-03.doc Name: Cement Top Fill AOGCC 04-23-03.doct Letter Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder~,admin.state, ak. us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission SCANNED APR ~ 5 21:)03 2 of 2 4/24/2003 7:55 AM Permit to Drill 200117'0 MD 13977 --'"'~ TVD DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. COLVILLE RIV UNIT CDt-04 6897 Completion Dat 11/8/2000 /Operator CONOCOPHILLIPS ALASKA INC / . Completi Statu 1-OIL Current Status 1-OIL APl No. 50-t03-20346-00-00 UIC N ._ . REQUIRED INFORMATION Mud Log N._.~o Sample N._~o Directional Survey N._~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name (data taken from Logs Portion of Master Well Data Maint R R Interval Log Log Run OH I Dataset Scale Media No Start Stop CH Received Number Survey Report 1/9/2001 Comments Surface to TD Pa'i~ R--ep~3-d~' i L L L L C Array Res MD ~ 2/5 ,_..- Array Res 'I'VD ~ 2/5 comp 2727 13977 CH 1/4/2001 comp 2727 13977 CH 1/4/2001 2726 13977 Case 1/312001 FINAL 2726 13977 CH 1/4/2001 2727-13977 BL, Sepia 2727-13977 BL, Sepia 09850/--~Z726-13977 (~ ~o.~ 985~6-13977 Digital Data Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y ! N R~.c.~.iv~.d ? Daily History Received? Y / N Formation Tops ~f~) N Comments: Compliance Reviewed By: . Date: MEMORANDUM TO: THRU: c:~ State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, ~~,. ~\ DATE: March 30, 2001 Commissioner Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Colville River Unit CD1 Pad Friday. March 30. 2001' I traveled to the Phillips Alaska's Alpine Field and _ witnessed a portion of the safety valve system tests on CD1. As the attached AOGCC, Safety Valve System Test Report indicates I witnessed the testing of 8 wells and 24 components with no failures observed. The Rosemount Iow-pressure switches (located in the manifold building) performed very well tripping at the set point on all wells tested. The surface safety valves .on .these wells operate very Slowly. probably due to.,being exposed to the elements and the length of. the . . control ,. ,l i ne from the hyd pane! to' the wellhead. '""" Gary Saltenreick conducted the testing today he demonstrated a good working' knowledge of the system and was a pleasure to work with. Summ'a, ry: I witnessed a portion of the semi-annual SVS testing at the CD1 Pad in the Alpine Field. . CRU CD1 Pad, 8 wells, 24 components, 0 failures Attachment: svs CRU CD1 Pad 3-30-01 CS , X, Unclassified Confidential (Unclassified if doc. Removed) SVS CRU CD1 3-30-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Jack Kralick ^oc c di ue Submitted By: Chuck Scheve Field/Unit/Pad: Alpine/CRU/CD1 Separator psi: LPS 143 Date: 3/30/01 HPS I I i ii i i I i I . i ii g~ll~~ I_l _1 J i i ii I __ "..': ?... We.~. Data?-."i'i::.;:/'. .." ' .".,/: ."?i:.":.': '.'..:."'." ~ ..... ..51 l~io'tS~. '~:' .i': '...'..:~.,,.::::.'.~7. !!:...(. '.?SSV:'; /...'..'Retest... ..'; Welt Type I I! I IIII I I I , i II , i ........ Well" Permit Separ Set L/P Test Test Test Date Oil, WAG, am,I, Numbe,r, .... Number , PSI PSI , Trip, Code Code, Code, Passed , G,~s or CV,C,,L,g CDI'01 1990460 CDi-06 '" 200083'0 ........ ' - ! , , ~ ,,n, ! , , ! , i , CDI-09 2OOO71O cD1-'13 '1990520 ............ _ . CDI-16 1990940 CDI'-17 2001450 '14J ' 100 .... 100 ' P ...... 1~' ' P ' oIL _ CD1-52A 36611o6 ' 143 ' 10b 100 P .... P P .... OiL · CD1-24 1990260 143 100 J00 ' -P "P ..... P ........... OIL .. CD1~25 2000080 '143' "' 00 ' P .... P' P ........ 0ic CD1-27 2000060 , , .... s , !, . . ..... ~ , · , ........ CD1-30 2001320 ' , . ..... ~ .................... _ . . :. . -._.._ cD1-32 1991040 ,CD1-34 2000430 ' :cD'1-35 ' 1990380 .... i43 ' 106" i00 'P "' P ' Ii. ' ' 0IL CD1-3g 2000030 _ CD1'40 1996~6 ..................... CD1-41 2000170 CD~243 ' 260~060 ................. - '- . .i i , i t i i , i i il ,, i i, .1_ _ J i i i CD1-44 ., 2000550 ..... , , , I , I I Il i I Il. I I I I ' CD1-04 '" 2001170 143 100 100 P P P ' OIL CDI-10 2001710 143 100 100 P P P OIL CD1-29 ....... 143" .... 100 '' '100 "P'' P P' : .... : ' OIL Wells: 8 Components: 24 Failures: 0 Failure Rate: 0.00% EJ~o var Remarks: RJF 1/16/01 Page 1 of 1 010330-SVS CRU CD1-CS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~ Gas [~ Suspended r-~ Abandoned D Se,ice 2. Name of Operator =7. Permit Number Phillips Alaska, Inc. 200-117 3. Address .8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~r 50-103-20346-00 4. Location of well at surface ~tl~r-,a=m 9. Unit or Lease Name .... ~ ..'-':~uh ~ Colville River Unit 243' FNL, 2551' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385979, 5975884) At Top Producing Interval _/_.~.: .~'~'.~.._. ~C)~';' -- ~ 10. Well Number 2003' FNL, 1453' FWL, Sec. 33, T12N, RSE, UM (ASP: 390200,5979342)! -~ = · CD1-04 At Total Depth ~ ~. ,. ....... ~.~ ; k. !11. Field and Pool 833' FNL, 1589' FEL, Sec. 4, T11 N, R5E, UM (ASP: 392388, 5975199)~i ....................... ..... -.~.~) ........ _.,.~ Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 56 feetI ADL 25557 / ALK 372095 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. ~15. Water Depth, if offshore 16. No. of Completions October 22, 2000 November 6, 2000 November 8, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey ~20. Depth where SSSV set 21. Thickness of Permafrost 13977' MD/6897'TVD 13977' MD/6897'TVD YES r~ No DI 1796, feetMD 1617' 22. Type Electric or Other Logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" lO cu yds Portland Type 3 9.625" 36# J-55 Surface 2727' 12.25" 435 sx AS III L & 213 sx Class 7" 26# L-80 Surface 9444' 8.5" 161 sx Class 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 9083' 8994' Open Hole completion 6.125" OH from 9444'-13977' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A a7. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 9, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~GAS-OIL RATIO 1/9/2001 4.0 Test Period · 8360 4590 344 60I 911 Flow Tubing Casing Pressure Calculated OIL-BBL ~3AS-MCF WATER-BBL OIL GRAVITY - APl (corr) Ipress. 749 psi not available 24-Hour Rate · 1459 801 60 not available ~28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A JAN 1 9 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGIn!Al ..... Submit in duplicate 29. " 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tasted, prassure data, all fluids recoverecl and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Alpine D 9242' 6848' Alpine 9288' 6859' Base Alpine 13927' 6897' N/A 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the bast of my knowledge. Quastions? Call Scoff Reynolds 265-6253 Signed ~/._~~ ~.~ ~ Title Alpine Drillinfl Team Leader Date G. C. Alvord Prepared by Sharon AIIsup-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. RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 JAN i 9 2001 Alaska Oil & Gas Cons. Commission Anchorage Date: 01/08/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-04 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: ALPINE SPUD:10/22/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20346-00 10/22/00 (D1) MW: 8.7 VISC: 300 PV/YP: 13/82 APIWL: 0.0 TD/TVD: 171/171 ( 171) DRLG AT 950' SUPV:MICKEY / LUTRICK Move rig off CDi-17. Set diverter on CD1-04. Move rig over CD1-04. NU diverter and test to 400 psi. Function test diverter system. Held pre-spud meeting. Drill 12.25" hole from 114' to 171' 10/23/00 (D2) MW: 9.6 VISC: 150 PV/YP: 15/33 APIWL: 12.0 TD/TVD: 2740/2385 (2569) RUNNING 9 5/8" CSG SUPV:MICKEY Drill 12-1/4" hole from 171' to 2740'. Pump sweep and circ bttms up, flow check. Wiper trip from 2740' to 1610', flow check. RIH from 1610' to 2740' 10/24/00 (D3) TD/TVD: 2740/2385 ( SUPV:MICKEY MW: 9.8 VISC: 150 PV/YP: 25/38 0) RUNNING 9 5/8" CSG APIWL: 10.0 Pump sweep & circulate bottoms up. POOH to run 9-5/8" casing. PJSM. Ran 9-5/8" casing. Work and wash casing from 788' to 975', unable to work past 975'. Circ, pump slug, prep to pull casing, PJSM. RIH with hole opener assembly to 780'. Ream from 780' to 1102', hole slick. RIH from 1102' to 2740', hole slick. Circ sweep and condition mud. Flow check, pump slug. 10/25/00 (D4) TD/TVD: 2740/2385 ( SUPV:D. BURLEY MW: 9.5 VISC: 44 PV/YP: 11/24 0) SLIP AND CUT DRILLING LINE. APIWL: 6.6 POH, no problems. Rig up to run casing, PJSM. Run 9-5/8" casing to 1450'. Wash and push casing from 1450' to 1510'. Run casing to 2727' and establish circulation. Circ and cond mud for cementing. PJSM. Pumped cement. ND diverter system. NU BOPE and test BoPE to 250/3500 psi. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Date: 01/08/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 10/26/00 (D5) MW: 9.6 VISC: 44 PV/YP: 8/20 TD/TVD: 4075/3315 (1335) DRILLING AHEAD ~ 4490'. SUPV:D. BURLEY APIWL: 6.0 Held kick drill. PJSM. Held stripping and well kill drills. Tagged cement @ 2620', cleaned out to 2636' and cond cement contaminated mud. Tested 9-5/8" casing to 2500 psi. Clean out cement to 2720' Change well over to 9.6 ppg LSND mud. Cleaned out cement and drilled 20' of new hole to 2760' CBU. Performed LOT, EMW = 15.7 ppg. Drill from 2760' to 4075' 10/27/00 (D6) MW: 9.8 VISC: 42 PV/YP: 9/16 TD/TVD: 6407/4954 (2332) DRILLING AHEAD FROM 7073' SUPV:D. BURLEY APIWL: 6.0 Drill from 4075' to 4313' Pumped high vis sweep and circ clean. Monitor well, wiped hole to shoe, no problems. RIH, precautionary wash last 90'. Drill from 4313' to 6407' Pumped high vis sweeps and circ hole clean, monitor well. Wiped hole to 4218', pulled through tight spots from 5742' to 5362'. RIH. Precautionary wash from 6317' to 6407', pumped high vis sweep. 10/28/00 (D7) MW: 9.7 VISC: 43 PV/YP: 9/20 APIWL: 5.4 TD/TVD: 8215/6212 (1808) DRILLING AHEAD FROM 8260'. SUPV:D. BURLEY Circ high vis sweep around. Drill from 6407' to 8215' Pumped high/low/high vis sweeps and circ clean, monitor well. POH to 6312', monitor well, pump dry job. POH to bha. 10/29/00 (D8) MW: 9.8 VISC: 42 PV/YP: 10/20 APIWL: 4.0 TD/TVD: 9093/6795 ( 878) DRILLING AHEAD FROM 9290'. SUPV:D. BURLEY RIH to 8115'. Pump high vis sweep and precautionary wash down to 8215'. Drill from 8215' to 9093'. 10/30/00 (D9) MW: 9.7 VISC: 40 PV/YP: 7/15 TD/TVD: 9454/6881 (.361) RUNNING 7" CASING FROM 6800' SUPV:D. BURLEY APIWL: 4.4 Drill from 9093' to 9454'. Pump high/low/high vis sweeps and circ clean. Monitor well, POH to 7800'. RIH, precautionary wash last 90'. Pump high/low/high vis sweeps and circ hole clean. POH to 8660', pump dry job. POH to 3450'. RU to run casing, PJSM, run 7" casing. 10/31/00 (D10) MW: 9.8 VISC: 41 PV/YP: 9/216 APIWL: 4.8 TD/TVD: 9454/6881 ( 0) MU BHA ~ 6. SUPV:D. BURLEY Run 7" casing ro 9444'. PJSM. Pump cement. Bumped plugs, floats held. Test packoff to 5000 psi. Test BOPE to 250/3500 psi. RECEIVED JAN 1 9 ?00? Alaska Oil & Gas Cons. Commission Anchorage Date: 01/08/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 11/01/00 (Dll) MW: 9.2 VISC: 51 PV/YP: 11/25 TD/TVD: 9558/6884 (104) DRILLING PRODUCTION HOLE FROM 9916' SUPV:D. BURLEY APIWL: 3.2 RIH. Attempted to shallow test tool, no good. POH. Change out MWD/LWD tools and shallow test @ 150'. RIH to 1000' and shallow test tools, OK. RIH. Cleaned out cement stringers from 9258' to 9330'. Test casing to 3500 psi. Cleaned out cement and float equipment, drilled 20' of new hole to 9474'. CBU and cond mu. Performed FIT to 12.5 ppg EMW. Changed well over to 9.2 ppg Flo-Pro drill-in fluid. Drill from 5474' to 9558' 11/02/00 (D12) MW: 9.2 VISC: 50 PV/YP: 10/26 TD/TVD:ll146/6898 (1588) DRILLING PRODUCTION HOLE FROM 11,580' SUPV:D. BURLEY Drill from 9558' to 11146' APIWL: 3.6 11/03/00 (D13) MW: 9.2 VISC: 50 PV/YP: 10/24 APIWL: 3.2 TD/TVD:12249/6898 (1103) POH FOR MWD FAILURE. SUPV:D. BURLEY / D. CUNNINGHAM Drill from 11140' to 12001'. Pumped low/high vis sweeps and circ clean, monitor well. Pump out to 9410', no problems. Monitor well, replace control switches on iron roughneck. RIH, no problems. Drill from 12001' to 12249'. MWD failed, trouble shoot MWD, failed. CBU. 11/04/00 (D14) MW: 9.2 VISC: 51 PV/YP: 10/27 APIWL: 3.2 TD/TVD:12350/6898 (101) DRILLING F/12,755' SUPV:D. BURLEY / D. CUNNINGHAM Pump out to 8970'. Monitor well, static. Pull 5 stds, well not taking fluid. CBU, monitor returns, no problems. Pump out from 8585' to 7623'. Monitor well, static. POH. CO MWS tools. RIH to 1323', test MWD, OK. RIH. Tag up ~ 9535', back ream to shoe. Ream under gauge hole to 9600'. Attempted to RIH, unable. Gauge ream from 9600' to 12246' Drill from 12246' to 12350'. 11/05/00 (D15) MW: 9.2 VISC: 52 PV/YP: 11/28 APIWL: 3.0 TD/TVD:13809/6898 (1459) DRILL TO PLANNED TD OF WELL/PUMP SWEEPS & WIPER TRIP SUPV:D. BURLEY / D. CUNNINGHAM Hold PJSM. Drill from 12350' to 13104'. Hold PJSM. Drill from 13104' to 13809' 11/06/00 (D16) MW: 9.2 VISC: 29 PV/YP: 0/ 0 TD/TVD:13977/6897 (168) RUNNING 4 1/2" COMPLETION ASSEMBLY. SUPV:D. BURLEY APIWL: 0.0 Drill from 13809' to 13977'. Pump high/low/high vis sweeps and circ clean. Monitor well, pump out to 11887', RIH, no problems. Pump sweeps and circ hole clean. PJSM. Change well over to KC1 brine. POH to 12087'. Pumped Flo-Vis pill and displaced into open hole. POH to 9409'. POH. 11/07/00 (D17) MW: 9.6 VISC: 29 PV/YP: 0/ 0 APIWL: 0.0 RECEIVED JAN 1 9 ZOO! Alaska Oil & Gas Cons. Commissidn TD/TVD:13977/6897 ( 0) MOVING RIG TO WELL CD1-02. SUPV:D. BURLEY POH. PJSM. RIH with completion assembly. ND BOPE, NU tree and test to 5000 psi. Set packer, test tubing to 3500 psi. Pumped brine down tubing, begin pumping diesel for freeze protection. 11/08/00 (D18) MW: 0.0 VISC: 29 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:13977/6897 ( 0) MOVING RIG TO WELL CD1-02. SUPV:D. BURLEY Displaced tubing and freeze protected 4.5" x 7" annulus to 2000' TVD with diesel. Released rig @ 0300 hrs. 11/8/00. RECEIVED JI N 1 ?..001 Alaska Oil & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey report 6-Nov-2000 03:15:02 Page 1 of 6 Client ................... : Phillips Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-04 API number ............... : 50-103-20346-00 Engineer ................. : Galperin COUNTY: .................. : Doyon 19 STATE: ................... : Alaska Spud date ................ : 22-0ct-2000 Last survey date ......... : 06-Nov-00 Total accepted surveys...: 141 MD of first survey ....... : 0.00 ft MD of last survey ........ : 13977.00 ft Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 55.80 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point .... Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 151.88 degrees [ (c)2000 Anadrill IDEAL ID6_lB_48] Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 25-0ct-2000 Magnetic field strength..: 1147.18 HCNT Magnetic dec (+E/W-) ..... : 25.60 degrees Magnetic dip ............. : 80.54 degrees MW/) survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.18 HCNT Reference Dip ............ : 80.54 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.61 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.61 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 6-Nov-2000 03:15:02 Page 2 of 6 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) Course length (ft) TVD Vertical Displ depth section +N/S- (ft) (ft) (ft) Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 1 0.00 0.00 0.00 0.00 2 114.00 0.00 0.00 114.00 3 262.00 1.25 85.00 148.00 4 445.00 3.75 104.00 183.00 5 563.61 6.54 94.02 118.61 · 6 629.00 8.27 83.87 65.39 7 743.00 10.81 75.28 114.00 8 834.00 12.50 73.50 91.00 9 917.00 14.43 71.30 83.00 10 1013.00 17.52 65.78 96.00 0.00 0.00 0.00 114.00 0.00 0.00 261.99 0.63 0.14 444.80 5.43 -1.13 562.92 11.63 -2.55 627.77 15.37 -2.30 740.19 20.92 1.29 829.31 24.88 6.25 910.03 28.38 12.12 1002.31 31.32 21.89 0.00 0.00 1.61 9.40 19.91 28.30 46.80 64.49 82.90 107.42 0.00 0.00 1.61 9.47 20.07 28.39 46.81 64.80 83.78 109.63 0.00 0.00 TIP 0.00 0.00 MWD 85.00 0.84 MWD 96.87 1.42 MWD 97.29 2.46 MWD 94.66 3.31 MWD 88.42 2.55 MWD 84.46 1.90 MWD 81.68 2.41 MWD 78.48 3.58 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 11 1105.00 20.97 58.13 92.00 12 1203.00 23.70 54.34 98.00 13 1297.00 25.14 53.49 94.00 14 1393.00 27.02 51.82 96.00 15 1487.00 29.67 46.82 94.00 1089.17 31.19 36.27 1179.82 27.46 57.01 1265.40 22.06 79.91 1351.63 15.28 105.52 1434.36 5.50 134.65 134.04 164.94 196.34 229.88 263.64 138.86 174.52 211.98 252.94 296.03 74.86 4.64 MWD 70.93 3.15 MWD 67.85 1.58 MWD 65.34 2.10 MWD 62.94 3.78 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 16 1583.00 31.54 40.14 96.00 17 1679.00 31.76 41.09 96.00 18 1775.34 33.53 41.13 96.34 19 1869.00 37.29 42.04 93.66 20 1966.00 40.25 42.45 97.00 21 2059.00 42.21 42.46 93.00 22 2156.00 43.88 43.07 97.00 23 2250.00 44.13 43.87 94.00 24 2345.00 45.05 44.62 95.00 25 2442.00 45.35 45.14 97.00 1517.01 -9.98 170.12 1598.73 -28.25 208.35 1679.85 -46.67 247.51 1756.17 -65.47 288.08 1831.79 -85.88 333.03 1901.73 -106.26 378.25 1972.62 -127.94 426.86 2040.23 -148.56 474.25 2107.88 -168.76 522.02 2176.23 -188.88 570.79 297.16 329.95 364.12 400.15 440.99 482.36 527.32 572.25 618.78 667.35 342.41 390.23 440.28 493.06 552.61 612.98 678.43 743.22 809.56 878.15 60.21 4.04 MWD 57.73 0.57 MWD 55.79 1.84 MWD 54.25 4.05 MWD 52.94 3.06 MWD 51.90 2.11 MWD 51.01 1.77 MWD 50.35 0.65 MWD 49.85 1.12 MWD 49.46 0.49 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 26 2537.00 44.95 46.30 95.00 27 2632.00 45.31 45.67 95.00 28 2679.00 45.72 44.16 47.00 29 2815.00 45.72 42.75 136.00 30 3005.00 45.33 41.60 190.00 [ (c)2000 Anadrill IDEAL ID6_lB_48] 2243.23 -207.63 617.81 2310.26 -226.07 664.59 2343.19 -235.85 688.34 2438.14 -266.63 759.02 2571.26 -312.33 859.48 RECEIVED JAN 1 9 ZOO1 715.56 763.98 787.65 854.62 945.64 945.37 1012.60 1046.04 1143.01 1277.87 49.19 0.96 MWD 48.98 0.60 MWD 48.85 2.45 MWD 48.39 0.74 MWD 47.73 0.48 MWD 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 6-Nov-2000 03:15:02 Page 3 of 6 Seq Measured Incl Azimuth Course S depth angle angle length - (ft) (deg) (deg) (ft) 31 3194.55 45.88 44.13 32 3386.00 46.23 43.57 33 3576.00 46.50 44.01 34 3767.00 46.08 43.09 35 3957.00 45.08 42.14 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 189.55 2703.88 -356.44 958.73 1037.77 1412.85 191.45 2836.74 -399.11 1058.14 1133.27 1550.47 190.00 2967.85 -441.80 1157.41 1228.43 1687.79 191.00 3099.84 -485.22 1257.47 1323.55 1825.65 190.00 3232.82 -529.98 1357.32 1415.44 1961.07 36 4147.00 45.06 43.81 190.00 3367.01 -573.56 1455.73 1507.13 2095.37 37 4338.00 44.40 41.66 191.00 3502.71 -617.63 1554.44 1598.34 2229.57 38 4528.00 46.50 43.53 190.00 3636.00 -662.30 1654.08 1690.00 2364.76 39 4717.00 46.39 42.75 189.00 3766.23 -706.31 1754.02 1783.66 2501.60 40 4909.00 45.51 43.55 192.00 3899.72 -750.62 1854.70 1878.03 2639.49 41 5100.00 45.11 42.46 191.00 4034.05 -794.54 1953.99 1970.64 2775.16 42 5290.00 44.68 41.88 190.00 4168.65 -839.77 2053.38 2060.67 2909.08 43 5480.00 45.98 42.59 190.00 4302.22 -885.19 2153.42 2151.50 3044.04 44 5670.00 46.98 43.56 190.00 4433.06 -929.59 2254.05 2245.60 3181.74 45 5860.00 46.02 43.40 190.00 4563.84 -973.09 2354.05 2340.44 3319.52 46 6050.00 45.05 42.97 190.00 4696.93 -1016.55 2452.92 47 6242.00 43.76 42.74 192.00 4834.09 -1060.34 2551.40 48 6432.00 43.97 42.56 190.00 4971.08 -1103.70 2648.24 49 6622.00 44.85 42.12 190.00 5106.80 -1148.18 2746.52 50 6812.00 46.27 40.63 190.00 5239.84 -1195.71 2848.32 51 7002.00 46.63 39.75 190.00 5370.74 -1246.61 2953.51 52 7193.00 45.88 42.55 191.00 5502.82 -1295.46 3057.41 53 7383.00 45.91 41.74 190.00 5635.06 -1341.53 3158.56 54 7573.00 46.02 43.68 190.00 5767.14 -1386.37 3258.92 55 7765.00 46.01 42.71 192.00 5900.48 -1430.63 3359.63 56 7955.00 46.29 42.83 190.00 6032.10 -1475.49 3460.22 57 8145.00 45.88 43.54 190.00 6163.89 -1519.36 3560.02 58 8267.00 46.50 41.72 122.00 6248.35 -1548.39 3624.79 59 8328.00 46.80 42.96 61.00 6290.22 -1563.23 3657.58 60 8362.00 47.23 45.38 34.00 6313.40 -1570.79 3675.41 [ (c)2000 Anadrill IDEAL ID6_lB_48] 2433.23 2524.61 2613.81 2703.36 2793.01 2881.87 2972.63 3064.18 3156.82 3251.38 RECEIVED 3344.42 3438.09 3497.70 3527.58 3544.91 JAN I 9 ZOO1 Alaska Oil & Gas Cons. Commission Srvy tool type 47.27 1.00 MWD 46.96 0.28 MWD 46.71 0.22 MWD 46.47 0.41 MWD 46.20 0.64 MWD 45.99 0.62 MWD 45.80 0.86 MWD 45.62 1.31 MWD 45.48 0.30 MWD 45.36 0.55 MWD 3455.06 3589.33 3720.91 3853.77 3989.21 45.24 0.46 MWD 45.10 0.31 MWD 44.97 0.73 MWD 44.89 0.64 MWD 44.83 0.51 MWD 4126.55 4264.30 4400.65 4537.19 4675.32 44.77 0.54 MWD 44.70 0.68 MWD 44.63 0.13 MWD 44.55 0.49 MWD 44.44 0.93 MWD 4812.30 4949.16 5037.16 5081.50 5106.37 44.30 0.39 MWD 44.19 1.13 MWD 44.13 0.31 MWD 44.09 0.74 MWD 44.06 0.36 MWD 44.03 0.15 MWD 44.00 0.35 MWD 43.98 1.19 MWD 43.96 1.56 MWD 43.96 5.36 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 6-Nov-2000 03:15:02 Page 4 of 6 Seq Measured Incl Azimuth Course TVD Vertical # depth angle angle length depth section - (ft) (deg) (deg) (ft) (ft) (ft) 61 8422.00 46.87 54.18 60.00 6354.33 -1579.99 62 8457.00 46.06 59.81 35.00 6378.45 -1582.15 63 8488.00 45.36 64.60 31.00 6400.10 -1582.03 64 8517.00 45.48 68.09 29.00 6420.46 -1580.43 65 8551.00 45.32 70.93 34.00 6444.33 -1577.21 66 8582.00 45.44 73.90 31.00 67 8612.00 45.81 76.69 30.00 68 8646.00 45.76 80.73 34.00 69 8677.00 45.45 83.80 31.00 70 8707.00 45.27 89.22 30.00 71 8741.00 44.57 94.61 34.00 72 8773.00 45.93 97.79 32.00 73 8806.00 47.29 101.64 33.00 74 8839.00 48.93 104.83 33.00 75 8870.00 50.66 107.59 31.00 76 8900.00 51.90 111.06 77 8932.00 53.09 114.47 78 8965.00 54.23 118.53 79 8995.00 55.90 122.09 80 9032.00 58.01 125.50 30.00 32.00 33.00 30.00 37.00 81 9062.00 59.58 129.10 30.00 82 9090.00 61.90 130.29 28.00 83 9123.00 64.51 133.21 33.00 84 9156.00 67.16 135.30 33.00 85 9183.00 68.52 136.35 27.00 86 9217.00 70.63 138.02 34.00 87 9248.00 73.09 140.23 31.00 88 9279.00 75.78 141.43 31.00 89 9311.00 78.36 142.66 32.00 90 9343.00 80.62 145.34 32.00 [ (c)2000 Anadrill IDEAL ID6_lB_48] Displ Displ Total +N/S- +E/W- displ (ft) (ft) (ft) 3703.72 3578.37 5149.98 3717.54 3599.63 5174.69 3727.89 3619.24 5195.77 3736.17 3638.16 5214.90 3744.65 3660.83 5236.80 6466.11 -1573.18 3751.31 3681.86 5256.27 6487.09 -1568.20 3756.75 3702.60 5274.69 6510.81 -1561.15 3761.52 3726.48 5294.88 6532.50 -1553.44 3764.50 3748.43 5312.46 6553.58 -1544.55 3765.80 3769.72 5328.42 6577.67 -1532.55 3765.01 3793.70 5344.85 6600.20 -1519.73 3762.55 3816.28 5359.17 6622.87 -1505.02 3758.49 3839.91 5373.19 6644.91 -1488.79 3752.86 3863.81 5386.37 6664.92 -1472.24 3746.25 3886.54 5398.11 6683.69 -1455.00 3738.50 3908.62 5408.67 6703.18 -1435.31 3728.67 3932.02 5418.83 6722.74 -1413.64 3716.81 3955.80 5427.98 6739.92 -1392.69 3704.39 3977.02 5435.00 6760.10 -1365.33 3687.14 4002.78 5442.17 6775.65 -1342.00 3671.59 4023.18 5446.70 6789.33 -1319.38 3655.98 4041.97 5450.12 6804.21 -1291.72 3636.37 4063.94 5453.33 6817.72 -1263.03 3615.36 4085.50 5455.46 6827.90 -1239.00 3597.42 4102.92 5456.68 6839.77 -1208.18 3574.05 4124.57 5457.65 6849.42 -1179.46 3551.77 4143.84 5457.70 6857.74 -1150.15 3528.62 4162.70 5457.04 6864.90 -1119.42 3504.03 4181.88 5455.86 6870.73 -1088.26 3478.58 4200.37 5453.77 RECEIVED JaN 1 9 ZOO1 Al~..ka Oil & Gas Cons. Commission At DLS Srvy Azim (deg/ tool (deg) 100f) type 44.01 10.75 MWD 44.08 11.89 MWD 44.15 11.29 MWD 44.24 8.58 MWD 44.35 5.97 MWD 44.46 6.83 MWD 44.58 6.76 MWD 44.73 8.52 MWD 44.88 7.15 MWD 45.03 12.87 MWD 45.22 11.38 45.41 8.24 45.61 9.43 45.83 8.74 46.05 8.80 46.27 9.93 MWD 46.52 9.23 MW/) 46.78 10.49 MWD 47.03 11.21 MWD 47.35 9.60 MWD 47.62 11.52 47.87 9.08 48.18 11.18 48.49 9.89 48.76 6.19 49.09 7.73 MWD 49.40 10.43 MWD 49.71 9.44 MWD 50.04 8.89 MWD 50.37 10.85 MWD Tool c/ual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 6-Nov-2000 03:15:02 Page 5 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total ~ depth angle angle length depth section +N/S- +E/W- displ - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) 91 9387.00 84.65 147.61 44.00 6876.37 -1044.83 3442.21 4224.46 5449.30 92 9484.00 87.90 148.76 97.00 6882.68 -948.25 3359.97 4275.48 5437.75 93 9579.00 88.68 150.26 95.00 6885.51 -853.38 3278.15 4323.66 5425.89 94 9674.00 89.38 149.44 95.00 6887.12 -758.45 3196.02 4371.37 5415.11 95 9770.00 90.30 149.74 96.00 6887.39 -662.53 3113.23 4419.97 5406.32 96 9864.00 90.13 150.24 97 9959.00 89.80 152.96 98 10054.00 88.23 153.36 99 10150.00 88.78 153.66 100 10244.00 89.35 153.34 101 10339.00 89.63 153.74 102 10434.00 89.65 153.36 103 10529.00 90.55 153.59 104 10624.00 88.13 153.21 105 10720.00 89.00 153.84 106 10815.00 89.98 153.61 107 10909.00 90.13 153.61 108 11006.00 89.65 153.56 109 11100.00 90.63 151.91 110 11196.00 90.85 151.26 111 11291.00 90.55 151.14 112 11386.00 90.88 151.16 113 11481.00 91.37 151.12 114 11578.00 89.60 150.54 115 11673.00 89.55 150.41 116 11763.00 89.68 150.29 117 11857.00 89.50 150.16 118 11949.00 89.08 149.89 119 12040.00 88.80 150.41 120 12132.00 89.95 150.79 [(C)2000 Anadrill IDEAL ID6_lB_48] 94.00 95.00 95.00 96.00 94.00 95.00 95.00 95.00 95.00 96.00 95.00 94.00 97.00 94.00 96.00 95.00 95.00 95.00 97.00 95.00 90.00 94.00 92.00 91.00 92.00 6887.03 6887.09 6888.73 6891.25 6892.78 6893.63 6894.22 6894.06 6895.15 6897.56 6898.41 6898.33 6898.51 6898.28 6897.04 6895.88 6894.70 6892.83 6892.01 6892.72 6893.32 6893.99 6895.14 6896.83 6897.84 -568.58 3031.83 4466.98 5398.70 -473.59 2948.27 4512.16 5389.99 -378.63 2863.52 4555.05 5380.36 -282.71 2777.63 4597.85 5371.73 -188.76 2693.52 4639.79 5364.95 -93.80 2608.48 4682.12 5359.70 1.16 2523.42 4724.43 5356.11 96.12 2438.42 4766.86 5354.33 191.07 2353.49 4809.39 5354.36 287.00 2267.58 4852.17 5355.89 381.95 2182.41 4894.22 5358.76 475.90 2098.20 4936.00 5363.45 572.86 2011.33 4979.16 5370.05 666.85 1927.78 5022.22 5379.50 762.84 1843.35 5067.89 5392.73 857.82 1760.11 5113.66 5408.09 952.81 1676.90 5159.49 5425.16 1047.78 1593.72 5205.34 5443.85 1144.76 1509.03 5252.61 5465.08 1239.72 1426.37 5299.43 5488.03 1329.69 1348.15 5343.95 5511.38 1423.65 1266.57 5390.63 5537.42 1515.59 1186.88 5436.59 5564.64 1606.54 1107.96 5481.88 5592.72 1698.51 1027.82 5527.03 5621.79 At DLS Srvy Azim (deg/ tool (deg) 100f) type 50.83 10.49 MWD 51.84 3.55 IMP 52.83 1.78 IMP 53.83 1.14 IMP 54.84 1.01 IMP 55.83 0.56 IMP 56.84 2.88 IMP 57.84 1.72 IMP 58.86 0.66 IMP 59.86 0.70 IMP 60.88 0.51 IMP - 61.89 0.40 IMP - 62.91 0.98 IMP - 63.93 2.58 IMP - 64.95 1.12 IMP - 65.97 1.05 IMP 66.97 0.17 IMP 68.00 0.50 IMP 69.00 2.04 IMP 70.01 0.71 IMP Tool c/ual type 6-axis -- -- -- 71.01 0.34 IMP - 72.00 0.35 IMP - 72.98 0.52 IMP 6-axis 73.97 1.92 IMP - 74.94 0.15 IMP - 75.84 0.20 76.78 0.24 77.68 0.55 78.57 0.64 79.47 1.32 IMP IMP ~ IMP ANADRILL SCHLUMBERGER Survey Report 6-Nov-2000 03:15:02 Page 6 of 6 Seq Measured In¢l Azimuth Course 9 depth angle angle length - (ft) (deg) (deg) (ft) 121 12221.00 90.38 148.58 122 12314.00 90.55 148.51 123 12404.00 90.75 148.44 124 12497.00 90.41 150.45 125 12590.00 90.38 150.50 126 12684.00 90.75 150.28 127 12777.00 90.86 153.29 128 12870.00 89.49 152.48 129 12961.00 89.38 150.59 130 13053.00 89.38 151.49 131 13144.00 89.59 152.78 132 13238.00 89.42 151.52 133 13326.00 89.01 151.25 134 13420.00 89.38 151.54 135 13511.00 89.97 151.30 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 89.00 6897.58 1787.43 950.99 5571.95 5652.53 93.00 6896.83 1880.27 871.66 5620.48 5687.67 90.00 6895.80 1970.11 794.95 5667.54 5723.02 93.00 6894.86 2063.01 714.87 5714.81 5759.35 93.00 6894.22 2155.98 633.95 5760.64 5795.42 94.00 6893.29 2249.95 552.23 5807.08 5833.28 93.00 6891.99 2342.93 470.30 5851.04 5869.91 93.00 6891.70 2435.91 387.52 5893.43 5906.16 91.00 6892.60 2526.90 307.53 5936.80 5944.76 92.00 6893.60 2618.88 227.04 5981.34 5985.65 91.00 6894.41 2709.88 146.60 6023.87 6025.65 94.00 6895.23 2803.87 63.49 6067.78 6068.11 88.00 6896.43 2891.86 -13.75 6109.92 6109.94 94.00 6897.75 2985.85 -96.27 6154.92 6155.67 91.00 6898.27 3076.84 -176.18 6198.45 6200.96 136 13603.00 90.10 151.37 92.00 137 13693.00 90.07 152.87 90.00 138 13785.00 90.27 151.50 92.00 139 13878.00 90.17 152.02 93.00 140 13925.54 90.17 151.46 47.54 Fin&~ sur~ ~s p~o~t~ to TD 141 13977.00 90.17 151.46 51.46 6898.21 3168.84 -256.91 6242.58 6247.87 6898.08 3258.83 -336.46 6284.67 6293.67 6897.81 3350.83 -417.83 6327.60 6341.38 6897.45 3443.83 ~499.76 6371.60 6391.17 6897.31 3491.37 -541.63 6394.11 6417.01 6897.16 3542.83 -586.83 6418.70 Srvy tool type 80.31 2.53 IMP 81.18 0.20 IMP 82.02 0.24 IMP 82.87 2.19 IMP 83.72 0.06 IMP 84.57 0.46 IMP 85.40 3.24 IMP 86.24 1.71 IMP 87.03 2.08 IMP 87.83 0.98 IMP 88.61 1.44 IMP 89.40 1.35 IMP 90.13 0.56 IMP 90.90 0.50 IMP 91.63 0.70 IMP 92.36 0.16 IMP 93.06 1.67 IMP 93.78 1.50 IMP 94.48 0.57 IMP 94.84 1.18 IMP 0.00 6445.47 95.22 Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [ (c)2000 Anadrill IDEAL ID6_lB_48] 11/30/00 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 742 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, Al( 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-16 20483 SCMT 001125 1 ,CD1-04 20474 M10/CDR/IMP 001107 1 CD1-04 20474 MD ARRAY RES 001107 I 1 ,CD1-04 20474 TVD ARRAY RES 001107 I I SIGN~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. NOV 2000 tasKa ur,,,,ng ......... Urllllng Kepor AFC No. l Date Rpt No Rig Accept- hr~asl~ R~I~~I~R/Ets~. Sz[~3'/'~..g'' 9s8c. 10/25/2000 4 10/282000 06:30:00 Anchorage Rig Relase - hfs: I PM Well: CD1-04 Depth (MDFI'VD) 2740/2385 Prev Depth MD: 2740 Progress: 0 Contractor: DOYON Daily Cost $ 293258 Cum Cost $ 594859 Est Cost To Date $ 550000 Ri..'g Name: Doyon 19 Last Csg: 9 518" {~ 2727' Next Csg: 7" ~ 9474' Shoe Test: Pending Operation At 0600: Slip and cut drilling line. Upcoming Operations: Test csg., clean out cement, LOT, PHIl 8-1/2" hole. MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill} LAST BOP/DIVERT LAST BOP/DRILL LSND 2 N TST 10/14~2000 10122/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.5ppg 8.5 1010gl2000 10/2312000 VISCOSITY PU VVT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 44sqc HYC N SPACE 10/2412000 0612112000 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2400 14 / 18 / 20 23368 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 980 6.6 10/25/2000 BBLS i~i~i~::~i POTABLE WATER 100 SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL !i'~ '~!J !i!'~ i iii ii!ii ii i~ ~i!jii:~ ' '~E~iiii ii !i~i~, i!iil i~ ii iii! ii~i '~ !i',',ii HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 18 175bbl 350111 / / CD1-04 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 10 2.s 1121 I 3.5 3h LINER SZ : RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 70' 9.0 5.5161 I 1189 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F 1.20 0.3% Ill .557 Water Base Muds 1497 PiT VOL GPM 2 JETS JETS Cement PHILLIPS 1 450 III 1tlt1111111111 IIIII 4. PERSONNEL 11 Other 150 DAILY MUD SPS 1 BIT COST BiT COST Diesel CONTRACTOR 25 8761 III ~oo PERSONNEL 0 OTAL MUD SPP ~ DULL DULL TOTAL VOL (bb,) M~SC PERSONNEL 5 22517 Ill III l il 1795 COMPANY MUD Wr GRADE GRADE TOT FOR WELL (bb~) SERWCE 14 M, III III Ill 28635 PERSONNEL TOTAL 45 ii~!~,~i',iiiilii~!~iiilli~,ili[i/i?,iii!i!liilliii!iiiii/il Bit, MIXL@I.2, NMSTAB, PONY, PONY, MWD, NMSTAB, 3 NMCSDC, XO, 3 HWDP, .JARS, 26 HWDP BH^ LENGTH 1081.33 5 4.281 19.5 G-I O5 4-1/2 IF Prem DATE LAST INSPECTED: HOURS ON JARS: 81.31 12:00 AM 01:00 AM 1.00 PRB_HOLE SURF Casing and POH, no problems. Cementing 01:00 AM 02:30 AM 1.50 PRB_HOLE SURF Casing and Stand back HWDP, laid down BHA, clear tools from floor. Cementing 02:30 AM 06:00 AM 3.50 RUN_CSG SURF Casing and Rig up to run casing, PJSM. Run 9-5/8" casing to 1450'. Cementing O6:O0 AM O8:0O AM 2.OO PRB_CSG SURF Casing and Wash and push casing from 1450' to 1510'. Cementing O8:00 AM 09:30 AM 1.50 RUN_CSG SURF Casing and Run casing to 2?2?' and establish circulation. Cementing 09:30 AM 10:00 AM 0.50 RUN_CSG SURF Casing and LD fill up tool and MU cement head. Cementing 10:00 AM 11:00 AM 1.00 CIRC SURF Casing and Circ and cond mud for cementing, PJSM. Cementing 11:00 AM 01:00 PM 2.00 CEMENT SURF Casing and Pumped 40 bbls of Blozan spacer with nut plug marker and Cementing 5O bbls of 10.5 ppg spacer. Cemented casing with 435 sxs of lead and 213 sxs of tall slurry. Displaced with 20 bbls of FW and 187.2 bbls of mud, bumped plugs, CIP @ 1300 hours. Full returns throughout, had 48 bbls of 10.7 ppg cement returns at surface. 01:00 PM O3:3O PM 2.5O OTHER SURF Casing and Ld cement head and landing jr.- flushed diYertor and Cementing surface equipment. Daily Drilling Report: CD1-04 10/25/2000 Page 1 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1- 04 Date: 10/ 26/00 Supervisor: D. Burle¥ Reason( s) for test: Initial Casing Shoe Test Formation Adequacy for Annular Injection Deep Test: Open Hole Adequacy for Higher Mud Weight Casing ,Size and Description: 9 5/ 8", 36~, J- 55, BTC CSG Casing Setting Depth: 2, 727' TMD 2, 377' TVD Hole Depth: 2, 760' TMD 2, 391' TVD Mud Weight: 9. 6 ppg Length of Open Hole Section: 33' EMW =Leak- off Press. + Mud Weight 0. 052 x TVD 760 psi + 9. 6 ppg 0. 052 x 2, 377' EMW for open hole section = 15. 7 ppg Used cement unit NO Pump output = 0. 0997 bps Fluid Pumped = 1. 3 bbls Ri, q pump used # 2 Fluid Bled Back = 1. 0 bbls 2, 800 psi I I I I II I I I I I I I I I I I I I I I I I I I I I I I I I I I I I i ; ; ; ; ; ;, i ; ; j~_; ;. i ;. : ;.; i. i i. --' -' '- ' ITIME LINE :! LEAK. OFF TEST - a-, CASING TEST _ LOT SHUT IN TIME - CASING TEST SHUT IN TIME - t--- TIME LINE _ 2, 700 psi 2, 600 psi 2, 500 psi 2, 400 psi 2, 300 psi 2, 200 psi 2, 100 psi 2, 000 psi 1, 900 psi 1, 800 psi 1, 700 psi 1, 600 psi 1, 500 psi 1, 400 psi 1, 300 psi 1, 200 psi 1, 100 psi 1, 000 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0ps! 0 10 20 30 40 50 STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME": see time line above PHILLIPS Alaska, Inc. A S~ sidi~ ~ PHILLIPS PETROLEUM COMPANT LEAK- OFF DATA MINUTES FOR LOT STROKES PRESSURE i .......... '-- 2. 0 ....3.. 0.. Es_. i__ i 3. 0 10_ 0.E. si 4. 0 ....2.. O... O. E.. s. i....l, j, s. o _.~.~_o.~?. L. l, 6. 0 __.3,_ 4. 0.~ s~ i' 7. 0 ,_.4. 1_ 0.. E. s. i.~ s. o .._.s. s_ o~. s.L,.' lO. O ._.61_ o=_ p__ p:L,i 11. 0 ,._6_ 7_ 02. s.L~ 12. 0 .... .7_ 2. 0_ E. s. L, 1:~. 0 .... 7. s.. o_ E.s!.: I I I 1 SHUT IN TIME SHUT IN PRESSURE o:_ o_ m. j.n_ .................... .7_~.. o.~..sj__ 1. 0 rain ,._.6.. 4. 0.~_ s.L' 2. 0 rain .... .5.. 8. 0.. p_ s. i__ 3. 0 rain __.5.. 6. 0_ p_ s. L- 4. 0 min .... .5._ 4~_ E. s.L- 5. 0 min .... .5. 30..~.. s. L- 6. 0 rain _._5. 1_ o== p== s= i__ 7. 0 rain ,._.5.. oo__ E. s.i__ 8. 0 rain __.4. 9_ o_ E. s. L' 0. 0 rain .... .4~ o._p~[.., CASING TEST DATA MINUTES FOR CSQ TEST STROKES PRESSURE 0.~ t..k.?. ....... .q. E.sJ. .... 2...,. t..k..,. ..... j.. 4. p.. R..,./.. 4..?. t.~..s. ..... .4. &0. ~.s__ i .. s... s_ t. k..,. ..... Z_~ p_ le.., j... s...~. t..k_.= ..... .e.. 3.. 0... p.?.i... j. o...~.t.~.?..' .j.,.. o& o_ p..,j.. i 12 stks 1, 270 Esi T" i-~';{[('~' .... : 1';~'~;~' 1" l-~. S...=. t.. k..=. .... J.,.. s. s_ o_ p.. s. L 20 stks .__2:. I_ 00_. Es_i..' 22 stks ...2.,.. 3. 4.. 0_ E. s.i..' 2.~..,. t..k..,.._ _2,.. s. 3.. o.. p.. sj... SHUT IN TIME SHUT IN PRESSURE o.. q.. mj. n. ................... _ 2.,.~.. so_ p. s_L 1. 0 min ...2.,.. 5. 2.~ R. s. i..' 2. 0 min 2, 510 psi 3. 0 min _ .2. ,.5_ j10_., p.. si... q.. m. j. n. ................... . 2.,.. si .o_ p.. sj.. o... m. j. n. .................. . 2.,_. s.1. O_ E.SJ.., 6.... 0... m. i..n. ................... ~,..5_ o. o_ E.sJ... 7..:. o... m. i..n. .................. 2_.,.. 5.. oop.. s.L J=. o_. roj. n. ................... ~,.. s.. o. o_ p...'.L o... m. j. n. .................. . 2.,.. s_oo_ p..,J_. j. o.:. O.. m_ i.. n. ................ . 2.,.. s.. OO_ E.SJ.- 15. 0 min _2_.,.. 4.. 9. 0_ E. Sj... o.:. o.._ mj. n_ ................ &~. o_ p.. s. L' 25. 0 m in ._.2,.. 4. 7.. 0_ E. s.i..' 30. 0 min 2~ 460 NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Modified by Scott Reynolds CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1- 04 Date: 11/ 1/00 Supervisor: D. Burle¥ Reason( s) for test: Initial Casing Shoe Test Formation Adequacy for Annular Injection Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/ 8" 36~ J- 55 BTC X 7" 26# L- 80 BTMC Casing Setting Depth: 2, 727' TMD Hole Depth: 2, 377' TVD TOC 8, 586' TMD 6, 399' TVD Mud Weight: 9. 7 ppg Length of Open Hole Section: 5, 859' EMW = Leak- off Press. + Mud Weight = 520 psi + 9. 7 ppg 0. 052 x TVD 0. 052 x 2, 377' EMW for open hole section = 13. 9 ppg Used cement unit yes Pump output = bbls pumped Fluid Pumped = 8. 0 bbls Ri. q pump used # 2 Fluid Bled Back = 0. 0 bbls 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi I I I I I I I I oNETIME' LINE::'MIN~ TICK,?, I LEAK- OFF TEST CASING TEST LOT SH~ IN TIME CASING TEST SH~ IN TIME TIME LINE 0 10 20 BARRELS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME": see time line above PHILLIPS Alaska, Inc. A Subsidiary ~ PHILLIPS PETROLEUM COMPANT LEAK- OFF DATA CASING TEST DATA MINUTES FOR CSQ TEST STROKES PRESSURE MINUTES FOR LOT BBLS i °0.$ 1. 0 1. 5 2. 0 2. 5 3.$ 4. 0 5.` 5 PRESSURE i'__o.p~L ................... . O...~! k. ?. ........ . o..~ j. ..... t. o. t. P~[ ................................................ l_ TZ... p.. s.i.._ 2.. s. 3.. E.. s. i.._ 3. s.. 9.. p.~.J ............................................... iiiZ..-. Zi. i.. ZiZZiii;ZiiiZZZi sZo..~.?. L~.% .......... ~. ............. .i- ................. 510 si 4_ s_ o.[,..,!. j .......... ~ .......... $ ................ s~.~. j ............... .I.. ............ $ ................ Z°.. P..s!..~ ................ .1.. ............ 1 ................. 4. 7_0~.?.[ ................................ t,'~. P.. s. t ................................................ i. I r I i. I i iSHUT IN TIME SHUT IN PRESSURE 6.-' 6' Tn,'" n- - l""~:~"~ T'" i 1. 0mln I 369~ 3si rn- !'"~'~;F" Z.¥~ Tn- ~"~ 5' 1~i'~" '['"~'~=[~['" 8.-' E;~'i'.- {'-~'~'~-~E' F" 9. 0 m~ n [ ~23 p_ si SHUT IN TIME SHUT IN PRESSURE o.._ o..m. Ln' ...................... ..o.£. s.~ ..... 1. 0 min 3. 0 min 4.-. o_m. Ln. .................................. s.;. o... mj. n. ................................. 6.;. 0...m. i~ .................................. 7. 0 min 8. 0 min o_ mj.,. .................................. 10. 0 min 15. 0 min 20. 0 min 25. 0 min 30. 0 rain NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Modified by Scott Reynolds MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-04 Date Dispatche 14-Nov-00 Installation/Rig Doyen 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 · . Received By Please sign and return to: Anadrill LWD Division 3940 Amtic Blvd, Suite 300 Anchorage, Alaska 99503 N Rose 1 @ slb.com Fax: 907-561-8417 LWD Log Delive~ V1.1, Dec '97 ALASRA OIL AND GAS CONSERVATION CO~ISSION Chip Alvord Drilling Team Leader Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLE$, ~OVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3102 PHONE: (907) 279-1433 FAX: (907) 276-7542 Coiville River Unit CD 1-04 Permit No: 200-117 Sur Loc: 243'FNL, 2551 'FWL, Sec. 5, T1 IN, R5E, UM Btmhole Loc. 836'FNL, 1597'FEL, Sec. 4, T1 IN, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations umil all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface easing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to thc Commission on form 10- 403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production easing annulus of a well approved for annular disposal on Drill Site CD 1 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer' than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. 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. (~~~.~iel T. Seamount,'Jr. ' Commissioner BY ORDER OF THE COMMISSION DATED this ~7~,~-~4~ day of August, 2000 dlf/Enclosures cc: Department offish & Game, Habitat Section w/o encl. Department of Enviromnental Conservation w/o end. ,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Redrill ~ lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen[ Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25557, 372095 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 243' FNL, 2551' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At target (=7' casing point ) 8. Well number Number 2138' FNL, 1576' FWL, Sec. 33, T12N, R5E, UM CD1-04 #U-630610 At total depth 9. Approximate spud date Amount 836' FNL, 1597' FEL, Sec. 4, T11 N, R5E, UM 08/25/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1- 03 13,990' MD Sec 5, Sec 33, feet 9.9' @ 200' Feet 2560 6,888' TVD feet Sec4 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 90.1 ° Maximum surface 2427 psig At total depth (TVD) 3215 at psig 7000' 'I'VD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Cesing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2740' 37' 37' 2777' 2400' 521 Sx Amticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 9447' 37' 37' 9484' 6881' 121 sx Class G N/A 4.5" 12.6# L-80 IBT-M 9004' 32' 32' 9036' 6749' Tubing (packer depth) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) tree vertical feet Casing Length' Size Cemented Meas~l~t~P~ ~ ~ W~'e~l~ depth Structural Conductor 0 RIG IN A L 000 Perforation depth: measured Alaska 0~ & Gas Cons, Commission true verticalAnchorage 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .~,~ ~'. ~,~.~._ Title Drilling Team Leader Date Commission Use Only Permit Number i AP, number i Appmva, date ~/~ ?//r~O [ See cover letter for ~_. el¢ll-, ,/a~ ~ 50- v~'O ~3~'-' '~- O ,~ ~',~' Other requirements Conditions of approval Samples required Yes (~ Mud log' requir~dl - Yes Hydrogen sulfide measures Yes (~ Directional survey required ~ No Required working pressure for BOPE 2M 3M 5M 1 OM 15M by order of Approved by Commissioner the commission Date ........ Form 10-401 Rev. 7-24-89ORIGINAL SIGNED BY D Taylor Seamount n triplicate Alpine: CD1-04 Procedure . . 3. 4. 5. 6. 7. 8. . 11. 12. 13. 14. 15. 16. 17. 18. 19. Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8-1/2" hole to the intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 ½, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus Set BPV and secure well. Move rig off. RECEIVED JUL ?-0 2000 Alaska Oit & Gas Cons. Commission Anchorage Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-03 will be the closest well to CD1-04 (9.9' at 200' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 8.3' at 325' MD. Drillina Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: There is some potential for lost circulation in the Alpine sand. If losses are encountered, conventional LCM treatments will be used. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD1-04 will be injected into the annulus of another permitted well on the CD1 pad. The CD1-04 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-04 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 27992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi RECEIVED JUL 2 0 2000 Alaska 0~ & Gas Cons. Commission Anohomge CD1-04 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 ½" Section - 6 1/8" point- 12 ~" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10-25 10-15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost cimulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss cimulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. RECE,,VE JUL 2 0 2000 Alaska 0~', & Gas Cons. Commission Anchorage (' Colville River Field CD1-04 Production Well Completion Plan ! i .- 16" Conductor to 114' Updated 07/18/00 I I [.~..i I I ] 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1700' TVD = 1792' MB ' I I I I I I../ ' Isolation, Sleeve ,w. ith DB-6 No-Go Lock (3.812" OB)run in profile IIII [111',, Dual 1/4 x 0.049 sis control lines IJ I I I I L-_'t9's/8 3SppfJ-55BTC ~ I I I I ~] Surface Casing @ 2777' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3,909" ID) at 3400' TVD for, E Dummy with 1" BK-2 Latch 4-1/2" 12,6 ppf L-80 IBT Mod. R..~3 tubing run with Jet lube pipe dope Camco KBG-2 GLM (3.909' ID) at 5200' TVD for E Dummy with 1" BK-2 Latch RE'CE V'ED JUL 2. 0 2000 Alaska Oi{ & Gas Co~s. Commission Anchorage Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve tuned' for casing side shear e +/- 2000 psi set 1 joint above the X landing nipple TOC @ +/- 8800' MD (+500' MD above top Alpine) Baker S3 Packer at +/- 9036' WRDP-2 SSSV (2,125"1D) w/DB-6 No-Go Lock (3,812" OD) - to be installed later Packer Fluid mix: 9,6 ppg KCl Brine with 2000' TVD diesel cap Tubino Suoended with - diesel to lowest GLM Completion Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3,909" ID) 4-1/2" tubing joint (1) HES "X" (3.813" ID) 4-1/2" tubing joint (1) S3 Packer (c/w handling pups) 4-1/2" tubing joint (1) HES "XN" (3.725" ID) 4-1/2" 10' pup joint WEG (+/- 63 deg) MD 32' 1792' 4209' 6786' 8950' 8995' 9036' 9089' 9100' Top Alpine at 9332' MD / 6860' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9484' MD / 6881' TVD O 87 deg TVD 32' 1700' 3400' 5200' 8704' 6729' 6749' 6776' 6781' Well TD at 13990' MD / 6888' TVD TOC @ +1- 8800' MD (+500' MD above top Alpine) ( Colville River Field (' CD1-04 Production Well Completion Plan Formation Isolation Contingency Options L 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.25" ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4"x 0.049" sis control line @ 1700' TVD = 1792' MD Updated 07/18/00 j9-5/8" 36 ppf J-55 BTC Surface Casing 2777' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R._~.3 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909' ID) at 5200' TVD for E Dummy with 1" BK-2 Latch (A) Bonzsi ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (C) Open Hole Bridge Plu_a Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear {) 2000 psi set 1 joint above the X landing nipple RECEIVED ,JUL 2 0 20O0 Alaska Oi~ & Gas Cmos. Commission Anohorage Baker S3 Packer set at +/- 9036' Well TD at 13990' MD I 6888' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9484' MD / 6881' TVD @ 87 deg CD1-04 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2777 / 2400 14.2 1086 1532 7" 9484 / 6881 16.0 3113 2427 N/A 13990 / 6888 16.0 3116 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1ID Where: ASP = Anticipated Surface pressure in psi FG - Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP- (0.1x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052)-0.1} D = [(10.9 x 0.052) -0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)-0.1} D = [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3113 - (0.1 x 6881') = 2425 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3116 - (0.1 x 6888') = 2427 psi RECEIVED ,JUL 2 0 2000 Alaska 0~i & Gas Cons. Commission Anchorage Alpine CD1-04 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 -500 -1500 -2500 Q -3500 -4500 -5500 -6500 -7500 II II II II ~111 I1~ II ~,~ ~[I % II '~ Itl Ill III III I I X, ~R,~OrL Ri III II ~11 II III II i.,= Ill II III III- III III ,,, III Ill Ill Ill 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT RECEIVED ~1.,. 2 0 2000 ~,~ co~$. Commission Anchorage 9 518" Surface Casing run to 2777 MD 12400' TVD. Cement from 2777' MD to 2277' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2227' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2227'-1617') X 0.3132 ft3/ft X 1.5 (50% excess) = 286.6 fts below permafrost 1617' X 0.3132 fts/ft X 4 (300% excess) = 2025.8 ft~ above permafrost Total volume = 286.6 + 2025.8 = 2312.4 ft~ => 521 Sx @ 4.44 ft%k System: 521 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft%k, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant Tail slurry: 500' X 0.3132 fts/ft X 1.5 (50% excess) = 234.9 ft~ annular volume 80' X 0.4341 ft~/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fts => 230 Sx @ 1.17 ft%k System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft%k 7" Intermediate Casing run to 9484 MD / 6881' TVD Cement from 9484' MD to +/- 8800' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (9484' - 8800')° X 0.1268 fts/ft X 1.4 (40% excess) = 121.4 fts annular volume 80' X 0.2148 ft°/ft = 17.2 ft~ shoe joint volume Total volume = 121.4 + 17.2 = 138.6 ft~ => 121 Sx @ 1.15 ft%k System: 121 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersa~nt, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft°/sk 1 By Weight Of mix Water, all other additives are BWOCement RECEIVED ,.JUL 2 0 2000 Alaska 0i{ & Gas Cons. Commission Anchorage Created by bm~choM For: B Robert~on Dote plotted: 17-Jul-2000 Plot R~femnce i',. 4 Vwm[on~t 1. Coordinates ore rn feet r~er~nce slot ~4. I ' True V,,rtff¢=l Oepths are reference £st;moted RKB.I PHILLIPS Alaska, Inc. 4OOO 3200 2800 2400 20aa 160O 1200 800 400 400 ~00 Structure : CD~I Field: Alpine Field 400 0 400 800 1200 1600 2000 2400 51.72 AZIMUTH 546a' ***Plane of Proposal*** .enSLS..o.k,. UUIIO/i urn Casing Pt. 400 0 400 800 1200 1600 2000 2400 Well: 4 Location: North Slope, Alaska East (feet) -> 2800 3200 3600 4000 Begin 4400 4800 5200 5600 6000 6400 6800 7200 RECEAVED JUL 2 0 2.000 Alaska C~ & Gas Cons. ¢ommi~on Anchorage 2~00 3200 3600 4000 4400 East (feet) -> EOC Casing Pt. CD1-4 TARGET LOCATION: 2138' FNL, 1576' FWL SEC. 33, T12N, RSE in Final Build CD1-4 INTERM. PT. LOCATION: 1640' FSL, 2369' FWL SEC. 35, T12N, RSE CD1-4 TD LOCATION: 856' FNL, 1597' FEL SEC. 4, T11N, R5E - Csg Pt. 4800 5200 5600 . 6000 6400 6800 7200 4000 3600 3200 2800 2400 2000 1600 1200 800 400 400 80O Z 0 400 PHILLIPS Alaska, Inc.[ Well: 4 I Location : North Slope, AlaskaI Structure: CD~I Field : Alpine Field 40O 800 1200 1600 2000 · ~- 2400 2800 -t-. ¢'~ 3200 0 3600 4000 4400 I 480O 5200 5600 6000 6400 RKB Elevation: 56' KOP 2.00 4.00 6.00 8.00 Begin Build/Turn 12.56 14.95 West $ok 51.72 AZIMUTH 17.66 5468' (TO TARGET) 20.46 DLS: 3.00 deg per 100 ft 23.30 ***Plane of Proposal*** 26.18 2g.08 31 .g9 Permafrost 54.92 40.81 EOC C-40 C-30 9 5/8 Casing Pt. C-20 K-3 K-2 AVERAGE ANGLE 45.7 DEC RECEIVED JUL 2 0 20°0 '~' % a Alaska OH & Gas Cons. Comm~s~{0n Anchorage Albion -97 Alblan-96 Begin Build/Turn DLS: g.o0 deg per 100 ft 6800 7200 I I I I I I I I I I I I I I I I I I I I I II I I I I I I I I I 400 0 400 800 1200 1600 2000 2400 2800 5200 5600 4000 4400 4800 5200 5600 6000 Vertical Section (feet) -> Azimuth 51.72 with reference 0.00 N, 0.00 E from slot #4 PHILLIPS Alaska, Inc. Struature: CD~I Well: 4 field: Alpine Field Looafion: North Slope, Alaska 151.88 AZIMUTH -965' (TO TARGET) ***Plane of Proposal*** ,~, 6250 '- 6500 '~ 6750, · 7000 V 7250 /;] ~.."~ TARGET ANGLE 4364r ~'~' 87 DEG 4~94~IHiHRZ ~.. ....... 4~.67\ ~ ~o~ 'I'ANGE~'I' ANGLE 57.60~ LCU .{~[~'-e ~& 6B~~°'" · C~ RECEIVED ,JUL 2 0 2000 Alaska O~ & ~as Cons. Commission Anchorage ~,o*~ FINAL ANGLE ~ 90.16 DEG · · i i i i i i i i J ! i i i I i i i ! J i ! i i ] i I i i J ! i i i i i i i ! i i i i i i i i 1750 1500 1250 1000 750 500 250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 ;t250 3500 3750 Verticol Section (feet) -> Azimuth 151.88 with referenoe 0.00 N, 0.00 E from slot //4 Created by bmlchae] FOI': B RobeFt~onI Date plotted: 18--Jul-2000 Plot Reference is 4 VemionjS11. Coordinotes ore In feet reference slot ~4. True Ver~cal Depths a~ce Estimated RKB.i iPHILLIPS Alaska, Inc. Sfructure: CD#I Well: 4 Field: Alpine Field Location : North Slope, Alaska Point IKOP Begin Build/Turn West Sok Permofrost EOC 'C-40 C-30 9 5/8 Casing Pt. C-20 K-3 K-2 "Albian-97 Albian-96 . IBeg~n Build/Turn HRZ <-1 _CU Miluveach A Alpine D Alpine Base Alpine Target - Casing Pt. EOC Begin Final Build EOC TD - Csg Pt. MD 300.00 800.00 1055.32 1617.10 2065.52 2455.99 2756.68 2776.75 3297.92 4768.42 5093.45 7660.75 81 64.76 8358.56 8633.89 8891.33 9067.91 9198.18 9275.96 9331.54 9454.80 9483.84 9754.91 11184.08 11230.25 13990.00 PROFILE COMMENT Inc Dir TVD 0.00 79.00 300.00 10.00 79.00 797.47 16.44 60.25 1046.00 32.50 47.15 1556.00 45.70 43.04 1903.29 45.70 43.04 2176.00 45.70 43.04 2386.00 45.70 43.04 2400.00 45.70 43.04 2764.00 45.70 43.04 3791.00 45.70 43.04 4018.00 45.70 43.04 5811.00 45.70 43.04 61 63.00 45.70 43.04 6298.35 44.37 78.29 6496.00 52.35 107.62 6669.00 61.26 123.40 6766.00 68.86 133.26 6821.00 73.66 138.64 6846.00 77.17 142.33 6860.00 85.11 150.17 6879.00 87.00 151.98 6881.00 89.71 151.99 6888.78 89.71 151.99 6896.00 90.16 151.88 6896.05 90.16 151.88 6888.30 DATA North 0.00 8.30 30.51 173.63 373.76 578.03 735.33 745.82 1018.47 1787.74 1957.78 3300.82 3564.49 5665.87 3758.88 3746.12 3681.93 3608.60 3555.67 3514.17 3413.03 3387.67 3148.48 1886.78 1846.04 -588.06 Eost 0.00 42.72 95.92 276.86 475.60 666.32 813.18 822.97 1077.54 1795.78 1954.54 3208.49 3454.66 3549.32 3713.40 3901.24 4033.34 4125.59 4176.73 4210.93 4278.40 4292.41 4419.67 5090.91 5112.63 6413.14 V. Sect 0.00 38.68 94.20 324.90 604.89 881.15 1093.89 1108.07 1476.81 2517.20 2747.16 4563.53 4920.11 5057.23 5243.65 5383.19 5447.12 5474.11 5481.46 5482.60 5472.90 5468.19 5419.90 5165.16 5156.98 4669.88 Deg/lO0i 0.00[ 2.00i i 3.OOj 3.ooi i 3.oo! O.OOj I o.oo! 0.00i o.ooi 0.001 0.00 I 0.00 0.00' i 0.00 · 9.00 9.00 9.00 9.00 9.00 I 9.00 9.00 9.00! 1.00[ 0.00 1.00 O.OOj RECE,VED ,JUL 2 0 2000 Alaska 0ii & Gas Cons. Commission Anchorage PHILLIPS Alaska, Inc. CD#I 4 slot #4 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT Baker Hughes INTEQ Your ref : 4 Version#il Our ref : prop3101 License : Date printed : 17-Jul-2000 Date created : 10-Aug-1998 Last revised : 14-Jul-2000 Field is centred on nT0 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is nT0 20 34.711,w150 55 31.478 Slot Grid coordinates are N 5975883.787, E 385978.787 Slot local coordinates are 242.49 S 2552.30 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-10548'>,,19,CD#1 PMSS <2827 - 11956'>,,19A, CD#1 PMSS <0-10897'~,,3,CD91 PMSS <0-8350'~,,26PH1,CD%1 PMSS <7755-11134'~,,26,CD#1 PGMS <0-10255'>,,WD2,CD#l PMSS <476 - 11190'>,,34,CD#1 PMSS <297 - 9882'~,,44PH1,CD#1 PMSS <9081 - 12811'~,,44,CD#1 PMSS <0-11300J>,,13,CD#1 PMSS <384 - 14477'~,,23,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <763 - 7440J~,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <472 - 1545~,,36PH1,CD#1 PMSS <0-10224'~,,39PH1,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <7182 - 11170'~,,41,CD91 PMSS <475 - 8166'>,,41PH1,CD#1 PMSS <0-10504'~,,5PH1,CD#1 PMSS <9499 - 14515'~,,5,CD%1 PMSS <0-9357'~,,16PH1,CD#1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <0-7331'>,,1PH1,CD%1 PMSS <5946 - 10289'~,,1,CD#1 PMSS <0-11608'~,,42,CD%1 PMSS <654 - 10956'~,,38PB1,CD#1 PMSS <9876 - 12240'~,,38,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <9810 - 10796'>,,24,CD#1 PMSS <0-13308'>,,6PH, CD#1 PMSS <12550 - 16023'>,,6,CD%1 PMSS <10016 - 11136'>,,32,CD91 PMSS <0-11067'>,,32PH1,CD%1 PMSS <0-8844'>,,45PH1,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <0-11492'>,,27,CD#1 PMSS <0-9236'>,,22,CD#1 22 PMSS(0 - 9239'>DepthShiEted,,22,CD#1 PMSS <10894 - 15350'>,,9,CD%1 PMSS <0-11934'>,,~PH,CD%1 PMSS <0-12055'>,,40,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance 6-ADz-2000 30-Apr-2000 4-Jan-2000 6-Mar-2000 1-Nov-1999 28-Jun-1999 11-May-2000 23-May-2000 23-May-2000 15-Ju1-1999 3-May-2000 15-Mar-2000 4-Jan-2000 22-Dec-1999 4-Jan-2000 4-Jan-2000 22-Sep-1999 3-Apr-2000 26-Mar-2000 23-Jan-2000 23-Jan-2000 4-Jan-2000 25-0ct-1999 29-Feb-2000 27-Jun-1999 23-Dec-1999 13-Feb-2000 14-Feb-2000 28-Jun-1999 14-Jun-2000 30-Jun-2000 11-Jul-2000 7-Jun-2000 4-Jan-2000 4-Jan-2000 16-Nov-1999 26-Aug-1999 16-Mar-2000 11-Jul-2000 11-Jul-2000 20-Jun-2000 14-~ul-2000 17-~ul-2000 149.8 149.8 9.9 220.2 220.2 291.9 299.9 400.1 400.1 89.7 189.2 209.5 320.1 320.1 320.1 350.0 350.0 369.7 369.7 10 1 10 1 118 9 118 9 29 6 29 6 380 0 339 6 339 6 309 9 200 1 19.7 19.7 279.7 279.7 409 9 409 9 330 0 229 9 180 3 180 3 49 7 49 7 360.0 M.D. Diverging from M.D. 100.0 100.0 100.0 200.0 100.0 100.0 2580.0 200.0 100 0 100 0 312 5 337 5 312 5 100 0 100 0 100 0 100 0 100 0 100 0 100 0 100 0 100 0 337 5 337 5 200.0 200.0 100.0 200.0 200.0 100.0 0.0 100.0 100.0 312.5 312.5 200.0 200.0 0.0 200.0 100.0 100.0 300.0 300.0 100.0 9331.5 13900.0 13990.0 13990.0 10940.0 10680.0 10540.0 10540.0 13680.0 13860.0 13990.0 10100.0 10100.0 10380.0 11440.0 11440.0 10380.0 10380.0 9754.9 13990.0 13990.0 13990.0 9483.9 6260.0 10360.0 11900.0 11900.0 10260,0 13990.0 11800,0 11800.0 10400.0 10400.0 10580.0 10580.0 13080.0 13990.0 10000.0 10000.0 13990.0 10400.0 11230.2 RECEIVED ,JUL 2. 0 2000 Alaska G*~ a GaS Cons. Commission Anchorage PHILLIPS Alaska, Inc. CD#i 4 slot #4 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : 4 Version#il Our ref : prop3101 License : Date printed : 17-Jul-2000 Date created : 10-Aug-1998 Last revised : 14-Jul-2000 Field is centred on nT0 20 37.100,w150 51 37.53 Structure is centred on nT0 20 37.100,w150 56 46.041 Slot location is nT0 20 34.711,w150 55 31.478 Slot Grid coordinates are N 5975883.787, E 385978.787 Slot local coordinates are 242.49 S 2552.30 E Projection t~pe: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 £eet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DBCREASIN~ CLEARANCES o£ less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-10548'>,,19,CD%1 PMSS <2827 - 11956~>,,19A, CD%1 PMSS <0-10897'>,,3,CD#1 PMSS <0-8350'>,,26PH1,CD%1 PMSS <7755-11134'>,,26,CD%1 PC~MS <0-10255~>,,WD2,CD%1 CD1-29 Version #2,,29,CD%1 CD1-31 Version #2,,31,CD#1 CD1-30 Version #4,,30,CD#1 CD1-33 Version #4,,33,CD#1 CD1-28 Version #5,,28,CD#1 PMSS <476 - 11190~>,,34,CD#1 PMSS <297 - 9882'>,,44PH1,CD%l FNSS <9081 - 12811'>,,44,CD#1 PMSS <0-11300'>,,13,CD%1 PMSS <384 - 14477'>,,23,CD#1 PMSS <832 - 12147'>,,25,CD%1 PMSS <763 - 7440'>,,36PHt,CD%l PMSS <6600 - 10654'>,,36,CD#1 PMSS <472 - 1545'>,,36PHl,CD#1 PMSS <0-10224'>,,39PH1,CD%1 PMSS <9146 - 13289'>,,39,CD%1 PMSS <7182 - 11170'>,,41,CD%1 PMSS <475 - 8166'>,,41PH1,CD#1 PMSS <0-10504'>,,SPHl,CD%1 PMSS <9499 - 14515'>,,5,CD%1 PMSS <0-9357'>,,16PH1,CD%1 PMSS <8393 - 12600'>,,16,CD#1 CD1-43 Version #11,,43,CD%1 PNSS <0-7331'>,,1PH1,CD#1 PMSS <594~ ~ 10289'>,,1,CD%1 PMSS <0-11608'>,,42,CD%1 PMSS <654 - 10956'>,,38PB1,CD#1 PI(SS <9876 - 12240'>,,38,CD#1 35 Version$6,,35,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 6-Apr-2000 )149.0( 30-Apr-2000 )149.0( 4-Jan-2000 }8.3( 6-Mar-2000 )219.3( 1-Nov-1999 )219.3( 28-Jun-1999 )231.3( 13-Jan-2000 }248.2( 11-Aug-1999 }268.4( 11-Aug-1999 )258.4( 11-Aug-1999 )288.4( 13-Jan-2000 )238.6( 11-May-2000 )297.9( 23-May-2000 )399.4( 23-May-2000 )399.4( 15-Ju1-1999 )88.0( 3-May-2000 )186.7( 15-Mar-2000 )207.0( 4-Jan-2000 )319.4( 22-Dec-1999 )319.4( 4-Jan-2000 )319.4( 4-Jan-2000 )348.7( 22-Sep-1999 )348.7( 3-Apr-2000 )368.2( 26-Mar-2000 }368.2( 23-Jan-2000 )9.5( 23-Jan-2000 )9.5( 4-Jan-2000 )117.0( 25-0ct-1999 }117.0( 6-Jul-2000 )389.1( 29-Feb-2000 )28.6( 27-Jun-1999 }28.6( 23-Dec-1999 }379.0( 13-Feb-2000 }338.0( 14-Feb-2000 )338.0( 6-~un-2000 )4410.8( 200 0 200 0 325 0 200 0 200 0 2600 0 312 5 312 5 312 5 312 5 300.0 300.0 200.0 200.0 325.0 350.0 325.0 100.0 100.0 100.0 312.5 312.5 200.0 200.0 200.0 200.0 375.0 395.0 300.0 300.0 300.0 200.0 200.0 200.0 5360.0 200.0 9617.2 13990.0 13990.0 13990.0 10920.0 11880.0 10540.0 11420.0 11920.0 13860.0 13080.0 11760.0 11760.0 13990.0 13990.0 13990.0 10020.0 10020.0 11440.0 11200.0 11200.0 13720.0 13720.0 8986.7 13960.0 13990.0 13990.0 11640.0 9517.2 11240.0 12360.0 13440.0 13440.0 5360.0 RECEIVED . ,JUL 2 0 2000 Alaska Oi~ & Gas Cons. Commissio~ Anchorage PMSS <0-8168'>,,35,CD#1 CD1-24 Version #5,,24,CD%1 ~=MSS <9810 - 10796'>,,24,CD#1 PMSS PMSS <12550 - 16023'>,,6,CD#1 CD1-32 Version #6,,32,CD~1 PMSS <0-11067'>,,32PH1,CD#1 PHSS <10016 - 11136'>,,32,CD!1 PMSS <0-8844'>,,45PH1,CD%1 PMSS <7950-11950'>,,45,CD~1 PMSS <562 - 12134'>,,37,CD~1 P~SS <0-11492'>,,27,CD#1 PMSS <0-9236'>0,22,CD~1 22 Version%1,,22,CD%1 22 PMSS(0 - 9239'>DepthShifted,,220CD#l PMSS <10894 - 15350'>,,9,CD#1 PMSS <0-11934'>,,gPH,CDtl 40 VersionJ6,,40,CD%1 PMSS <0-12055'>,,400CD#1 CD1-2 Version CD1-10 Version #3,,10,CD#1 CD1-15 Version #2,,15,CD%1 CD1-17 Version #8,,17,CD%1 CD1-20 Version ~3,,20,CD%1 CD1-21 Version #3,,21,CD#1 28-Jun-1999 29-Jun-2000 14-Jun-2000 30-Jun-2000 11-Jul-2000 8-Jun-2000 4-Jan-2000 7-Jun-2000 4-Jan-2000 16-Nov-1999 26-Aug-1999 16-Mar-2000 11-Jul-2000 11-Jul-2000 11-Jul-2000 20-Jun-2000 14-Jul-2000 13-Jul-2000 17-Jul-2000 8-Aug-1999 10-Aug-1999 5-Apr-2000 19-Apr-2000 10-Aug-1999 10-Aug-1999 )308.9, )866.9, )39.8 )18.3 )18.3 )9898.2 278.1 278.1 · 408.9 408.9 328.2 228.9 179.0 )2363.1 )179.0 )48.1 )48.1 )10412.7 )359.2 )12.5 )58.4 )108.4 )128.0 )158.5 )168.4 200.0 13990.0 13990.0 312.5 312.5 2500.0 325.0 325.0 200.0 200.0 300.0 200.0 312.5 7360.0 312.5 300.0 300.0 1688.9 200.0 800.0 350.0 312.5 312.5 312.5 312.5 10400.0 13990.0 13990.0 12280.0 12280.0 9325.2 11240.0 11240.0 12180.0 12180.0 13920.0 13990.0 9719.4 7360.0 9719.4 13990.0 10420.0 13990.0 11192.1 9860.0 13840.0 9567.2 13160.0 11780.0 11192.1 RECEIVED JUL 2_. 0 2000 Alaska Oi~ & '"' ~. "",, ~a~ u,,ns. Commission Anchorage Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 19, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-04 Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is August 25, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-04 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. RE'CE VED JUL 2 0 2000 Alaska 0i{ & Gas Cons. Commission Anchorage If you have any questions or require further information, please contact Chip Alvord on 265-6120. Sincerely, Brian Roberts~'n :' Senior Drilling Engineer Attachments CC: CD1-04 Well File / Sharon AIIsup Drake Chip Alvord Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ATO 1030 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com RECEIVED JUL 2 0 2000 Alaska 0i{ & Gas Cons. Commission Anohomge CASH ADVANCE DRAFT 109 PAY TO ~X~)~) 82-40/1021 EnfJewood, Cobrado P~yabb ~ Norwe~ I~nk ~f Gr~nd Grind 2.0 ~ 2.00 t: :L S '"0 2. ? DOLLARS lOT VAUD FOE AI~IOUNT OVEP..$1000 ~ST COMPANY. ,- _ _ , - se.rv "WCllbore .,,.g ann disposal para req F ELD & POOL ~ INIT CLA~S ~ GEOL AREA ~ UNIT# ~ ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg. : ...... 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved...' ~ ~,; '~,O ~'~ 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet'regulation ................ .~ DATE 26. BOPE press rating appropriate; test to '~z~_,c'-O~,,.,~ psig. ~ 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30.... Permit can be issued wlo hydrogen sulfide measures ..... ~ N _~' 31. Data presented on potential overpressure zones ....... Y N 32. Seismic analysis of shallow gas zones.' .......... '.. Y AP~,P~R ....D~AT~ . 33. Seabed condition survey (if. off-shore) ............. · ~. -.,~ 34. Contact name/phone for weekly progress reports [exploratory on~j~Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... ~ N APPR DATE (B) will not contaminate freshwater; or cause drilling waste ~ .. (~ N .~u~.x~ ~G~¥,e~, ~'~£ '~1'~ i_1_~,,~_ ~,t---"/'t4l<~ tA,)~H_~, IA.)~,~, ~.~.jv3, ~ ~~ 4) (C) will not impair mechanical integrity of the well used for disposal; .(~ ~ ~,4 ~ ~ ~,~1), ' (D) will not damage producing formation or impair recovery from a pool; and .. (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ["~") N GEOLOGY: ENGINEERING_: UlClAnnular COMMISSION: Comments/Instructions: Z --I -l- in c:Vnsoffice\wordian~diana\checklist (rev. 02/17100)
