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Home My WebLink About205-148MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD4-319 COLVILLE RIV UNIT CD4-319 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 CD4-319 50-103-20516-00-00 205-148-0 W SPT 6908 2051480 1727 2015 2015 2015 2015 280 367 350 336 4YRTST P Bob Noble 6/25/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD4-319 Inspection Date: Tubing OA Packer Depth 800 2800 2740 2730IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230629130642 BBL Pumped:2.3 BBL Returned:2.3 Thursday, July 27, 2023 Page 1 of 1            P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 13, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Brennen Green ConocoPhillips Well Integrity Field Supervisor Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.04.13 11:34:18-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green ConocoPhillips Alaska Inc.Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-offReport of Sundry Operations (10-404)Alpine FieldWell Name API # PTD #Initial top of cementVol. of cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant dateft bbls in galCD3-106 5010320611-0000 210-001 N/APost Conductor Ext10.75" 4/5/2022 2 4/12/2023CD3-117 5010320596-0000 209-026 N/APost Conductor Ext13" 4/5/2022 3 4/12/2023CD3-127 5010320634-0000 211-005 18' 1.0 8" 4/9/2022 1 4/12/2023CD3-302A 5010320522-0100 210-035 N/APost Conductor Ext9" 4/5/2022 2 4/12/2023CD4-214 5010320537-0000 206-145 22' 8" 1.6 7" 4/9/2022 1.5 4/12/2023CD4-319 5010320516-0000 205-148 22' 3" 1.5 7" 4/9/2022 1.5 4/12/2023Date 04/13/2023CD3 & CD4 PadsCD4-3195010320516-0000205-14822' 3"1.57"4/9/20221.54/12/2023 ! 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Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: SC REPAIR_ 2.Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 18,521' Casing Collapse Conductor Surface Production Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:6/9/2021 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Well Integrity Field Supervisor Roger Mouser / Roger Winter n1927@conocophillips.com 7118' 114'114' 11995' 78'16" 9 5/8" 7" 3159' Length TVD Burst 11,789' MD 2397' 7153' 3196' 7,135'12,190' PRESENT WELL CONDITION SUMMARY 7,155' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380077 ADL0384209 205-148 P.O. Box 100630, Anchorage, Alaska 99508 50-103-20516-00-00 ConocoPhillips Alaska, Inc. COLVILLE RIVER CD4-319 COLVILLE RIVER COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 7,155'-7,136' Perforation Depth TVD (ft):Tubing Size: 12,190'-18,480' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 659-7506 Baker Premier Packer MD- 11,033' TVD- 6,909' Size Authorized Signature: 7/9/2021 4.5" Perforation Depth MD (ft): L-80 m n P s 2 66 t y t _ c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:31 pm, Jun 09, 2021 321-285 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.06.09 14:25:51-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter X Photo document all steps including cutting windows, leak repair, site clearance and SC before and after patch VTL 7/6/21 10-404X DLB 06/09/2021 DSR-6/9/21 N/A DLB dts 7/6/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.06 17:16:44 -08'00' RBDMS HEW 7/7/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 09 June 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well ALP CD4-319 (PTD 205-148) to repair the Surface Casing. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.06.09 14:25:19-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ConocoPhillips Alaska, Inc. ALPINE WELL CD4-319 (PTD 205-148) SUNDRY NOTICE 10-403 APPROVAL REQUEST June 9, 2021 This application for Sundry approval for Alpine well CD4-319 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing. 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to ~20’. 4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to production. 13. File 10-404 with the AOGCC post repair. Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:CD4-319 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Subsidence Drift 10/6/2019 CD4-319 claytg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 114.0 Set Depth (TVD)… 114.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELD Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.84 Top (ftKB) 36.5 Set Depth (ftKB) 3,196.1 Set Depth (TVD)… 2,396.5 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.7 Set Depth (ftKB) 11,994.9 Set Depth (TVD)… 7,153.4 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 11,845.0 Set Depth (ftKB) 18,521.3 Set Depth (TVD)… 7,135.2 Wt/Len (l… 12.60 Grade L-80 Top Thread SLHT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 11,845.0 7,144.1 81.69 SLEEVE BAKER 'R' LINER SETTING SLEEVE 4.420 11,853.8 7,145.3 82.06 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 11,856.3 7,145.7 82.19 HANGER BAKER 'DG' FLEX LOCK LINER HANGER 4.400 11,865.6 7,146.9 82.82 XO CROSSOVER 5x4.5" 4.000 18,479.9 7,136.2 91.47 BUSHING BAKER PACKOFF BUSHING 2.380 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 33.1 Set Depth (ft… 11,788.7 Set Depth (TVD) (… 7,134.8 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 33.1 33.1 0.05 HANGER FMC TUBING HANGER 4.500 2,239.9 1,897.0 57.14 NIPPLE CAMCO 'DB' NIPPLE 3.812 10,773.7 6,755.1 49.14 NIPPLE HES 'X' NIPPLE 12.600 10,843.7 6,800.1 51.21 GAUGE WEATHERFORD 7500 psi POD2 GAUGE CARRIER 3.958 11,032.96,909.0 58.65PACKER BAKER PREMIER PACKER 3.875 11,089.1 6,937.1 61.35 NIPPLE HES 'XN' NIPPLE 3.725 11,782.8 7,133.7 79.05WLEG BAKER FLUTED WIRELINE ENTRY GUIDE 3.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 2,239.7 1,896.8 57.13 INJ VALVE A-1 INJECTION VALVE (S/N: 610431) ON 3.812" DB LOCK 10/6/2019 1.250 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 12,190.0 12,669.0 7,155.2 7,157.6 11/23/2005 99.0 SLOTS SLOTTED LINER 12,709.0 13,185.0 7,157.1 7,153.1 11/23/2005 99.0 SLOTS SLOTTED LINER 13,225.0 13,703.0 7,154.3 7,144.1 11/23/2005 99.0 SLOTS SLOTTED LINER 13,743.014,220.0 7,143.6 7,150.311/23/2005 99.0SLOTSSLOTTED LINER 14,261.0 14,657.0 7,149.8 7,150.2 11/23/2005 99.0 SLOTS SLOTTED LINER 14,897.0 15,413.0 7,142.7 7,149.7 11/23/2005 99.0 SLOTS SLOTTED LINER 15,453.0 15,894.0 7,150.2 7,151.8 11/23/2005 99.0 SLOTS SLOTTED LINER 16,171.0 18,480.0 7,143.7 7,136.2 11/23/2005 99.0 SLOTS SLOTTED LINER Notes: General & Safety End Date Annotation 12/4/2009 NOTE: View Schematic w/ Alaska Schematic9.0 12/4/2009 NOTE: *** THERE IS A 59' DISCREPANCY IN TUBING COMPLETION DEPTHS - NEEDS VERIFICATION *** 11/29/2005 NOTE: TREE: FMC GEN V / 5K psi - TREE CAP CONNECTION: STANDARD CD4-319, 5/29/2020 11:22:51 AM Vertical schematic (actual) LINER; 11,845.0-18,521.3 SLOTS; 16,171.0-18,480.0 SLOTS; 15,453.0-15,894.0 SLOTS; 14,897.0-15,413.0 SLOTS; 14,261.0-14,657.0 SLOTS; 13,743.0-14,220.0 SLOTS; 13,225.0-13,703.0 SLOTS; 12,709.0-13,185.0 SLOTS; 12,190.0-12,669.0 PRODUCTION; 34.7-11,994.9 WLEG; 11,782.8 NIPPLE; 11,089.1 PACKER; 11,032.9 GAS LIFT; 10,926.9 GAUGE; 10,843.7 SURFACE; 36.6-3,196.1 INJ VALVE; 2,239.7 NIPPLE; 2,239.9 CONDUCTOR; 36.0-114.0 HANGER; 33.1 WNS INJ KB-Grd (ft) 43.37 Rig Release Date 12/8/2005 CD4-319 ... TD Act Btm (ftKB) 18,683.0 Well Attributes Field Name NANUQ KUPARUK Wellbore API/UWI 501032051600 Wellbore Status INJ Max Angle & MD Incl (°) 95.03 MD (ftKB) 13,655.28 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Friday, May 21, 2021 11:36 AM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: CRU Injector CD4 -319 (PTD#205-148) Chris— Yesterday Operations found CRU Injector CD4 -319 (PTD#205-148) with low OA pressure, and was unable to pressure up the annulus. The well was on water injection service, and has been shut-in and freeze protected. We will perform diagnostics including a surface casing leak detect in the near future, and form a path forward based on those results. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Adam Earl Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 2, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD4 -319 COLVILLE RIV NAN-K C134-319 Sre: Inspector Reviewed By: P.I. Supry �`r— Comm Well Name COLVILLE RIV NAN-K CD4 -319 API Well Number 50-103-20516-00-00 Inspector Name: Adam Earl Insp Num: mitAGE190623113040 Permit Number: 205-148-0 Inspection Date: 6202019 ' Rel Insp Num: Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well CD4 -319 -Type Inj I W -iTVD 6908 Tubing 1452 - 1456 - 1452 1451 -p 1 Test SPT 'est ps� 1727 IA 340 2390 - —D25 - ->315 BBL Pumped: 2.4 T PTD zosws6 Type BBL Returned: � 2.4 - OA 42 90 ss so Interval 4YRTST - - P/F _I— P J✓ Notes: MIT IA i Tuesday, July 2, 2019 Page I of I • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,October 08,2015 TO: Jim Regg �� b� G��I5 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-319 FROM: Lou Grimaldi , COLVILLE RIV NAN-K CD4-319 Petroleum Inspector ®1�� ,1t! ti 's� ' % Src: Inspector Reviewed By: P.I.Supry ,..18t--- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-319API Well Number 50-103-20516-00-00 Inspector Name: Lou Grimaldi Permit Number: 205-148-0 Inspection Date: 10/2/2015 Insp Num: mitLG151002180601 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 cDa-319 Type Inj `` "TVD 6905 Tubing 1850 1855 - 1857 • 1856 .77 PTD 2051480 - 1Type Test SPT Test psi 1727 • IA 470 2606 • 2587 ' 2578 - --___-- t---- —_.---P �----- 655 663 664 •� 664 Interval 4YRTST p/F OA • Notes: 4.4 bbl's diesel pumped,4 bbl's returned.Good test,all pertinent paperwork supplied prior to test. +4-1•46c -S ' 0 ► re sc..e_s O Lao Thursday,October 08,2015 Page 1 of 1 1 ' S 0 tr dwa1a4og3 in N o C3 0 it . 1 . 1 I. .1. j , L .1. .4 I . 1.(1,,.1: . I . 1 .'. .I. .1 ' - i 6 _ U) 6. cn to - r a) 1s utt UCV a _ 111.0 If3 M Q1 O - 1s O (f) - r 7 us N ILL d — In ar°- r - W r I I l 'I i•I III I.1 I• I I III I'J 1' 1 I I 'l III t 111 1' I , j I- a- 0 0 0 0 0 O u. 0 0 U)0 IO OO ,O O CO CO N N T r ISd or • };11 111 tSlt9C�21Qo O WNS CD4-319 Conoco hiIIips Vials, Well Attributes Max Angle&MD TD Alaska.IncI Wellborn APW WI Field Name Well Status Ind C) MD(M(0) Act Bern(SKS) 501032051600 NANUOKUPARUK (NJ 9503 11655.28 18683.0 CommeH2S(ppm) Date Annotation I End Date KB-0rd(R) Rig Rebut Date "," Wee Conte - 1B 4040012453.20 AM SSSV.NIPPLE Last WO: L_._ 43.37 1282005 _CpaJ _- - - '-- -'-_ -_. Gmatic- Annotation Depth(MIB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:RESET INJ VALVE ninant 1 4242012 Casing Strings ~ Cuing Description String 0... String ID...Top(118) Set Depth IL.Set Depth(TVD)...String Wt...String d String Top Thr '.. WINGER 33 a ` r ■ CONDUCTOR 16 15.06236.0 114.0 114.0 62.50 H-40 WELD Casing Description String 0... String ID... Top(18(B) Set Depth(L.,Set Depth(TVD)-,String Wt...String...String Top Thrd SURFACE 95/8 8.835 36.2 3,196.1 2,396.5 40.00 L-80 BTC 4 r, P Casing Description l String 0... String ID...Top(1H(B) Sat Depth(f,.,Set Depth(TVD)_.String Wt...String...String Top Thrd - PRODUCTION I 7 6.276 34.6 11,994.9 7,153.3 26.00 L-80 BTCM Caning D0404pdo41 ;String 0... String ID...Top IBKB) Set Depth(l_.Set Depth(ND)...String Wt...String...String Top Thrd LINER j 41/2 1958 11,845.0 18,521.3 71352 12.60 L-80 SLHT CONDUCTOR. Moor36114 "lidiftri - --._ Top Depth It (TVD) Top bot ml... NooID nn a. Top(444) (a KB) 1") Item DesulpBon Comment ( NIPPLE.2240 11,845.0 7,144.0 81.42 SLEEVE BAKER'R'LINER SETTING SLEEVE 4.420 VALVE.2.240 L 11,853.8 7,145.3 82.02 NIPPLE BAKER'RS'PACKOFF SEAL NIPPLE 4.250 no 11,856.3 7,145.7 82.19 HUNGER BAKER Tom'FLEX LOCK LINER HANGER 4.400 11,865.7 7,146.9 82.82 XO CROSSOVER 5X4,5" 4.000 18,479.9 7,136.1 91.27 BUSHING BAKER PACKOFF BUSHING _.-- 2.380 SURFACE __ Tubing Strings 36.3196Tubing Description String 0.., String ID...Top(RKB) Set Depth(t_.,Set Dep--- (TVD)pth(TVD)...,String Wt...[String..!String Top Thrd `a TUBING 4 112 3.958 32.8 1 11,788.7, 7,131.2 j 12.60 1 L-80,,-_ IBTM NIPPLE.10.714 ------- t -+ Completion Details Top Depth (TVD) Top Intl Top(m(B) (*KB) t") it..Description Comment ID lin) GAUGE.14844--- - ® 32.8 32.8 -2.30 HANGER FMC TUBING HANGER 4.500 IIIII 2,239.7 1,896.5 57.13 NIPPLE CAMCO'DB'NIPPLE 3.812 fill 10,773.8 6,754.6 48.41 NIPPLE HES'X'NIPPLE 12.6... MIK 10,843.7 6,799.3 51.47 GAUGE WEATHERFORD 7500 psi PO02 GAUGE CARRIER 3.958 GAsrouaFT,_. IIIM. 11,033.0 6,907.2 58.18 PACKER BAKER PREMIER PACKER 3.875 111111 11,089.1 6,937.1 61.31 NIPPLE HES'XN'NIPPLE 37.~25 MOP 11,782.8 7,129.4 77.20WLEG BAKER FLUTED WIRELINE ENTRY GUIDE 3.980 1111, PACKER,_.- - IP - 71,033 , (ND) Top Ind -� Top(1148) (2K6) 1•)13 Description L __- - (S/N: ' --_ 1R3/0ata12 11.25 Alt 2,240 1,896,5 57.13 VALVE -1 INJECTION VALVE SM:HWS-0384 4/13/2012 1.250 r9PPLE,11.13W t :. Perforations&Slots _.-Shot MB IIIK Top(TVD) B4n(TVD( Dans Top(10(8)Bim(SKB) IID(B) (158) Son. Date (eh... Type Comment WLEG.11,7.3 .-. :� __ 12,190 12,669 7,155.2 7,157.8 11/23/2005 99.0 SLOTS SLOTTED LINER 12,709 13,185 7,157.1 7,151.7 11232005 99.0 SLOTS SLOTTED LINER 13,225 13,703 7,153.9 7,142.7 1123)2005 99.0 SLOTS SLOTTED LINER rill 13,743 14,220 7,143.6 7,150.4 11/23/2005 99.0 SLOTS SLOTTED LINER 14,261 14,657 7,148.9 7,150.2 -------� 11232005 99.0 SLOTS SLOTTED LINER --14.897 15,413 7,142.7 7,149.8 11232005 99.0 SLOTS SLOTTED LINER 15,453 15,894 7,150.2 7,150.6 11232005 99.0 SLOTS SLOTTED LINER 16,171 18,480 7,143.8 7,136.1 !11232005 99.0 SLOTS SLOTTED LINER hetes:General 4 SOOT End Date Annotation 11/29/2005 NOTE:TREE:FMC GEN V/5K psi-TREE CAP CONNECTION.STANDARD PRODUCTION 35.11 595 12/42009 NOTE:View Schematic w/Alaska Schematic9.0 12/42009 NOTE:"""THERE IS A 59'DISCREPANCY IN TUBING COMPLETION DEPTHS-NEEDS VERIFICATION SLOTS. 12.78012.680 1:I :1 SOTS. 12,7041La1e5 I I• 6 s BLOTS, I 13.22613,703 SLO2E1Ta.�e I. 13,74314, ii SLOTS,__ I I 14.161-14,657 �I I' ndrei Details _ Top Depth TopP rim_._- � SLOTS. illa 6 (TVD) Inti OD VNw Latah'Elsa TRO Run 14107.5.113�I I' 73fn TopIhItol 1111(8! C) Make I Medal Ib) Sen TYW Type lin) (pal) Run Dab Com... I1 10,927_0 6,850.3 54,45 CAMCO KBG-2 1 GAS LIFT DMV -BK 0,000 0.0 429/2006 s I SLOTS. __IlI II 15,153.15.99, 16,17,-011.480 SLOTS. :I UNER, 11. .S21 tg TO,19.663 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 17,2015 TO: Jim Reggj / P.I.Supervisor KO-r1 Vic 1c SUBJECT: Mechanical Integrity Tests 6 CONOCOPHILLIPS ALASKA INC CD4-319 FROM: Johnnie Hill COLVILLE RIV NAN-K CD4-319 Petroleum Inspector Src: Inspector Reviewed By P.I.Supry LJ c— NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-319 API Well Number 50-103-20516-00-00 Inspector Name: Johnnie Hill Permit Number: 205-148-0 Inspection Date: 6/12/2015 Insp Num: mitJWH150613214209 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Wellr CD4-319 (Type Inj N 1TVD T 6908 Tubing 480 7 480 - 480 " ' 480 - 2051480 SPT 1727 770 2154 - 2027 2016 PTD Type Testl Test pst � IA Interval 4YRTST - P/F P - OA 601 611 610 1 610 Notes: 4 5bbls diesel JUL .4. r ./..015 s.�►1111E© Wednesday,June 17,2015 Page 1 of 1 cat zes t4go Regg, James B (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, June 15, 2015 8:28 PM bli ( y To: Regg,James B (DOA) ;�iI ? l5 Subject: RE: CD4-PAD MIT-IA Attachments: CD4-319.pdf; CD4-12 90 Day TIO plot.JPG Jim- Attached is an updated copy of the wellbore schematic for CD4-319 (PTD 2051480 and the 90 day TIO plot for CD4-12 (PTD 2100910). As for the elevated pre-test IA pressure on CD4-12; the well was brought on MI injection on the 2"d of March 2015. The well initially was taking gas at a very minimal and sporadic rate. The well eventually began taking gas at slow but increasing rate which corresponds with the time in which IA pressure also began to increase. The IA increase to just below the "do not exceed" of 2400 psi for a gas injector and a bleed was performed to—1600 psi. The IA pressure from that point appears to have been influenced by changes in the injection rates and temperature as you can see similar increasing and decreasing trends over the 90 day TIO plot. The IA was left at the elevated pressure due to the fact that it was capable of maintaining a substantial differential pressure between the tubing (-4000 psi) while not needing additional bleeds to remain under the "do not exceed" of 2400 psi. After the passing state witnessed MIT-IA was performed, the IA was bled below the initial starting pressure and other than what is thought to be rate/thermally influenced changes in the IA it does not show indications of increasing IA pressure at this point in time. If you have any questions or concerns please feel free to contact us. Cheers Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 SCANNED JUL 0 2 2015 Cell phone: (907) 943-0450 WELLS TEAM ConocciPhinips From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, June 15, 2015 10:49 AM To: NSK Problem Well Supv Cc: Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Subject: [EXTERNAL]RE: CD4-PAD MIT-IA CD4-12 (PTD 2100910): pre-test IA pressure was 1999psi. Please explain the high pressure and provide previous 90day TIO plot CD4-319 (PTD 2051480): packer TVD should be 6938 ft based on well file Jim Regg 1 Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: NSK Problem Well Supv [mailto:n1617©conocophillips.com] Sent: Sunday, June 14, 2015 1:21 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Wallace, Chris D (DOA); Brooks, Phoebe L (DOA) Subject: CD4-PAD MIT-IA Attached is a copy of the SW MIT-lAs that were performed on the 12th of June. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 WELLS TEAM co,«.Philips 2 WNS CD4-319 Conocc liIIIps "0, Well Attributes Max Angle&MD TD Alaska Inc ' 1 Wellbore API/UWI Field Name Well Status Incl(°) MD(RKB) Act Btm(RKB) c.,nnc,ol+unq,, 501032051600 NANUG KUPARUK INJ 95.03 13,655.28 18,683.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date • ••• Well Confip:-CD4.319,42420129:53:20 AM SSSV:NIPPLE Last WO: 43.37 12/8/2005 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:RESET INJ VALVE ninam 4/24/2012 Casing Strings Casing Description String 0... String ID.,.Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd HANGER,33 CONDUCTOR 16 15.062 36.0 114.0 114.0 62.50 (1-40 WELD Casing Description String 0... String ID...Top(1 KB) Sat Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 36.2 3,196.1 2,396.5 40.00 L-80 BTC '/)'i • Casing Description String 0... String ID...Top(RKB) Set Depth(t..Set Depth(ND)...String Wt...String...String Top Thrd :-:"^ PRODUCTION 7 6.276 34.6 11,994.9 7,153.3 26.00 L-80 BTCM Ceasing Description String 0... String ID...Top(RKB) Set Depth(1...Set Depth(ND)..String Wt...String... String Top Thrd LINER 41/2 3.958 11,845.0 18,521.3 7,135.2 12.60 L-80 SLHT coNOU36-1 4 Liner Details Top Depth III (ND) Top Incl Nomi... IlL Top(11KB) (WB) (•) Rem Description Comment ID(in) NIPPLE.2.24011,845.0- 7,144.0 81.42 SLEEVE BAKER'R'LINER SETTING SLEEVE 4.420 VALVE,2,240 _! 11,853.8 7,145.3 82.02'NIPPLE BAKER'RS'PACKOFF SEAL NIPPLE 4.250 I 11,856.3 7,145.7 82.19 HANGER BAKER'DG'FLEX LOCK LINER HANGER 4.400 • 11,865.7 7,146.9 82.82 XO CROSSOVER 5x4.5" 4.000 18,479.9 7,136.1 91.27 BUSHING BAKER PACKOFF BUSHING 2.380 suRFACE. Tubing Strings 3G-3,1% Tubing Description String 0... String ID...Top(RKB) Set Depth(I...Set Depth(ND)...String Wt...String... String Top Thrd TUBING 41/2 3.958 32.8 11,788.7 7,131.2 12.60 L-80 IBTM NIPPLE,10.774 Completion Details Top Depth (TVD) Top Incl Nomi... St Top(RKB) (RKB) r) Rem Daaedptbn Comment ID(in) GAUGE.10.844 . 32.8 32.8 -2.30 HANGER FMC TUBING HANGER 4.500 2,239.7- 1,896.5 57.13 NIPPLE CAMCO'DB'NIPPLE 3.812 It 10,773.8 6,754.6- 48.41 NIPPLE -HES'X'NIPPLE 12.6... St 10,843.7 6,799.3 51.47 GAUGE WEATHERFORD 7500 psi PGD2 GAUGE CARRIER 3.958 GAS LIFT 11,033.0, 6,907.2 58.18 PACKER BAKER PREMIER PACKER 3.875 10.927 11,089.1 6,937.1 61.31 NIPPLE HES'XN'NIPPLE 3.725 It 11,782.8 7,129.4 77.20 WLEG BAKER FLUTED WIRELINE ENTRY GUIDE 3.980 all Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) PAC7'033 KER, � Top Depth 1 (ND) Top Incl Top(RKB) (RKB) P) Description Comment Run Date ,ID(in) It 2,240 1,896.5 57.13-VALVE A-1 INJECTION VALVE(S/N:HWS-0384) 4/13/2012 1.250 i NIPPLE,11,089III. Perforations&Slots Shot MB Top(ND) Min(ND) Dans lop(MB)She(SKS) IRKS) (RKB) Zone Date (oh••• Type Comment WLEG,71,783 12,190 12,669 7,155.2 7,157.8 11/23/2005 99.0-SLOTS SLOTTED LINER 1 12,709 13,185 7,157.1 7,151.7 11/23/2005 99.0'SLOTS SLOTTED LINER t 1 13,225 13,703 7,153.9 7,142.7 13,743 14,220 7,143.6 7,150.4 11/23/2005 99.0 SLOTS SLOTTED LINER 11/23/2005 99.0 SLOTS SLOTTED LINER 14,261 14,657 7,148.9 7,150.2 11232005 99.0 SLOTS SLOTTED LINER 14,897 15,413 7,142.7 7,149.8 11232005 99.0 SLOTS SLOTTED LINER 15,453 15,894 7,150.2 7,150.6 11232005 99.0 SLOTS SLOTTED LINER 16,171 18,480 7,143.8 7,136.1- 1123/2005 99.0 SLOTS SLOTTED LINER Notes:General&Safety End Date Annotation 11/29/2005 NOTE:TREE:FMC GEN V/5K psi-TREE CAP CONNECTION:STANDARD PRODUCTION, A 35-71,995 12/4/2009 NOTE:View Schematic w/Alaska Schematic9.0 12/4/2009 NOTE:***THERE IS A 59'DISCREPANCY IN TUBING COMPLETION DEPTHS-NEEDS VERIFICATION SLOTS. 12,190-12,669 I.. SLOTS, 12,70&13,185 -•�, I ••• 1 1,... 13.22573, SLOTS.703 'lldtl'1 1_ I 13,743SL4G30 - li II SLOTS, -/ I 71,261.1 OTS. 11' I 47 Mandrel Details 111 II Top Depth Top Port T, 1 1 (ND) Incl OD Valve Latch Sian TRO Run 14,897-S15LO;7S3 ice„1 1 Stn Top(RKB) (RKB) (°) Make Model (in) Sery Type TTM PM (PO Run Date Com... 1 10,927.0 8,850.3 54.45 CAMCO KBG-2 1 GAS LIFT'DMY 'BK 0.000 0.0 4/29/2006 , _..a„. 15,453.S1LO5,89TS4 ',1 I SLOTS. 16,171-78,460 4. : "'' LINER, 11,845-75,521 .1 l TO 18,683 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~- 1 ~- ~ Well History File Identifier Organizing (done> ^ Two-sided III II'lll II III II III ^ Rescan Needed III IIIII II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) ~olor Items: Diskettes, No. I ^ Maps: ^ Greysca(e Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: BY: Maria Date: a (.7 ^ Other:: /s/ Protect Proofing III 111111 IIIII IIIII BY: aria Date: V /s/ ' Scanning Preparation _~ x 30 = ~ 2 ~ + ~~ =TOTAL PAGES ~~~ I ~ (Count does not i ~ dude cover sheet) ,/~/~ ~ ' BY: Maria Date: ' ~ ~ ~ / ~l ~ ' Production Scanning Stage 1 Page Count from Scanned File: ~J(Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ' (~,~~ V /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II IIIII ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked 10/6/2005 Well History File Cover Page.doc • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: P.I. Supervisor � DATE: Tuesday, July 05, 2011 Jim Rp , leti SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4 -319 FROM: Matt Herrera COLVILLE RIV NAN -K CD4 -319 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv NON- CONFIDENTIAL Comm Well Name: COLVILLE RIV NAN -K CD4 -319 API Well Number: 50- 103 - 20516 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFHII0701085529 Permit Number: 205 -148 -0 Inspection Date: 6/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4 -319 Type Inj. W ' TVD 6938 - IA 245 2830 2767 2750 ' P.T.D 2051480 ' TypeTest SPT Test psi 1734 - OA 610 610 620 625 Interval 4YRTST _ P/F P - Tubing 2085 2067 2067 2065 Notes: IA tested to 2800 psi 5.3 BBL's F }fit; A Tuesday, July 05, 2011 Page I of 1 • MEMORANDUM T~~ Jim Regg P.I. Supervisor ~~'~lq ~(~l U`'~ C FROM: Bob Noble Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 29, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-319 COLVILLE RIV NAN-K CD4-319 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~l~- Comm Well Name: COLVILLE RIV NAN-K CD4-319 API Well Number: 50-103-20516-00-00 Inspector Name: Bob Noble Insp Num: mitRCN090729093723 Permit Number: ZOS-148-0 / Inspection Date: ~~23/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ CD4-319 TyPe Inj. W 'r~ 6938 IA 867 2818 '~ 2772 2771 P.T.D 2051480 TypeTest SPT TCSt PSl 28~g -' ~E~ 411 438 438 439 Interval 4YRTST P~ P '~ Tubing 1950 1950 1950 1950 Notes: M.~ ~ ~~es~- p~s~,~~ ( 7 34- ~s; ~ . FAt}, y ~~ e tia'.u rs ~ ~ ~ G k~ #~w r., E~ u • . .. ~,. .. Wednesday, July 29, 2009 Page 1 of 1 i ,nw-, ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 ~~ lF~~~! Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: acs- i~~ ~°I G~ ~. 3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 18~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sinc Perry ~~~~~ ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18/2009 CD4-306 207-094 SF NA 5" NA 1.70 3/18/2009 CD4-07 207-118 SF NA 6" NA 0.42 3/18/2009 CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 CD4-210 206-077 SF NA 7" NA 1.27 3/18/2009 GU4-Z71 L06-153 9" NA 9" NA 3.82 3/18/"LUUy CD4-214'' 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 ~ 206-157 5" NA 5" NA 2.55 3/18/2009 CD4-16 206-131 SF NA 5" NA 2.55 3/18/2009 C 4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321' 206-142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18/2009 rw- F:~LaserFicheiCvrPgs_InsertstMicrofilm Marker.doc Permit to Drill 2051480 ~~ DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Well Name/No. COLVILLE RIV NAN-K CD4-319 Operator CONOCOPHILLIPS ALASKA INC API No_ 50-103-20516-on-00 Completion Date 11!29!2005 Completion Status 1-OIL Current Status WAGIN UIC Y Mud Log No Samples No Directional Su y Yes GR/Res/Dens/Neutron (data taken from Logs Portion of Master Well Data Maint MD 18684 TVD 7132 REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run Well Log Information: Log/ Electr Data Digital Dataset T~ Med/Frmt Number Log Log Run Interval p}.I / Scale Media No Start Stop CH Received Comments C Lis 1378'Iz' Induction/Resistivity D Pdf ~gc;.~ Directional Survey Cement Evaluation 13781 LIS Verification (L6g Production ~D C Pdf 13969LNeutron t~D C Pdf 13969 'Neutron ~D C Pdf 13969`- Gamma Ray ~D C Pdf 13969 ~ Rate of Penetration ~D C Asc 13969 ~ LIS Verification ~D C Lis 139691nduction/Resistivity Log 14057 Induction/Resistivity i L~ 14057 Induction/Resistivity ~~~ ~ ~.t5 ~/ jKC1J ? T1~~',..~~IW,-. v 114 11958 Open 3/9/2006 DGR EWR4 CTN ALD ACAL PWD SLD 0 0 1/17!2006 DEFINITIVE SURVEY 5 Col 1 9000 11779 1/9/2006 ULTRASONIC IMAGER CEMENT/CORROSION LOG USIT/GR/CCL 114 11958 Open 3/9/2006 DGR EWR4 CTN ALD ACAL PWD SLD 5 Blu 1 10970 14140 Open 3/24/2006 Production Profile w/Deft with WeIITec Tractor 14- Mar-2006 , 1-3 168 7154 6/27/2006 CNO, SLD, ALD 28-Oct- 2005 1-3 168 12005 6/27/2006 CNO, SLD, ALD 28-Oct- 2005 1-3 168 7154 6/27/2006 DGR, EWR 28-Oct-2005 1-3 168 12005 6/27/2006 ROP, DGR, EWR Horizontal Presentation 28 Oct-2005 1-2 114 3196 6!27!2006 LISTPE 3-Mar-2006 114 11928 Open 6/27/2006 RHOB, DRHO, NCNT, NPHI, EWR4, GR, ROP 25 Blu 168 18683 Open 8/23/2006 Res, MD Final Composite 24-Nov-2005 w/Graphics 25 Blu 168 18683 Open 8!23/2006 Res, TVD Final Composite 24-Nov-2005 w/Graphics DATA SUBMITTAL COMPLIANCE REPORT 1/29/2008 Permit to Drill 2051480 Well Name/No. COLVILLE RIV NAN-K CD4-319 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20516-00-00 MD 18684 TVD 7132 Completion Date 11/29/2005 Completion Status 1-OIL Current Status WAGIN UIC Y og See Notes 5 Cof 1 11200 18400 Case 7/3/2007 Maxtrac (PROF, Spin, Pres, Temp, Tractor 17- '~ Jun-2007 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~N Daily History Received? ~/ N Chips Received? -Y-7'N-- Formation Tops ~ N Analysis ~F-f-N" Received? Comments: Compliance Reviewed By: Date: w-,. ~~ ~ RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION .JUN 2 9 2007 REPORT OF SUNDRY WELL OPERATION,S.~.t,n n:~ 9. r`~_ ~_~_ r•,......_:__:__ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other AnCi~ra ~ ~- ~ ` Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ ^ ~~ Waiver ^ Time Extension ` -~ _ ~ ~~ Change Approved Program ~ Operat. Shutdown^ Perforate ^ ~~ Re-enter Suspended Well ^ ~ J 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 205-148 ~ ~ 3. Address: Stratigraphic ^ Service Q - 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20516-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 56' CD4-319 8. Property Designation: 10. Field/Pool(s): ADL 380077, 384209 Colvile River Field/Nanuq Oil Pool 11. Present Well Condition Summary: Total Depth measured 18684' feet true vertical 7132' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 3140' 9-518" 3196' PRODUCTION 11939' 7" 11995' SLOTTED LINER 6676' 4-1l2" 18521' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 11847' MD. Packers &SSSV (type & measured depth) Baker Premier Packer set at ~ ~os2' SSSV= NIP SSSV= 2297 12. Stimulation or cement squeeze summary: Intervals treated (measured) p~+ ~U~ ~ ~ ~Q~~ Df~6 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 4000 2000 None Subsequent to operation 15155 f 1293 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ ~ Daily Report of Well Operations _ 16. Well Status after proposed work: Oil^ Gas^ WAGQ ° GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIa if C.O. Exempt: 306-343 contact Jack Walker Printed Name Jack Walker Signature Title Phone 265-6268 Production Engineer Date ~ Z~ ~ ~ ') "v- ~ Pre ared b Jeanne HHaa 263-4470 t" I` v O R{ G I N A L ~< ~~ ~l~°~ ~~ ,.,~.o~ Form 10-404 Revised 04/2006 Su mit riginal Only ~. ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Walker, Jack A [Jack.A.Walker@conocophillips.com] Sent: Wednesday, July 25, 2007 11:23 AM To: Maunder, Thomas E (DOA) Subject: RE: CD4-319 (205-148) and CD4-209 (206-065) Tom, CD4-319 started injecting on December 2, 2006. It's production test period ended in March 16, 2006. CD4-319 was shut in during the interim, waiting on drill site facilities. CD4-209 acid treatment was pumped on April 12, 2007. The following is a more complete CD4-209 treatment report from 4/12/07 than the original 10-404: Lay in 12% HCl acid from 13,1SS' to 6,991' CTMD with coiled tubing. Pump acid at 1.7 bpm white taking returns to tanks. CTP pressure = 3100 psi, with average WHP ~ 280 psi. Freeze protect well to 2000' MD with diesel. Please let me know if there is any other info needed. Jack From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Wednesday, ]uly 25, 2007 10:55 AM To: Walker, Jack A Subject: CD4-319 (205-148} and CD4-209 (206-065} Jack, You recently submitted 404 reports of sundry operations for these wells. A lithe further information is needed. CD4-319 -- would you provide the date that the well was converted from a producer to injector. CD4209 -- would you provide the date when the well was stimulated. Thanks in advance. Tam Maunder, PE AOGCC 7/2S/2007 os/z8/o7 ~Cb~l~~~l'~P~ Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth N0.4311 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Well Job # Log Description Date Color BL Prints CD CD4-302 11665451 USIT 06/19/07 1 CD4-319 11665448 MAXTRAC (PROF 06117107 1 SIGNED: DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. MEMORANDUM Toy Jim Reg ~` P.I. Supervisor~~~ ~~~ Ct~~, 1 FR01t: John Crisp Petroleum Inspector State of Alaska ~~ Alaska Oil and Gas Conservation Commission DATE: Wednesday. January I7, 2007 SUBJECT: Mechanical Inteerity Tests CONOCOPHILLIPS ALASKA INC CDa-3 19 COLVILLE RIB' NAN-K CD4-319 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: COLVILLE RIV NAN-K CDa-319 API Well Number 5 0-1 03-205 1 6-00-00 Inspector Name: John Crisp Insp Num: mitJCr0701 t7o5at37 Permit Number: 2o5-tab-o Inspection Date: vt V20o7 Rel Insp Num Packer Depth Pretest Initial 151VIin. 30 Min. ~5 Min. 60 Min. YP J -- 693s --- ------ Well I cDa si9 IT a In'. ' w I TVD ', IA i319 I96o I9ao j I93o - - --- - P.T. '~ ~osi~so ~TypeTest sPT I Test psi t~~a.s ~ OA ' Asa ~zs 6zo biz Interval rnITU PlF P Tubing ~ Iaso Iaso ~ Iaso Iaso ~~ ~ - - I NOteS .7~ bbl pumpad for test. No problems Wednesday, January I7. 2007 Pale l of 1 L1110.11111 ~. l~lll VL\V I. L.J V1'LL-V /.AIJ~ t~llt L.1\V L.~V`t Vl'1L~V /.,<lJ M Subject: Emailing: iYIIT CRU CD3 01-12-07.x1s, ~VIIT CRU CD4 01-I2-07.x1s From: NSK Problem Well Supv <n1617(c~~conocophillips_com> Date: Sun, 14 Jan 2007 10:30:08 -0900 To: bob_fleckenstein@admin.state.ak.us, jim re~~~adtnin.state.ak.us, Thomas E iVlaunder <tonl _maunder@adYnin. state.ak.tis> « MIT CRU CD3 01-12-07.x1s» Ge «MIT CRU CD4 01-12-07.x1s » ntlemen, Enclosed are the initial MITIA results for CD3-110, CD4_-319, and CD4-321. ,~, ~OS-1~ Regarding the T X IA communication in CD4-321 PTD # 206-142, reported 12/23/06, the CMD was found to be in the open position. Slick Line closed the sleeve. After passing the witnessed initial MITIA I removed CD4-321 from the monthly failed MITIA report. Let me know if you .have any questions. Sincerely, Perry Klein Problem ~Aell Supervisor office (907} X59-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 -- Content-Description: MIT CRU CD3 01-12-07x1s MIT CRU CD3 01-12-07.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT CRU CD4 O1-12-07.x1s 'MIT CRU CD4 01-12-O'7.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 1/16'2007 4:03 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 2Q5-14$_ ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-319 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ Q WDSPL ^ 50-103-20516-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final ~ 305-373 12/7/2005 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 389* 389 totals (bbls): 2005 / 4tn 12618 100 0 12718 13 12/19/2005 12/31/2005 CD4-208, CD4-318 Zoos/1st 12328 100 0 12428 12 1/1/2006 1/18!2006 CD4-318 2006 / 2nd 4398 100 0 4498 6 5/24/2006 5/29/2006 CD2-404, CD4-209 20o6/3rd 1877 100 0 1977 1 7/1/2006 7/1/2006 CD4-320 Total Ending Report is due on the 20th volume 31221 400 389 32010 32 Ex: of the month following the final month of the quarter (bbls): . July 20 for the second quarter, April 20 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze rotect volumes and in~ectivit test to th e st of my knowledge. be I hereby certify that the fore Is true and corre~c`t ~ '~ - -~ ~ Si `~-~`-~~ ~ ti'~-'~- D I /1~°'~O gnature: ate: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 r L Form 10-423 Rev. 212004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~. ' '~ i FRANK H. 1WURKOUVSKI, GOVERNOR _ ~ . a ~ ~ , " ~-7~~ OfiJ t>•tsii ~ 333 W. T" AVENUE, SUITE 100 COI~TSERVATIOI~T COIrII~IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jack Walker Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq-Kuparuk Oil Pool, CD4-319 Sundry Number: 306-343 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, Cathy P. Foerster Commissioner DATED this day of October, 2006 Encl. ~- , < ~~u .. ;< • STATE OF ALASKA ~~C~iv~a ~~~~_ O C T 0 6 Z~a6~ ALASKA OIL AND GAS CONSERVATION COMMISSION AtaSka Oil & Gas COfiS. COit1mISS10tT APPLICATION FOR SUNDRY APPROVAL p h 20 AAC 25.280 nc Drags 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ L~f+~i/t~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ ~ r~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 205-148 ~'~ ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number; P. O. Box 100360, Anchorage, Alaska 99510 50-103-20516-00 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? Y@S ^ NO Q CD4-319 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): RKB 56' #N/A 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (n): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18684' 7132' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 3140' 9-5/8" 3196' PRODUCTION 11939' _ 7" _ 'F1995' SLOTTED LINER 6676' 4-1/2" 18521' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1 /2" L-80 11847 Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 2297' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ /J Q.o Service ©~• 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: November 15, 2006 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representativ 18. I hereby certify that the ifNegoing is true and correct to the best of my knowledge. Contact: Jack Walker @ 265-6268 Printed Name .1 ~ W er , ~c~iZ~~ ~if2Sy ~~- Jc.~C~ ~~~~@: Production Engineer ,, Signature /f ~ Phone 265-6268 Date j~p ~~ O .Commission Use Onl Sundry Number: Conditions of appr al: Notify Commission so that a representat ive may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: S ~~~ o c ~ ~ ~~ 2oah Subsequent Form Required: ~~~ J p APPROVED BY -~ / O / (Q Approved by: OMMISSIONER THE COMMISSION Dat Form 10-403 Rev~sed 06/2006 ~ j R l.r t ~ Submit in Duplicate ao~- t~ i~'C:iANICAL INTEGRITY REPORT ..: ~liD L " - l©/`~~ `"o~ OPER ~ FZELD ~P ps ~ ~~. ~C '-L~~RJ~ _ _ _ ~\~~4"0 ~ ~~LL 5~ .c ~ NUMBER ~>y -~`~ ._~ . .. .... . .~ ~ LL DAT =_ TD : 1~56~5~t.?~.. ~~3~ Tti'D ; ?BTD : '~. '-~ ~ TVD i i ~,t Shoe: \1~c`~ID ''115--TVD; DV: t~G~- ?~ 1~1~ T~`Di as ~`g: ~`~ e~~ t~ l-/~ c h o e 1 ~.5~-\ ~ X113 ~ T~~D ; : C ~ 1~ ~y5 }-~ '1 ~y`~ _'; ~ ---1 - ., _ ~ ~„r . ~-il l ~ P acicer ~-1Q~--~3 - - - T'~i Set a t 1 \FS~~ v _ P e r ~ ~ S` O ~~ `~~ ~C- ole S_~e ~~ and ~ ~~~ -- •V`~= C'r'..r~?~?C~~ INTEGR.ZTY - P Q.RT # 1 :_n.:ulus Press Test: Comments: `~ 1 S coin .3 0 min 13~s~ ~~~ -~ ~~ b-als ~' CHA?~ I Cry ZNTEGRIT'*" - PART # 2 ~ ~~ ` a 3 b4~\ ~ (~ V y J ~11 ~ L r~ ~ ~ ~ 1 t s-t `~ Cement Voles :~ ~.mt. Liner ~p, ~ CsQ ~ DV `~ZX.c~rc~S ~o ~~ aloovre_~~00~~s -~-o Cov~F-~JG~nc~ ~~~~ C.rt -rot to cover oer_s \. - =eoretical TCC -~~r~p~~~cc~,` ~~` ~ ~~(~~~ ~.~ r1 ~ o~ _ Cement Bond Log (Yes or No)_~`(~C~S -~ In AOGCC File \~ ~ CBL Evaluation, gone aoovp ner*'s C S vJS ~C~`~~- Production Log: Tyne Evaluation CONCLJS ~ OI1S : • ?art i 1 ? t T 6 r . .. ~..+r-''~~- ~G~' _ / i t O~1 ~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL. 1. Operator: 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 205-148 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-319 2. Address: 4b. Well Status: Oil ^ Gas WAG 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ Q WDSPL ^ 50-103-20516-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation Q or Final ^ 305-373 12/7/2005 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 389"` 389 totals (bbls): 2005 ! 4th 12618 100 0 12718 13 12/19/2005 12/31/2005 CD4-208, CD4-318 2006! 1st 12328 100 0 12428 12 1/1/2006 1/18/2006 CD4-318 2006 / 2nd 4398 100 0 4498 6 5/24/2006 5/29/2006 CD2-404, CD4-209 2006 / 3rd 1877 100 0 1977 1 7/1/2006 7/1/2006 CD4-320 Total Ending Report is due on the 20th volume 31221 400 389 32010 32 (bbls>: of the month following the final month of the quarter. Ex: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze rotect volumes and in~ectivit test I hereby certify that the foregoing is and correct to the best of my knowledge. Signature: Date: t6 ~6 ~b 6 Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2!2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate U =C_ ~qDS- I'~/mod Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth Well Job # ~~~~ V ~~ AUG 2 3 2006 ~ ~ Bc ~ (,'Oils. COfif I-ISSIOft Af1C(10ta(~ Log Description Date NO. 3932 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color BL Prints CD CD4-319 40012651 MD VISION RESISTIVITY 11/24/05 1 1 CD4-319 40012651 TVD VISION RESISTIVITY 11/24/05 1 SIGNED: ~ DATE: '~'I s~3frY Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. 08/22/06 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number. 205-143'' ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-319 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ~ WDSPL ^ 50-103-20516-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 305-373 12/7/2005 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls); Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 389* 389 totals (bbls): 2005 / 4th 12618 100 0 12718 13 12/19/2005 12/31/2005 CD4-208, CD4-318 2006 / 1st 12328 100 0 12428 12 1/1/2006 1/18/2006 CD4-318 2006 / 2nd 4398 100 0 4498 6 5/24/2006 5/29/2006 CD2-404, CD4-209 2006 / 3rd 0 0 0 0 Total Ending Report is due on the 20th volume 29344 300 389 30033 31 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and in~ectivi test 1 hereby certify that the foregoing is true and correct to the best of my knowledge. ""`.•. -~ CI o h ~ Signature: ~.~~~ l,"-------~ Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate WELL LOG TRANSMITTAL To: State of Alaska June 15, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-319, AK-MW-4025926 CD4-319: 1 CD Rom with LDWG formatted LIS data & Graphic Log Images (EMF, CGM, & PDF formats). 50-103-20516-00 PLEASE ACKNOWLEDGE RECEIl'T BY SIGNING AND RETURNIl~TG THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~+c~~vEa Date .: ~, ; Signed: l~&Gas Cons. Commission Anchorage aw. awyu..,av w ii ~.,vv ai. aaauas avia~~, vvu«.i u~ ~.a~-t Subject: Re: Request to inject Drilling Rinse water at CD4 From: Thomas Maunder <tom_maunder@,admin.state.ak.us> )Date: Thu, 25 May 2006 11:23:14 .0800 To: ALP Cnst Env Coord <ALPCnstEnvCaord@conocophillips.cam> CC: Jim Regg <}im_re~gGadmin.state.ak.us> ~.._ Chuck, ~~ S-_ ~ Your plan is acceptable. This approval is specific for the wash water volume you specify in the 2nd paragraph of your message. Please call or message with any questions. Tom Maunder, PE AOGCC ALP Cnst Env Coord wrote, On 5/25/2006 9:56 AM: Tom: As per 20 AAC 25.080 (d-e) disposal of drilling waste is not authorized through the annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste except upon approval from the Commission on a case-by-case basis. As we discussed on the phone this morning, CPAI Alpine is requesting annular disposal of approximately 300 bbl of drilling wash water that was generated at CD-2 404, within the annulus on CD4-319. This rinse water was generated by cleaning out the rig pits and floor and therefore in contact with only Class II material /fluids. The mixture is not materially different from the expected waste stream that will be generated and normal{y disposed of via annular disposal at CD4. Annular disposal of this rinse water was not possible at CD2 56 as the well has pressured up. This fluid was then sent for injection in the Class II injection well, CD1-19A, but unfortunately both our injection skid (conversion to high line power) and Hot Oil injection truck (clutch brake on injection pump) are down. We expect the Hot Oil injection truck to be up and running in a couple of days. Annular disposal of this 300 bbl will allow the rig to begin hauling mud and keeping up with the current drilling schedule. As you indicated, CD4 319 had pressured up yesterday. It was determined to be an ice plug in the well. The rig was able to breakthrough this plug and well is now functioning properly. Thank you in advance for considering this request. Please contact me if you have any questions or comments. I look forward to hearing from you. Chuck Chuck Wheat /Henry Platt Alpine Construction Environmental Coordinators Phone: 907-670-4423 Fax:907-670-4507 1 of 1 5126!2006 7:08 AM ~ ~ STATE OF ALASKA ~°5; ~ ~ ~ 's ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~~~~~ ~~~ ~~ `~~~~~'~~t°~~ I~~rnr=aos:~ian 1. O erations Performed: Abandon p ^ Repair Well ^ Plug Perforations ^ k ~ ~~ `~ Stimulate ^ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program Q Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 205-148 / 3. Address: Stratigraphic ^ Service^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20516-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 56' CD4-319 8. Property Designation: 10. Field/Pool(s): Nanuq-Kuparuk 11. Present Well Condition Summary: Total Depth measured 18684' feet true vertical 7132' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Surst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 3140' 9-5/8" 3196' PRODUCTION 11939' 7" 11995' SLOTTED LINER 6676' 4-1/2" 18521' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 11847' MD. Packers &SSSV (type & measured depth) Hydraulic-set permanent, ~ 1092' SSSV=NIP SSSV= 2297' 12. Stimulation or cement squeeze summary: ~~ ~~~ ~~~ ~ ~ 200 Intervals treated (measured) not applicable ' ' 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 welt operation 4000 2000 -- -- - Subsequent to operation -- -- 7500 bwpd 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run ~ X Exploratory ^ Development ^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: 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 NIA if C.O. Exempt: 306-077 Contact Jack Walker @ 265-6268 Printed Name Jack~W~Iker Signature ~ ~~ Title Production Engineer // / Date 3 f j p 10~ Phone ZG ~ 2 ~~'~~(.~ G 2 iL (0 ~ ~ Form 10-404 Revised 0412004 Q R ! ~ 1 ~ A L Su it Or' final Only ,~r.~/°~ ~r y CD4-319 Well Operations AOGCC Sundry 306-077 March 30, 2006 Sequence of Events 3/8/06 22:00 Begin flowback. Rate history attached. 3/9/06 11:00 Choked well due to tanker truck down time and disposition site demand for cuttings handling. 3!9!06 23:00 Disposition site shut down forced CD4-319 shut in. 3/11 /06 3/11 /06 19:30 3/12/06 3!13/06 3114!06 3/14/06 17:00 3/15/06 5:00 3/15/06 8:15 3!15106 21:46 3/16/06 12:15 Disposition site restarted taking CD4-319 oil. Clean up complete, choked well for bottomhole sampling. Collected 4 bottomhole samples. Attempted horizontal well production log via tractor. Tractor failed. Trouble shoot tractor. Run in hole with production log tools and tractor. Begin production logging. Open choke for production logging. Rig down production logging unit. Shut-in well. Production -Clean Up Operations 133 bbl deisel load 2750 STB crude ~ 274 bbl mud solids & water 1394 MSCF gas flared Production -Sampling/Logging/Test Operations 3863 STBO 1 31 bbl BS&W 2038 MSCF gas flared Gas flaring to be reported separately with Colville River Field Facility Report of Produced Gas Disposition (10-422). Pressure data from monitoring well, CD4-318, to be provided in supplemental report after pulling battery-powered pressure recorders. 5000 -- 4500 N Q 4000 U ~ 3500 O m ~ 3000 N ~' 2500 a -v m s 2000 a~ ~; 1500 a~ c~ ~ 1000 c~ - 500 O 0_ - 3/8/06 3/9/06 3/10/06 3/11 /06 3/12/06 3/13/06 3/14/06 3/15/06 3/16/06 12:00 12:00 '12:00 12:00 12:00 12:00 12:00 12:00 12:00 50 45 LL 40 0 a~ 35 a~ n E 30 ~ c~ 25 ~ a~ 20 °~ a 15 ~ 10 ~ 5 m 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: ~ '' 205-148 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-319 2. Address: 4b. Well Status: Oil ^ Gas WAG 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^~ WDSPL ^ 50-103-20516-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 305-373 12/7/2005 COlVllle River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 389* 389 totals (bbls): 2005/atn 12618 100 0 12718 13 12/19/2005 12/31/2005 CD4-208, CD4-318 2006 / 1st 12328 100 0 12428 12 1/1/2006 1/18/2006 CD4-318 2006 / 2nd 0 0 0 0 2006 / 3rd 0 0 0 0 Total Ending Report is due on the 20th Volume 24946 200 389 25535 25 (bbls): of the month followin the final month of the uarter. Ex: g q April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and in'ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ~ Date: ~7`r?fie 6 Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-319, i March 06, 2006 AK-MW-4025926 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20516-00. G Ci~,~ ~'~~E~ ~( l"~a~ ~+~t ~, os - l`t~ ~; r~.,s ~ i ~~ y~~s i ,~ '~~ ~ ~~'°~' ~ ~I~"~,-~ ," ~" ? ~ ~ ~~'3 ~{ FRANK H. MURKOWSKI, GOVERNOR ~i tam ~t ~ ~+ ~ ~~ OIL ~ uva7 I~ 333 W. T" AVENUE, SUITE 100 COI~TSERQATIOI~T COMl~'II5SIOI~ ' ANCHORAGE, ALASKA 99501-3539 ~°~ PHONE (907) 279-1433 FAX (907)276-7542 Jack Walker Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Nanuq-Kuparuk Field, CD4-319 Sundry Number: 306-077 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 attachment to the enclosed, approved form 10-403. 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, Cathy . Foerster Commissioner DATED this ay of March, 2006 Encl. STATE OF ALASKA ~ECE~VED ~KA OIL AND GAS CONSERVATION COMMIS ~'~~ APPLICATION FOR SUNDRY APPROVALS `MAR U 2 2006 ~n nnr~ ~~ ~Rn A1ac4~ n:~ n „ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver h Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Anchorage Change approved program0 Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Dril l Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ / 205-148 l/ 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 100360 Anchorage, AK 99510 505-103-20516-00 7. KS Elevation (ft): 9. Well Name and Number: RKB 56 ft CD4-319 8. Property Designation: 10. Field/Pools(s): ADL38077 Nanuq-Kuparuk 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18684 7132 Casing Length Size MD TVD Burst Collapse Structural n/a Conductor 114 16" 114 114 Surface 3140 9 5/8" 3196 2396 5750 3090 Intermediate n/a n/a n/a n/a n/a n/a Production 11939 7" 11995 7153 7240 5410. Liner 6526 4 1/2" 18521 7135 n/a n/a Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): n/a n/a 4 1/2" L-80 11848 Packers and SSSV Type: 4.5" x 7" Baker Premier Packer Packers and SSSV MD (ft): SSSV: 2297 ft MD Camco 4-1/2" SSSV Packer: 11092 ft MD 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/12/2006 Oil [~ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: ~ / J~ 3 ~ .~ 17. 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 one 265-6268 Date 3/1!2006 COMMISSION USE ONLY Conditions of a roval: Notif Commission so that a re resentative ma witness Sund `~ 4 ! Number: ~O y pp y ry p 1.5~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: f~E /,`TTAtM~Q G.rfT OC ~oN~s7-~oNS OF /}~~R~~~~ ~ rv ` _. ~1~3 c~,v~rce~ ~~ cE~.~~`~'v~,E,l~ ~ Z~~~~~ib~ Subsequent Form Required: ~~ ~ ~-,~~~ ~~ ~ ~~~ ~~~ ~ ~ ~~~ V ~ 2~~6 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3 ~ O rv I ORIGINAL r~issian CD4-319 was drilled and completed as a slotted liner, horizontal producer in the Nanuq-Kuparuk Oil Pool. The application for its permit to drill included an injection pulse test. A production pulse test is now planned with at least 10,000 barrels of oil to be produced from CD4-319. Because drill site facilities are under construction, associated gas will be flared. The CD4-319 production test will create a pulse that will be monitored via bottom hole pressure recorders in CD4-318. CD4-319 will shut in after the production pulse, and will begin injection the fourth quarter of 2006. ~~~~' ~,~~~ Form 10-403 Revised 07/2005 / ~ ,3 ~'~~ Submit in Duplicate • • Sundry Application 306-077 Conditions of Approval 1) Total volume of all liquids produced cannot exceed 7,000 stb, unless a larger volume is necessary for proper well cleanup, 2) Should the 7,000 barrel limit be exceeded for well cleanup purposes CPAI must obtain commission approval before producing any additional volumes for the purpose of well testing, 3) CPAI must take all prudent steps to minimize the amount of fluid produced and gas flared or vented, 4) CPAI must provide the commission with a report on the well cleanup and production testing operations within 30 days of completion of the test. The report must include: a. A detailed timeline of well cleanup and testing operations including significant flowrate changes, b. Volume and type of liquids produced and volume of gas flared or vented during well cleanup operations, c. Volume and type of liquids produced and volume of gas flared or vented during well test operations, and d. Copies of all production logs and pressure survey results, both in the CD4- 319and CD4-318 wells, obtained in conjunction with these operations. 5) In accordance with 20 AAC 25.235(b) CPAI must submit a Facility Report of Produced Gas Disposition (Form 10-422) for the volume of gas that was flared or vented in excess of what was required for well cleanup operations. Gas flared or vented during the well cleanup operation is incidental to normal oil field operations and will be considered de minimis under 20 AAC 25.235(d)(4) and does not need to be reported on Form 10-422. C L Review of Sundry Application 306-077 ConocoPhillips Alaska, Inc. Well CD4-319 AOGCC Permit 205-148 Recommendation: I recommend approval of Sundry Application 306-077 to allow ConocoPhillips Alaska, Inc. to conduct a production test on well CD4-319 rather than the injection test originally approved. Conditions of Approval: The following conditions should be imposed on CPAI to ensure that waste is minimized and that we receive adequate information about this activity that will provide us with additional information about the reservoir and can guide us in future actions. 1) Total volume of all liquids produced cannot exceed 7,000 stb, unless a larger volume is necessary for proper well cleanup, 2) Should the 7,000 barrel limit be exceeded for well cleanup purposes CPAI must obtain commission approval before producing any additional volumes for the purpose of well testing, 3) CPAI must take all prudent steps to minimize the amount of fluid produced and gas flared or vented, 4) CPAI must provide the commission with a report on the well cleanup and production testing operations within 30 days of completion of the test. The report must include: a. A detailed timeline of well cleanup and testing operations including significant flowrate changes, b. Volume and type of liquids produced and volume of gas flared or vented during well cleanup operations, c. Volume and type of liquids produced and volume of gas flared or vented during well test operations, and d. Copies of all production logs and pressure survey results, both in the CD4- 319 and CD4-318 wells, obtained in conjunction with these operations. 5) In accordance with 20 AAC 25.235(b) CPAI must submit a Facility Report of Produced Gas Disposition (Form 10-422) for the volume of gas that was flared or vented in excess of what was required for well cleanup operations. Gas flared or vented during the well cleanup operation is incidental to normal oil field operations and will be considered de minimis under 20 AAC 25.235(d)(4) and does not need to be reported on Form 10-422. Conclusions: The commission has the authority under 20 AAC 25.235(d)(6) to allow gas flaring or venting during well test operations. The proposed activity will result gas flaring or • • venting, but by performing the testing operation in conjunction with the well cleanup operations CPAI will minimize the amount of gas flared or vented as a result of the test. Based on the 7,000 stb of liquid limitation and the estimated GOR of 500 scf/stb the maximum amount of gas that would be flared or vented is 3.5 mmcf, of which approximately half would be associated with the well cleanup operations that would have to be done regardless of whether an injection or production test was done. The amount of gas flared or vented in association with the production test would likely be between 1.5 and 2.0 mmcf, which is substantially less than the 5 to 10 mmcf implied by the original sundry application. It is possible, if it takes a long time to clean up the wellbore, that no additional production will have to occur too conduct the well test in which case no gas would be flared or vented for the express reason of conducting the well test. Conducting a production test will allow CPAI to gain some information that could not be obtained from an injection test. Namely, they can obtain a good reservoir fluid sample, they can assess wellbore stability and solids production issues, and they can evaluate the production performance of the long horizontal section wellbores. CPAI will be able to apply the lessons learned from this test to the production wells that are yet to be drilled and completed in this formation. D.S. Roby March 8, 2006 • • Chronological Discussion on CD4-319 Sundry Application On March 1, 2006, ConocoPhillips Alaska, Inc. submitted the above referenced application to change the approved testing procedure for the CD4-319 well, AOGCC Permit 205-148, in the Colville River Unit. The approved test was a positive pressure pulse test that would have injected 10,000 bbl of seawater into the Nanuq-Kuparuk pool and the pressure monitored in the CD4-318 well. The proposed change is to convert the test from an injection test to a production test and produce at least 10,000 bbls of oil and flare the associated gas. I called Jack Walker with CPAI on March 6, 2005, and asked for additional information about the proposed change. He stated that the primary purpose for the test was to evaluate well spacing, approximately 6,000 feet, in the pool and that secondary purposes were to collect a reservoir sample for PVT analysis and to evaluate the productivity of the horizontal wellbore. He stated that conducting a production test would be logistically easier for CPAI and that the GOR of the formation is estimated to be 500 scf/stb. He followed up this phone conversation with an email (copy attached) that provided additional information. Based on the stated GOR the production test would have flared in excess of 5 mmscf, with the only advantage from a reservoir management standpoint over the injection test being that a good quality reservoir fluid sample could be obtained. CPAI's pool rules application indicated that the solution GOR was expected to be 990 SCF, nearly twice what Mr. Walker stated. Regardless of the actually GOR flaring this much gas to obtain a good reservoir sample is not a good conservation practice, particularly when later this year production facilities will be installed at CD4 and a reservoir sample can be obtained at that time with no loss of gas. Based on the information currently available I recommend disapproving this request. Should CPAI provide a more robust justification for this operational change I would reconsider the issue. D.S. Roby March 6, 2006 Additional information after meeting with Jack Walker on March 7, 2006. Steve Davies, Tom Maunder, and I met with Jack Walker of CPAI to further discuss the issue of the pulse test on the CD4-319 well. Mr. Walker provided a more detailed description (copy of handout attached) of the proposed test and provided information that was not in evidence in the earlier communications on this issue. Most notably he indicated that he believes the 10,000 bbl test volume would include the volume produced during well cleanup operations. The well clean up operations are anticipated to require between 0.5 and 1 stb per foot of completion. Well CD4-319 has an open hole slotted liner completion of 6,678 feet in length. At this length the well cleanup would require between 3,339 and 6,678 stb of production. • • Additionally Mr. Walker said that he believes that the test volume would be in reservoir bbls and not stock tank bbls, but he was going to confirm this with his reservoir engineer. He anticipates, from data obtained during the flowback of the CD4-318 well, that the Bo of the produced fluid will be 1.5 rb/stb and the GOR will be around 500 scf/stb. Assuming the test volume is reservoir barrels and not stock tank barrels and that the anticipated Bo is correct than the 10,000 rb test would equate to 6,667 stb of production. If both of Mr. Walker's assumptions are correct then the amount of additional oil produced as a result of the pressure pulse test would be no more than 3,328 stb of oil, which yields a volume of gas flared for the test of 1,664 mscf, assuming the GOR of 500 scf/stb is correct. It is possible that well cleanup operations alone will require a larger flow volume than is necessary to complete the pressure pulse test, in which case no additional gas would be flared as a result of this test. Mr. Walker did state that wells drilled with water-based muds, as were used on the CD4-319 well, tend to cleanup more easily than wells that used oil-based mud. Based on this it is likely that the well test will require some additional flow, and consequently flaring, beyond what would be needed for the well cleanup operations alone. Mr. Walker promised to provide us with some additional information that would clarify/verify what he said about the test volumes. D.S. Roby March 7, 2006 Follow up to March 7th meeting As promised Mr. Walker sent us an email (received at 6:30PM on Tuesday March 7, 2006, with a copy attached) with a more detailed description of the proposed well cleanup and testing procedure to be used on the CD4-319 well and received clarification from the CPAI reservoir engineer about the requirements for the test volume. The information provide by Mr. Walker in his email confirmed what he stated during the meeting and aligns closely with the numbers I presented above. Although the proposed change in the approved test methodology will result in the waste of gas resources the volume would be significantly less than I had originally estimated based on their Sundry application. Additionally, the production test will allow the operator to obtain some information about the reservoir that they could not obtain from an injection test. This information includes an accurate reservoir fluid sample, information about wellbore stability and potential solids production. Although I am still concerned about the waste of resources I believe that the operator is acting in good faith to minimize the amount of waste and that a production test could provide some useful information that could not be obtained from an injection test. Therefore, in accordance with 20 AAC 25.235(d)(6), which allows for flaring of gas in • • conjunction with well testing, I recommend approving the Sundry application on the following conditions: 1) Total volume of all liquids produced cannot exceed 7,000 stb, unless a larger volume is necessary for proper well cleanup, 2) Should the 7,000 barrel limit be exceeded for well cleanup purposes CPAI must obtain commission approval before producing any additional volumes for the purpose of well testing, 3) CPAI must take all prudent steps to minimize the amount of fluid produced and gas flared or vented, 4) CPAI must provide the commission with a report on the well cleanup and production testing operations within 30 days of completion of the test. The report must include: a. A detailed timeline of well cleanup and testing operations including significant flowrate changes, b. Volume and type of liquids produced and volume of gas flared or vented during well cleanup operations, c. Volume and type of liquids produced and volume of gas flared or vented during well test operations, and d. Copies of all production logs and pressure survey results, both in the CD4- 319and CD4-318 wells, obtained in conjunction with these operations. 5) In accordance with 20 AAC 25.235(b) CPAI must submit a Facility Report of Produced Gas Disposition (Form 10-422) for the volume of gas that was flared or vented in excess of what was required for well cleanup operations. Gas flared or vented during the well cleanup operation is incidental to normal oil field operations and will be considered de minimis under 20 AAC 25.235(d)(4) and does not need to be reported on Form 10-422. D.S. Roby March 8, 2006 a .. ~4-319 Proposed Well Operat~s March 7, 2006 CD4-319 Background Summary Total depth: 18521 ft Production hole length: 6678 ft Sand thickness: 10 feet First Kuparuk development well in Colville River Field Rtc~.~ v: g ~.~r4~'1 3/7/06 Longest Kuparuk horizontal well operated by ConocoPhillips Objectives of CD4-319 Proposed Procedure 1. Minimize formation damage. 2. Confirm completion design will inhibit solids production. 3. Verify development well plans with productive length information. 4. Provide reservoir fluid sample for PVT analysis. 5. Evaluate reservoir transmissibility and size. Total Volumes Estimated for the Proposed Procedure 400 STB well load (diesel, brine, drilling fluid) 6,600 STBO crude 7,000 STB total liquid production 3.3 MMSCF gas production is expected based on the anticpated solution gas-oil ratio of 500 SCF/STB. Pulse test design work indicated a 10,000 reservoir barrel pulse is needed to create a clear pressure response if continuity exists. Applying the anticipated formation volume factor of 1.5 RB/STB, approximately 7,000 STB to create a 10,000 RB pulse volume. ~4-319 Proposed Well Operas March 7, 2006 CD4-319 Proposed Procedure and Technical Analysis 1. Flow well to clean up drilling fluid fitrate and mud filter cake. Monitor mud, solids, and reservoir fluids production. Solids and emulsion production is used decide when well has cleaned up; 0.5 to 1 STB/ft of well length required for Alpine well clean-up. 2. Flow well and shut in after a total of 7,000 STB (10,000 RB) have been produced including clean up operations in step 1, above. a. Acquire production log via electric line tractor during the second portion of the flowing operation after clean up. Evaluate effective producing length. b. Choke the well to a high flowing bottomhole pressure and acquire bottomhole reservoir fluid sample at the end of the second portion of the flowing operation after clean up. Conduct PVT lab analysis. Provide Pb and FVF data for voidage management. Run process simulations for well test shrinkage factors. c. In addition to the providing the opportunity to production log and collect bottomhole sample, the second portion of the flow period will provide opportunities to: i. Monitor solids production to evaluate slotted liner completion. ii. Monitor flowing bottomhole pressure and evaluate formation damage. iii. Offtake to create production pulse observable in the 5 to 10 psi range at the offset well if adequate continuity exists. 3. Monitor bottomhole pressure in offset CD4-318. Determine interwell transmissibility from response time. Determine reservoir OOIP from pressure change. CD4-319 Anticipated Volumes 1. Clean-Up Period 3000 STBO, 1.5 MMSCF reservoir fluids flowed to surface A total of 3400 bbl are expected to be required for clean up, but the first 400 bbl are expected to be well load fluids. 2. Production Log/Bottomhole Sample Period 3600 STBO, 1.8 MMSCF reservoir fluids flowed to surface Production logging and sampling will be accomplished simultaneously with the latter portion of the flowing operation after the well has cleaned up. 3 rv A~Gc~ o^ 3/z/~6 Pao ~,' drd • CD4-319 Proposed Well Operations March 6, 2006 CD4-319 Background Summary Total depth: 18521 ft Production hole length: 6678 ft Sand thickness: 10 feet First Kuparuk development well in Colville River Field Longest Kuparuk horizontal well operated by ConocoPhillips Objectives of CD4-319 Proposed Procedure 1. Minimize formation damage. 2. Confirm completion design will inhibit solids production. 3. Verify development well plans with productive length information. 4. Provide reservoir fluid sample for PVT analysis. 5. Evaluate reservoir transmissibility and size. Proposed Procedure and Technical Analysis 1. Flow well to clean up drilling fluid fitrate and mud filter cake. Monitor mud, solids, and reservoir fluids production. 2. Continue flowing well, 10,000 STB. Monitor solids production to evaluate slotted liner completion. Monitor flowing bottomhole pressure. Evaluate formation damage. Create production pulse. 3. Acquire production log via electric fine tractor. Evaluate effective producing length. 4. Acquire bottomhole reservoir fluid sample. Conduct PVT lab analysis. Provide Pb and FVF data for voidage management. Run process simulations for well test shrinkage factors. 5. Monitor bottomhole pressure in offset CD4-318. Determine interwell transmissibility from response time. Determine reservoir OOIP from pressure change. Final Summary 18683' MD COP CD4-319 a o a o y °o, vfo ~ 6 o ~ o c~.o ado F o F 4 F o ~ o [C a ~ o U p U p U °p ~ N ~ N ~ N _O O O = O ~ O = O O d $ O M d C'1 d N 3ti ~ Q 'h ~ ~~ q N O ~:° r N a~, ~ ~ •~- d p q d ~? i7 0 ~ O 000 10000 11000 12000 13000 14000 15000 ~I l - Rt h O 7120 ! ~ ~ ~_. ` "" ~.~ 7140 ~~yy d. 3 ~ is 7160 m f- Plan trajectory 7-14 ft thick Kuparuk C Interval i~r ~, ii , i If' ~~~ ' :~` ~ ~ ~ ~ .., ~ i . ~.~ ~ ~t~'YI~ 11~ i~~~ ViYillli~~ ,~ , .~ ~~; I i r~l l' ~ ~~~ ~~~I~I~, i G 11 3000 9500 7oso ~ ~U~ ~ 7100 ~ a> a~ H 1 bi • • CD4 - 319 Nanuq Kuparuk Injector Completion updated March 7, 2006 16" Insulated Conductor to 114' 4-'/i' 12.6 ppf L-80 IBT Mod. Tubing 3.812" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 3419' MD / 2517' TVD USIT top of cement ` 9360' MD / 5681' TVD Top Reservoir at +/- Nanuq 9902' MD / 6212' TVD Kuparuk 11881' MD / 7148' TVD Well Capacity Tubing volume: 180 bbl Inner annulus to GLM: 204 bbl Production hole: 212 bbl Upper Completion: Top MD TVD Angle 1) Tubing Hanger 32' 32' 0 deg 2) 4-1/2", 12.6#/ft, IBT-Mod Tubing 3) Camco DB nipple 2297' 1927' 59 4) 4-1/2", 12.6#/ft, IBT-Mod Tubing 5) HES 3.813 X nipple 10832' 6792' 51 6) 4-1/2", 12.6#/ft, IBT-Mod Tubing w/ special Clearance couplings (2) 7) Weatherford 7500 psi mPOD2 Gauge and Gauge Carrier ID=3.958", OD=6.145" 10903' 6836' S4 8) 4-1/2", 12.6#/ft, IBT-Mod Tubing w/ special Clearance couplings (2) 9) Camco KBG2- 1" GLM w/ BK'/<" OV 10986' 6883' 57 10) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) 11) Baker Premier Packer 11092' 6938' 61 12) 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) 13) HES "XN" (3.725") 11148' 6962' 65 14) 4-1/2", 12.6#/ft, IBT-Mod 15) BOT Stinger with Fluted WLEG/pup/shear sub 11842' 7142' 82 4 '/2" tubing tail 11848' Lower Completion: 16) Baker 5" x 7" Flexlock Liner Hanger 11845' 7143' 82 17) 4-1/2", 12.6#/ft, SLHT Tubing 18) 4 '/z" 12.6#/ft L-80 SLHT slotted liner w/ blank across shale and slots across sand 19) Baker Shoe w/ packoff bushing 18480' 7146' 91 20) Completed depth 18521' 4-''/2' 12.6#/ft L-80 IBT Mod Slotted liner Pattern: '~ __ ._ _ ____ _ ___ 32 slots /_ft~ 2-'/4'_x 1/8" slots______ _____ 15 16 18 19 13 ==_- ==_ = = =- =========== i _....._.._ _ TD 6-1/8" hole 7" 26 ppf L-80 BTC Mod 18683' MD / 7131' TVD Production Casing @ +/-87° 12005' MD, 7152' TVD CU4-3l~ Sundry Follow-Up • ~ Subject: CD4-319 SundxyFollow-Up From: "Walker, Jack A" <Jack.rl.Walker(~i'.conocophillips.com=> Date: Mori, (76 Mar 2006 10:40:6 -090 To: davc_roby(uadmin.state.ak.us Dave, We have planned a pulse test of the Nanuq-Kuparuk oil pool to ensure that we have adequate well spacing. The planned Nanuq-Kuparuk well spacing is 6000 feet, and we need to ensure continuity exists at this well spacing, or if more wells will be needed. It is important to understand well spacing needs early in the field life before substantial local pressure depletion/pressurization occurs if well spacing is inadequate. The production pulse created by CD4-319 will be monitored at CD4-318. Secondary objectives of the production pulse test include assessment of completion performance, reservoir limit, and PVT properties. We do not have aNanuq-Kuparuk PVT analysis needed for well test shrinkage factors and reservoir management. We plan to acquire a bottomhole sample from CD4-319 for PVT analysis. The pulse test was originally planned as an injection pulse, then revised to a production pulse because the logistics of an injection pulse add scope to the simultaneous well operations and construction activity at CD4 pad. To clean up the completions and prepare the wells for operation, we are flowing back the CD4 wells to a portable well test system. The CD4-318 flowback indicated that the Nanuq-Kuparuk gas:oil ratio is approximately 500 SCF/STB. The well test system used for the well flowbacks is proposed for the CD4-319 production pulse. The injection pulse would require setting up a temporary injection facility with tank farm, injection pumps, injection line, heaters, and methanol injection, and water hauling. Please call me if you have any other questions. Jack Walker Western North Slope Development ConocoPhillips Alaska, Inc. 1 of 1 3/6/2006 12:58 PM Sundry Application for CD4-319 • Subject: Sundry Applica#ion for CD4-;1 ~) From: Dave. Roby ~daee roby(a.admin.state.ak.us:% Datc: Mon. 06 filar ?OOG 10:1 x:33 -0900 To: 7~homas 1~ '~~launder <tom_maunder'~iadmin.state.ak.us>. Catherine P Foers~er ~cathyfoerster(«;admin.state.ak.us=> Tom and Cathy; I just talked with Jack Walker of CPAI about his sundry application for the CD4-319 well to change the test protocol from an injection test to a production test with gas flaring. He is going to email me a write-up, which I will forward to you, explaining why they are requesting the change. In brief he said that they are proposing to change the test because it is logistically easier to conduct a production test than a injection test. He anticipates a producing GOR of about 500 scf/stb, which would result in a flared volume of at least 5,000 MCF. I am not sure where he is getting this GOR from as the limited data that we have for the Nanuq pool (note: the test is of the Nanuq-Kuparuk pool) shows a GOR of over 13,000 scf/stb. He also anticipates production rates of 3 to 5 MBOPD, which would mean a test of 3 days ±. Additionally, he stated that they have completed their earlier work and want to begin this test sooner (the next day or two) than originally anticipated in their application (March 12, 2006). I'll let you know when I get more information. Dave 1 of 1 3/6/2006 12:58 PM • - ��-L HECHANICAL INTEGRITY REPORT _FUD D _ _ : OC L?1 � �D OPER & FIE �� R 3 : Nom a - OQ S i, ELL N Ut-EB ER ,ELL DATA TD: 15sbA`11-9D .. 'Z \3DTVD; PBTD: TVD Casing: `A Shoe: 1 kc■cAj MID " TVD; DV: •TVD liner : N Shoe : '•D) TVD ; TCP : '•SD ub `4 0 . I; Packer \\O TVD ; Set e t \ \ C SLI t�csr \�. 1005\ Hole Size C 3�1y and ; Perfs to • \t_ov ,t-o \L S\o l 1 +mac v \ ( \S5 - k -C C'c?.rANICLL INTEGRITY - PART 11 Annulus Press Test: _p ; 15 min ; 30 min • Comments : crcS Z cue -c CVO r — ' S \ '� CH�NICA� INTEGRITY - PART 12. !t i Sv Cement Volumes Amt. Liner ; Csg i3(:) ; DV . C� t(, C.mt vol to cover perfs 455 N)LS o CF t`^ a Sv' E� C23 e -- 5 UCH Q Theoretical TOC e 3G \ 5 � "?cm .4 \© CN C- C 75 , Cement Bond Log (Yes or No) ‘-(Q-5 ‘-(Q-5 ; InAOGCC File Yc CBL Evaluation, zone above perfs eOf% Production Log: Type ; Evaluation CONCLUSIONS : �� Part #l: Part f2: . S2. Sit-0(0 • ConocoPhillips February 13, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-319 (APD 205-148) Dear Commissioner: P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ~E~I~E FEB Y 4 2006 A-eska Oil $, Gas cons. Conaraa~ •• _ Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD4-319. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells G. C. Alvord Alpine Drilling Team Leader Drilling & Wells GCA/skad RECEIVED STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMI~S~ION FEB 1 4 2006 WELL COMPLETION OR RECOMPLETION REPOI~~s~-til®s~• Corranissian 1a. Well Status: Oil ^ - Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: (1C 0[8g Development ^/ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: November 29, 2005 12. Permit to Drill Number: 205-148 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 30, 2005 ~ 13. API Number: 50-103-20516-00 4a. Location of Well (Governmental Section): Surface: 2973' FNL, 419' FEL, Sec. 24, T11 N, R4E, UM 7. Date TD Reached: November 22, 2005 14. Well Name and Number: CD4-319 At Top Productive Horizon: xx FSL, xx FEL, Sec. 25, T11 N, R4E, UM 8. KB Elevation (ft): 36.7' RKB 15. Field/Pool(s): Colville River Field Total Depth: 2064' FNL, 612' FEL, Sec. 23, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 18684' MD / 7132' TVD Nanuq-Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377825 y- 5957442 Zone- 4 10. Total Depth (MD + ND): 18684' MD / 7132' TVD • 16. Property Designation: ADL 380077, 384209 TPI: x- y- Zone- 4 Total Depth: x- 372367 ~ - 5958442 ~ Zone- 4 11. Depth where SSSV set: Landing Nipple @ 2297' 17. Land Use Permit: ALK 38077 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1770' MD 21. Logs Run: GR/Res/Dens/Neutron 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# 11-40 36.7' 114' 36.7' 114' 42" Portland Type III 9.625" 40# L-80 36.7' 3196' 36.7' 2396' 12.25" 511 sx AS Lite, 234 sx Class G 7" 26# L-80 36.7' 11995' 36.7' 7152' 8.75" 13o sx LiteCRETE, 111 sx Class G 4.5" 12.6# L-80 11845' 18521' 7144' 7135' 6.125" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number, if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 11848' 11092' slotted liner from 11845' - 18521' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production not available Method of Operation (Flowing, gas lift, etc.) Pre-produced injector Date of Test not available Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GASOIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~S®MS SF~ F~~ ~ 5 Zoos ~,, -1~ r NONE ~~~ Z ~ ` y~ii: i~~ a Form 10-407 Revised 12/2003 ~ ~ ~ n ~ n) ~ ~ CONTINUED ON REVERSE 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD4-319 K-3 5899' 3853' ` K-1 11554' 7086' Kuparuk D 11720' 7121' Kuparuk C 11880' 7148' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name C. Alvord Title: Alpine Drillino Team Leader p /~ /n~~. Signature _~}~ ~ l~L Phone ZG ~' - ~ t 2 p Date chi l t 3 ~ Z. D.-~ fat 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. Prepared by Sharon Allsup-Drake Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List al! test information. If none, state "None". Form 10-407 Revised 12/2003 • Legal Well Name: CD4-319 Common Well Name: CD4-319 'Event Name: ROT -DRILLING Contractor Name: Ri N Doyon Drilling Inc g ame: Doyon 19 Date From - To Hours Code 10/27/2005 ~ 06:00 - 12:00 12:00 - 00:00 10/28/2005 00:00 - 12:00 12:00 - 00:00 110/29/2005 100:00 - 10:00 10:00 - 13:30 13:30 - 16:30 16:30 - 17:30 17:30 - 18:30 18:30 - 19:00 19:00 - 20:00 20:00 - 21:00 21:00 - 00:00 00:00 - 02:00 02:00 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 10:00 10:00 - 12:00 12:00 - 00:00 10/31!2005 100:00 - 12:00 12:00 - 00:00 .1111 /2005 100:00 - 01:30 01:30 - 02:30 02:30 - 06:00 ConocoPhillips Alaska Operations Summary Report Sub Phase Code Start: 11 /1 /2005 Rig Release: 11/30/2005 Rig Number: 19 Page 1 of 12 ~ Spud Date: 10/30/2005 End: 11 /1 /2005 Group: Description of Operations 6.00 MOVE RURD MOVE Rigged down and prepared to skid back. Safety Stand down meeting held with crew. 12.00 MOVE MOVE MOVE Skidded back derrick. Moved Ball Mill to CD4. Prepared Pitt and Motor Module and moved to CD4. No problems with the road as yet. Safety Stand down meeting held with crew. 12.00 MOVE MOVE MOVE Moved Sub base and rig package to CD4. Prepped area for camp. 12.00 MOVE MOVE MOVE Moved Camp, Sewer plant, and Shop. Spotted camp and moved Pipe shed. 10.00 MOVE MOVE MOVE Finished spotting Sub over well. Matted area for Pitts and Motors package. Spotted and connected Pitts and motors. Skidded out rig package. 3.50 WELCTL NUND MOVE Nippled up Diverter and Diverter line. Rig accepted @ 1000 Hrs. 10/29/05. 3.00 DRILL RIRD RIGUP Measured out riser (needed to shorten ti') and sent it to the welder. Loaded pipe shed with 75 Jts. DP. 1.00 WELCTL BOPE RIGUP Function tested Diverter. Witiness waived by Jeff Jones AOGCC. 1.00 WELCTL SFTY RIGUP Pre spud meeting with all hands followed by Divert drill. 0.50 RIGMNT RSRV RIGUP Serviced rig and top drive. 1.00 DRILL OTHR RIGUP Finished taking on Spud mud and changed shaker screens. 1.00 WELCTL NUND RIGUP Nippled up modified riser and flowline. 3.00 DRILL PULD SURFAC Picked up and stood back 5" DP from pipe shed. 2.00 DRILL PULD SURFAC Picked up and stood back 5" drill pipe and HWDP. 3.00 DRILL PULD SURFAC Picked up BHA. 1.00 DRILL OTHR SURFAC Filled stack and tested lines to 3500 psi. 0.50 DRILL DRLG SURFAC Spudded well @ 0600 and drilled to 169' to have room to bury Nuke tool. 0.50 DRILL TRIP SURFAC POOH to pick up MWD Nuke. 3.00 DRILL PULD SURFAC Picked up Nuke tools and up loaded. RIH to 169'. 2.00 DRILL DRLG SURFAC Drill 12 1/4" hole f! 169' to 306' MD - 306' TVD ADT - 1.16 hrs. =ART - .84 hrs. AST - .32 hrs. WOB 15 k RPM 50 GPM 450 @ 1180 psi String wt. PU 102 SO 100 Rot 100 Torque on/off btm. - 5,000/4,000 ft. lbs. 12.00 DRILL DRLG SURFAC Drill 12 1/4" hole f/ 306'to 1,517' MD - 1,415' TVD ADT - 7.56 hrs. =ART - 3 .4 hrs. AST - 4.16 hrs. WOB 25/30 k RPM 50 GPM 506 @ 1450 psi String wt. PU 130 SO 123 Rot 129 Torque on/off btm. - 7,500/6,500 ft. lbs. 12.00 DRILL DRLG SURFAC Drill 12 1/4" hole f/ 1,51 T to 2,413' MD - 1,988' TVD ADT - 8.92 hrs. =ART - 6 .03 hrs. AST - 2.92 hrs. WOB 25/30 k RPM 60 GPM 650 @ 2450 psi String wt. PU 140 SO 125 Rot 130 Torque on/off btm. - 9,000/8,000 ft. lbs. 12.00 DRILL DRLG SURFAC Drill 12 1/4" hole f/ 2,413' to 3,034' MD - 2,270' TVD ADT - 9.03 hrs. =ART - 7 .33 hrs. AST - 1.70 hrs. WOB 25/40 k RPM 60 GPM 670 @ 2540 psi String wt. PU 138 SO 120 Rot 130 Torque on/off btm. - 9,500!7,500 ft. lbs. 1.50 DRILL DRLG SURFAC Drilled from 3,034' to 3,206' TD TVD=2,401' ADT=1.29 ART=1.29 PUW=135K SOW=120K ROT=125K TOon/off=9.5K/7.5K @ 3200'. 1.00 DRILL CIRC SURFAC Circ'd hole clean. 2X BU. 3.50 DRILL WIPR SURFAC Pumped out from 3,206' to 935' w/ 500 gpm, 40 rpm, 1,850 psi. Printed: 2/1/2006 2:15:14 PM • • ConocoPhillips Alaska Operations Summary Report Page 2 of 12 Legal Well Name: CD4-319 Common Wel{ Name: CD4-319 Spud Date: 1 013 012 0 0 5 Event Name: ROT -DRILLING Start: 11/1/2005 End: 11/1/2005 Contractor Name: Doyon Drilling Inc Rig Release: 11/30/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours Code Code Phase Description of Operations 11!1/2005 06:00 - 07:30 1.50 DRILL WIPR SURFAC Observed well, static. Blew down TD and RIH from 935' to 3,206'. 07:30 - 09:15 1.75 DRILL CIRC SURFAC Circ'd @ 670 gpm, 50 rpm, 2,430 psi. 09:15 - 09:30 0.25 DRILL OBSV SURFAC Checked flow, static. 09:30 - 09:45 0.25 DRILL TRIP SURFAC POOH on TT from 3,206' to 3,119'. Gained 15 bbls, RIH to 3,206' 09:45 - 10:45 1.00 DRILL CIRC SURFAC Circ'd and weighted up from 9.6 ppg to 10.0 ppg. 10:45 - 11:00 0.25 DRILL TRIP SURFAC POOH on TT from 3,206' to 2,928'. 0.5 bbl fill. 11:00 - 12:00 1.00 DRILL TRIP SURFAC Pumped out from 2,928' to 2,452' w/ 126 gpm, 420 psi. 12:00 - 14:00 2.00 DRILL TRIP SURFAC POOH on TT from 2,452' to tight spot @ 750'. RIH to 832'. 14:00 - 14:45 0.75 DRILL TRIP SURFAC Pumped out from 832' to 482' w! 3 bpm, 280 psi. Checked flow, static. 14:45 - 16:30 1.75 DRILL SURV SURFAC Took gyro surveys @ 482', 393', 303'. Continued to pump out. 16:30 - 20:30 4.00 DRILL PULD SURFAC Stood back 1 std HWDP and DC's. Held PJSM, pulled sources, downloaded MWD. UD 4 MWD components, XO, stab, motor and bit. Cleaned floor. 20:30 - 22:00 1.50 CASE RURD SURFAC R/U to run 9.625" casing. Held PJSM. 22:00 - 00:00 2.00 CASE RUNG SURFAC RIH wi 40# 9.625" csg as per detail to 496'. PUW=90K SOW=90K 11/2!2005 00:00 - 00:45 0.75 CASE RUNC SURFAC RIH w/ 9.625" casing from 496'to 1,530'. 00:45 - 01:30 0.75 CASE CIRC SURFAC Circ'd one casing volume @ 2 BPM. 01:30 - 03:00 1.50 CASE RUNC SURFAC RIH w/ 9.625" casing from 1,530' to 3,196'. PUW=170K SOW=125K @ 3,196'. 03:00 - 03:45 0.75 CASE RURD SURFAC R/D casing equipment. R/U cement head. 03:45 - 06:00 2.25 GEMEN CIRC SURFAC Circ'd and cond. mud for cement job. 06:00 - 08:45 2.75 GEMEN PUMP SURFAC Held PJSM, Cemented 9 5!8" casing as follows: Pumped 40 bbls Biozan water w/nut plug as marker -Switched over to Dowell -Pumped 3 bbls water -Tested lines to 2750 psi -Dropped btm plug -Mixed & pumped 50 bbls 10.5 ppg MudPush spacer @ 5 bbls/min @ 170 psi -Mixed & pumped 10.7 ppg lead slurry (Arctic Set Lite) @ 7.5 bbls/min @ 240 psi to 350 psi -Observed nut plug marker @ shakers w/ 385 bbls lead slurry pumped -Pumped down surge can -pumped total of 406 bbls lead slurry -Switched to tail slurry mixed & pumped 48 bbls -15.8 ppg (Class G w! .2% DO-46, .3% D065, 2% S001) @ 5.2 bbls/min - 320 psi - Dropped top plug w/ 20 bbls water. Reciprocated pipe while pumping until just prior to beginning tail slurry -hole becoming sticky -set down onto landing ring for remainder of job. Switched back to rig pumps & displaced cement w/ 216.4 bbls 9.7 ppg mud @ 7 bbls /min ICP 300 psi - pre bump pressure 640 psi -Slow rate to 4 bbls /mins for last 32 bbls of displacement -bumped plug w! 1200 psi - Checked floats OK - CIP @ 0840 hrs. -Full returns through out job w/ 125 bbls cement to surface. 08:45 - 09:00 0.25 CEMEN OTHR SURFAC Checked floats, held. 09:00 - 09:30 0.50 CASE DEOT SURFAC Successfully tested 9.625" casing to 2500 psi for 30 mins. 09:30 - 10:45 1.25 GEMEN RURD SURFAC Blew down cement line, R/D cement head, washed down floor. 10:45 - 12:00 1.25 WELCTL EQRP SURFAC N/D BOPs diverter. 12:00 - 13:30 1.50 WELCTL EQRP SURFAC NID surface diverter system, flowline and mousehole. Removed diverter, removed hydril and secured. Removed from cellar. 13:30 - 14:45 1.25 WELCTL EQRP SURFAC Installed casing head and tested metal-to-metal seals w. FMC. Installed accumulator valve on wellhead. 14:45 - 16:15 1.50 WELCTL EQRP SURFAC N/U BOPs, bell nipple, flow line, turnbuckle, mousehole, and service lines. 16:15 - 18:15 2.00 WELCTL EQRP SURFAC Installed test plug and tested. Leaked. Tightened lower flange bolts on wellhead adapter assembly, packing on lockdowns, test ports on wellhead. Retested, good. 18:15 - 23:00 4.75 WELCTL BOPE SURFAC Tested BOPs. Hydril to 250 & 3500 psi -Pipe rams ,blind rams, choke Printed: 2l1t20b6 2:15:14 PM • • ConocoPhillips Alaska Operations Summary Report Page 3 of 12 Legal Well Name: CD4-319 Common Well Name: CD4-319 Spud Date: 10/30/2005 Event Name: ROT -DRILLING Start; 11!1/2005 End: 11/1/2005 Contractor Name: Doyon Drilling Inc Rig Release: 11/30/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours Code Code Phase Description of Operations !11/2/2005 I 18:15 - 23:00 4.75 WELCTL BOPE SURFAC 23:00 - 23:30 0.50 WELCTL EORP SURFAC 23:30 - 00:00 0.50 CASE NUND SURFAC 1,1113/2005 00:00 - 00:30 0.50 DRILL RIRD SURFAC 00:30 - 10:30 10.00 DRILL TRIP SURFAC i 10:30 - 10:45 0.25 DRILL RIRD SURFAC 10:45 - 12:00 1.25 DRILL PULD SURFAC 12:00 - 15:30 3.50 DRILL PULD SURFAC 15:30 - 17:45 2.25 DRILL TRIP SURFAC 17:45 - 19:15 1.50 RIGMNT RSRV SURFAC 19:15 - 19:45 0.50 DRILL TRIP SURFAC 23:00 - 23:30 0.50 ~ DRILLN~ DRLGO `SURFAC 23:30 - 00:00 0.50 CEMEN CIRC SURFAC 11/4/2005 00:00 - 00:15 0.25 CEMEN FIT SURFAC 00:15 - 00:45 0.50 CEMEN FIT SURFAC 00:45 - 01:00 0.25 CEMEN RURD SURFAC 01:00 - 01:30 0.50 DRILL CIRC INTRM1 01:30 - 01:45 0.25 DRILL CIRC INTRM1 01:45 - 12:00 I 10.251 DRILL I DRLG I INTRM1 12:00 - 00:00 I 12.001 DRILL I DRLG I INTRM1 & kill line valves, choke manifold valves, floor safety & dart valves, TD IBOP valves to 250 & 5000 psi -Performed accumulator closure test - Witnessing of test waived by Jeff Jones of AOGCC. Blow down kill & choke lines - RD test equipment. Pulled test plug. Installed wear bushing and L/D test joint. P/U and install short bails and elevators. Cleaned up floor, spotted Geo-Span. P/U 5" DP from shed, total 222 jts and stood back in derrick. Cleaned up floor, blew down choke. M/U BHA #2. Held PJSM. P/U BHA #2 included: 3 MWD components, pulser, uploaded MWD, installed sources, float sub, 3X flex DCs, 3X HWDP, jars, 14X HWDP to 734'. Tested MWD, Geo-Span unit to 3500 psi. Downlinked Geopilot. P/U 5" DP from shed {69 jts) to 2.939'. Sliipped and cut 60' drilling line and serviced rig. RIH to 3,039' and broke circ to break in Geopilot bearings. Washed to FC @ 3,119'. No cement encountered. Drilled FC and shoe track. Drilled shoe @ 3,194' and rathole to 3,206'. Drilled from 3,206' to 3,226' MD / 2412' ND. ADT=0.23 PUW=150K SOW=110K ROT=130K TQon/off=10.5K/9.2K @ 3226', Circa and cond. mud for FIT @ 500 gpm. R!U for FIT test. Pertomled FIT to 18:4 ppg equivalent. Blew down kill line, R/D FIT equip. C/O to 9.6 LSND mud. Cleaned surface equipment, obtained SPR. SPR #1=30stkl120psi, 40stkl160psi SPR #2=30stk/110psi, 40stk/160psi @ 3220'. Drilled from 3,225' to 4,369' MD/ 3074' ND ADT=6.44 PUW=160K SOW=120K ROT=140K TQon/off=10.5K/9.2K @ 4,369'. Drilled from 4,369' to 5,755' MD/ 3,782' ND ADT=8.15 PUW=180K SOW=125K ROT=150 TQon/off=12.5K/11 K @ 5,755'. SPR #1=30stk/190psi, 40stk/250psi SPR #2=30stk/190psi, 40stk/270psi @ 5,509'. 11 /5/2005 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ DRLG ~ INTRM1 12:00 - 00:00 I 12.001 DRILL I DRLG I INTRM1 1/6/2005 100:00 - 08:00 I 8.001 DRILL I DRLG I INTRM1 Drilled from 5,755' to 7,319' MD/ 4,581' ND. ADT=7.66 PUW=205K SOW=135K ROT= 160 TQon/off=14.5K/13K @ 7,319' SPR#1=30stk/190psi, 40stk(260psi SPR#2=30stk/180psi, 40 stk/260psi @ 6,461' & 0600hrs Drilled from 7,319' to 9,509' MD/ 5,793' ND. ADT=8.17 PUW=240K SOW=150K ROT=190K TQon/off=18.5K/16.3K @ 9,414'. SPR#1=30stk/280psi, 40stk/320psi SPR#2=30stk/280psi, 40 stkl320psi @ 9,032' & 2124hrs. Drilled from 9,509' to 10,652' MD/ 6,673 ND ADT=4.98 PUW=250K SOW=175K ROT= 214 TQon/off=19K/14.5K SPR#1=30stkf190psi, 40stk1260psi SPR#2=30stk/180psi, 40 stk/260psi Printed: 2!1!2006 2:15:14 PM • ConocoPhiflips Alaska Operations Summary Report Page 4 of 12 Legal Well Name: CD4-319 Common Well Name: CD4-319 Spud Date: 10/30/2005 Event Name: ROT -DRILLING Start: 11/1/2005 End: 11/1!2005 Contractor Name: Doyon Drilling Inc Rig Release: 11/30/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date I From - To I Hours I Code Code Phase Description of Operations 11/6/2005 00:00 - 08:00 8.00 DRILL DRLG INTRM1 @ 10,652' & 0900hrs 08:00 - 09:00 1.00 DRILL CIRC INTRMI Circ'd and cond. mud, weighted up to 9.8 ppg, pumped hi-vis sweep @ 650 gpm, 100 rpm, 2450 psi. 09:00 - 12:00 3.00 DRILL TRIP INTRM1 Checked flow, static. Blew down TD. POOH on Tf from 10,652' to 9,604'. Checked flow, static. Pumped dryjob, blew down. Cont'd to POOH from 9,604' to 8,366'. PUW=235K SOW=150K @ 8,366' 12:00 - 16:15 4.25 DRILL TRIP INTRMI Cont'd to POOH on TT from 8,366' to 775'. Checked flow, static. S/B HWDP and jars. 16:15 -20:00 3.75 DRILL PULD INTRMI S/B 1 std DCs, held PJSM, removed sources, downloaded MWD. UD nuke, MWD, serviced geopilot and UD geospan unit. Performed function test. 20:00 - 23:00 3.00 DRILL PULD INTRM1 P/U BHA #3, motor, C/O sleeve and orient, M/U bit. P/U MWD, nuke, HOC, flt sub. Held PJSM and installed sources. P/U 1 std DCs, HWDP, jars from derrick to 743'. Pulse tested MWD, blew down TD. 23:00 - 00:00 1.00 DRILL TRIP INTRM1 RIH w/ 5" DP to 1,401'. 11/7!2005 00:00 - 01:30 1.50 DRILL TRIP INTRM1 Cont'd to RIH from 1,401' to 5,222'. Filled every 2000'. 01:30 - 02:30 1.00 DR1LL CIRC INTRM1 CBU @ 500 gpm, 40 rpm, 1270 psi. Blew down TD. 02:30 -05:00 2.50 DRILL TRIP INTRM1 Cont'd to RIH from 5,222'to 10,459'. 05:00 - 06:00 1.00 DRILL REAM INTRM1 Washed down from 10,459' to 10,652'. CBU @ 650 gpm, 50 prm, 3000 psi. 06:00 - 12:00 6.00 DRILL DRLG INTRM1 Drilled from 10,652' to 10,851' MD/ 6,$04 ND ADT=3.0 AST=2.5 ART=0.5 PUW=245K SOW=180K ROT= 2'10 TOon/off=14.5K/13K @ 10,851' SPR#1=30stk/320psi, 40stk/430psi SPR#2=30stk/330psi, 40 stk/440psi @ 10,745' & 0920hrs 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled from 10,851' to 11,316' MD/ 7,023 ND ADT=7.23 AST=5.76 ART=1.47 PUW=245KSOW=180K ROT= 210 TOon/off=14K/13K @ 11,220' SPR#1=30stk/420psi, 40stk/480psi SPR#2=30stk/400psi, 40 stk/470psi @ 11,220' & 2205hrs 11/8/2005 00:00 - 11:00 11.00 DRILL DRLG INTRM1 Drill 8 3/4" hole w/ motor f/ 11,316' to 12,005' MD 7152.96' ND ADT - 7.4 hrs. =ART -2.96 hrs. AST - 4.44 hrs. WOB 8/15 k RPM 0/50 GPM 650 @ 3050 psi String wt. PU 255 SO 165 Rot 205 Torque on/off btm. - 14,500/13,000 ftllbs. 11:00 - 13:00 I 2.001 DRILL I CIRC I INTRM1 13:00 - 15:00 2.00 DRILL WIPR INTRM1 15:00 - 15:45 0.75 DRILL TRIP INTRM1 15:45 - 17:00 1.25 DRILL CIRC INTRM1 17:00 - 18:30 1.50 DRILL WIPR INTRMI 18:30 - 19:00 0.50 DRILL TRIP INTRM1 Circulate -pump hi-vis sweep @ 650 gpm @ 2880 psi w/ 70 rpm - Circulate out sweep & circulate 2nd btms. up standing back 1 std every 30 mins to 11,822' -flow check -static Continue wiper trip w/ pump @ 500 gpm @ 1850 psi w/ 70 rpm f/ 11,822' to 10,681' -Flow check -static -Blow down TD RIH f! 10,681'to 11,919' w/ 10-15K drag. Broke circ. and pumped hi-vis sweep around @ 12,005' w/ 650 gpm, 70 rpms, 2980 psi. Checked flow, static. POOH w/ pump from 12,005' to 10,936' w/ 500 gpm, 70 rpm, ICP 1880 psi, FCP 1840 psi. Hole looked good. RIH from 10,936'to 11,919'w/ 10-20K drag. Printed: 2/1(2006 2:15:14 PM ConocoPhillips Alaska Page 5 of 12 ~ Operations Summary Report Legal Well Name: CD4-319 Common Well Name: CD4-319 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 -Date From - To Hours Code Code Phase 11/8/2005 19:00 - 19:15 0.25 DRILL CIRC INTRM1 19:15 - 20:15 1.00 DRILL CIRC INTRM1 20:15 - 22:00 1.75 DRILL TRIP INTRM1 22:00 - 00:00 2.00 DRILL TRIP INTRM1 11/9/2005 00:00 - 06:00 6.00 DRILL TRIP INTRMI 06:00-08:30 2.50 DRILL PULD INTRM1 08:30 - 11:00 2.50 DRILL OTHR INTRMI 11:00 - 13:00 2.00 CASE OTHR INTRM1 13:00 - 16:30 3.50 CASE RUNC INTRMI 16:30 - 17:00 0.50 CASE CIRC INTRM1 17:00 - 20:45 3.75 CASE RUNC INTRM1 20:45 - 21:45 1.00 CASE CIRC INTRM1 21:45 - 00:00 2.25 CASE RUNC INTRMI 11/10/2005 00:00-01:30 1.50 CASE RUNC INTRMI 01:30 - 03:00 1.50 CASE CIRC INTRM1 03:00 - 06:30 3.50 CASE RUNC INTRM1 06:30 - 07:00 0.50 CASE OTHR INTRM1 07:00 - 09:00 2.00 CEMEN CIRC INTRM1 09:00 - 11:00 2.00 CEMEN PUMP INTRM1 11:00 - 12:00 1.00 CASE MIT INTRM1 12:00 - 13:00 1.00 CEMEN PULD INTRM1 13:00 - 14:00 1.00 CASE DEQT INTRM1 Spud Date: 10/30/2005 Start: 11/1/2005 End: 11/1/2005 Rig Release: 11!30/2005 Group: Rig Number: 19 Description of Operations Broke circ. for precaoutionary ream to 12,005' CBU and spotted strengthening and tube pills w/ 650 gpm, 70 rpm, 2970 psi. Checked flow, static. POOH w/ pump @ 3 BPM, spotting pills from 12,005' to 10,555'. Blew down TD. POOH on TT from 10,555' to 9,126'. String wt. PUW=230K SOW=170K Continue POOH on TT f/ 9126' to 744" -Flow check (static) -Pumped dryjob @ 8650' -Stand back HWDP PJSM on handling RA sources -Stand back NM flex DC's -Remove RA sources from MWD -down load MWD - LD BHA Pull wear bushing -Set test plug -Change saver sub in TD & change top pipe rams to 7" -test rams to 250 & 5000 psi -Pull test plug -set thin wall wear bushing RU tro run 7" casing -Held PJSM Run 7" 26# L-80 MBTC casing as follows: FS (Ray Oil Tools sliver bullet} 2 jts. csg - FC (Weatherford} 2 jts_ casing (all connecetions made up w/ BakerLoc -fill pipe & check floats) 71 jts. csg (75 jts. total) to 3188' Circualte casing volume -stage pumps up to 4.5 bbls/min. @ 290 psi Continue running 7" 26# L-80 MBTC casing f/ 3188' to 6,380' (150 jts). CBU staged pump up from 3.3 bpm w/ 430 psi to 4.5 bpm w/ 370 psi. String wt. PUW=185K SOW=140K Cont'd RIH w 7" casing from 6,380' to 8,001' (188 jts}. String wt. PUW=235K SOW=150K Continue running 7" 26# L-80 csg f/ 8001' to 9569' (225 jts. total) Establish circulation -circulate btms up @ 4 bblslmin ICP 600 psi FCP 450 psi Continue running 7" 26# L-80 csg f! 9569' to 11,958' - PU hanger & landing jt. & land casing w/ shoe @ 11994.86' - FC @ 11907.85' - No problems running casing - no tight spots & no losses LD Frank's fill up tool - RU cement head & lines Establish circulation -stage pumps up to 6 bbls/min -circulate & condition for cement job - ICP 730 psi FCP 620 psi reciprocals pipe PU 325 k SO 165 k Held pre job meeting with crew on cementing operation Cement 7" casing as follows: Pumped 5 bbls CW-100 -Tested lines to 3700 psi -Pumped 35 bbls CW-100 @ 5 bbls/min @ 560 psi -Mixed & pumped 50 bbls 10.5 ppg MudPush XL spacer @ 5 bbls/min @ 560 psi -Dropped btm plug -Mixed & pumped 77.8 bbls 11.0 ppg lead slurry LiteCrete @ 6 bbls/mins @ 560 psi -Mixed & pumped 23 bbls 15.8 ppg tail slurry (class G w( additives) @ 4.4 bblslmin @ 350 psi -Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w! 436 bbls 9.8 ppg LSND mud @ 6.5 bbls /min @ 460 to 770 psi - slowed pumps to 3.5 bbls/min for last 35.9 bbls 570 psi top 700 psi bumped plug w/ 1200 psi -check floats OK - CIP @ 11:05 hrs. -Full returns through outjob -reciprocated pipe until half of lead slurry out of shoe Checked float, holding. Tested casing to 3500 psi for 30 mins. R/D cement and casing equip. UD landing jt. Pufled 7" wear ring. Installed 9.625"X7" packoff, energized lock downs and tested seals to 5000 psi for 10 mins. w/FMC. Printed: 2/1/2006 2:15:14 PM • • ConocoPhillips Alaska Operations Summary Report Page6of12~ Legal Well Name: CD4-319 Common Well Name: CD4-319 Spud Date: 10/30/2005 Event Name: ROT -DRILLING Start: 11/1/2005 End: 11/112005 Contractor Name: Doyon Drilling Inc Rig Release: 11/30/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To ~ Hours Code Co e Phase Description of Operations 11/10/2005 14:00 - 15:00 ~ 1.00 WELCTL~EORP INTRM1 Held PJSM. Changed ram to 3.5"X6" variable. 15:00 - 15:30 ~ 0.50 ~ DRILL ~ OTHR ~ INTRM1 ~ Installed short wear bushing. 15:30 - 19:15 3.75 DRILL PULD INTRM1 19:15 - 20:00 0.75 DRILL PULD INTRMI 20:00 - 00:00 4.00 DRILL PULD INTRM1 11/11/2005 00:00-00:30 0.50 DRILL PULD INTRM1 00:30-04:30 4.00 DRILL PULD INTRM1 04:30 - 05:00 0.50 RIGMNT RSRV INTRM1 05:00-07:30 2.50 DRILL PULD INTRM1 07:30-08:30 1.00 RIGMNT RSRV INTRM1 08:30 - 11:30 3.00 DRILL DRLG INTRM1 11:30 - 12:00 0.50 WELCTL OTHR INTRM1 12:00 - 19:15 7.25 WELCTL BOPE INTRM1 19:15 -19:45 0.50 WELCTL OTHR INTRM1 19:45 - 20:15 0.50 DRILL OTHR INTRM1 20:15 - 21:00 0.75 DRILL PULD INTRM1 21:00 - 00:00 3.00 DRILL TRIP INTRM1 11/12(2005 f 007:00 - 08:00 ~ 1.00 DRILL REAM INTRM1 08:00 - 12:00 I 4.001 CEMENlI DSHO I INTRM1 12:00 - 13:15 1.25 CEMEN DSHO INTRM1 13:15 - 14:00 0.75 DRILL CIRC INTRM1 14:00 - 14:45 0.75 DRILL FIT INTRM1 14:45 - 16:30 1.75 DRILL CIRC PROD 16:30 - 17:30 1.00 DRILL TRIP PROD 17:30 - 18:30 1.00 DRILL TRIP PROD 18:30 - 19:30 1.00 DRILL TRIP PROD 19:30 - 20:30 20:30 - 21:30 21:30 - 23:00 23:00 - 00:00 11/13/2005 00:00 - 06:30 06:30 - 09:00 1.00 DRILL TRIP PROD 1.00 DRILL CIRC PROD 1.50 DRILL TRIP PROD 1.00 DRILL TRIP PROD 6.50 DRILL TRIP PROD 2.50 DRILL PULD PROD 09:00 - 15:00 6.OOIDRILL (TRIP (PROD UD 5" DP via mouse hole. Move 6.75" DCs, UD jars, repositioned HW in derrick. Cont'd to UD 5" DP via mousehole. Finish laying down excess 5" DP via mouse hole Change over to 4" handling equipment - PU &RIH w/ 4" DP f/ pipe shed Service TD & draw works Continue PU &RIH w/ 4" DP f/ shed to 7350' (231 jts total) PJSM -Cut & slip drilling line 60' POOH w! 4" DP & rack back in derrick (77 stds) Pufl wear bushing -set test plug - RU to test BOPE Tested BOPs. Hydril to 250 & 3500 psi -Pipe rams ,blind rams, choke & kill line valves, choke manifold valves, floor safety & dart valves, TD IBOP valves to 250 & 5000 psi -Performed accumulator closure test - Witnessing of test waived by Lou Grimaldi of AOGCC. BLow down kill & choke lines - RD test equipment. Pulled test plug. Installed wear ring. Set block height for Schlumberger MWD. M/U BHA for cleanout run and FIT test. RIH w/ 4" DP from shed to 2,774'. String wt. PUW=110K SOW=100K @ 2,774' Continue RIH -picking up 4" DP f! pipe shed f/ 2770' to 11,641' RIH w/DP f/derrick to 11,738' -Wash & ream f/ 1,738' to 11,862' (tag top of cmt.) Clean out shoe track f/ 11,862' (drill FC @ 11,907') hard cmt to 11,995' (top of FS) Drill out FS & clean out rat hole to 12,D05' -Drill 20' new hole to 12,025' Circulate hole clean for FIT . R/U for FIT and performed. 12.5 EMW. Blew down, rig down. Changed over to 9.2 ppg Flo-Pro system. Obtained SPRs, checked flow, static. SPR#1=20stkl550psi, 30stk/700psi SPR#2=20stk/530psi, 30stk/650psi POOH w/ pumps from 11,995' to 11,551' @ 4 bpm, 850 psi. POOH on TT from 11,551' to 10,407' w/ improper fill. Circa B/U @ 6 BPM, 1300 psi, 20 rpm. Carbonate screening out over shakers, mud weight had decreased to 9.1 ppg. RIH from 10,407'to 11,994'. Weighted up to 9.2 ppg, circa bypassing shakers @ 6 bpm, 1500 psi, 30 rpm, TO=8K. POOH w/ pumps from 11,994'to 11,074 @ 4 bpm, 750 psi. Checked flow, static. Proper fill volumes. POOH on TT from 11,074' to 10,597'. String wt. PUW=195K SOW=150K @ 10,597. Continue to POOH on TT f/ 10,597' to 196' -Flow cheek (static) Std back HWDP - LD bit & NB stab - MU Schlumberger power drive (rotary steerable system)w/ Periscope 15 &MWD -Surface test tools - PU NM flex DC's & RIH w/ HWDP & jars to 363' RIH f/ 363' to 11,809' w/ Schlumberger rotary steerable system -filling every 20 stds. Printed: 2/1/2006 2:15:14 PM • ~ ConocoPhillips Alaska Page 7 of 12 Operations Summary Report Legal Well Name: CD4-319 Common Well Name: CD4-319 Spud Date: 10/30/2005 Event Name: ROT -DRILLING Start: 11/1/2005 End: 11/1/2005 Contractor Name: Doyon Drilling Inc Rig Release: 11/30/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours I Code Cod I Phase i Description of Operations 11!1312005 15:00 - 16:00 1.00 RIGMNT RSRV PROD PJSM -Cut & slip 60' drill line -adjust brakes SPR#1=20stk/730psi, 30stk/1080psi SPR#2=20stk/690psi, 30stk/960psi @ 11,809'and 1500hrs 16:00 - 16:45 0.75 DRILL OTHR PROD Hook up Schlumberger wt. indicator & calibrate 16:45 - 17:00 0.25 DRILL TRIP PROD RIH f! 11,809'to 12,000'. 17:00 - 17:45 0.75 DRILL OTHR PROD Pumped and established clean hole ECD baseline of 10.4-10.6 ppg wi 200-230 gpm. 17:45 - 00:00 6.25 DRILL DRLG PROD Drilled from 12,025' to 12,315' MDI 7,157' TVD. ADT=3.40 WOB 3/8 k RPM 100 GPM 230 @ 2400 psi String wt. PUW=200K SOW=150K ROT=175K Torque on/off btm. - 10,000/8,500 ft. lbs. ECD - 10.5 ppg 111/14/2005 100:00 - 11:00 I 11.001 DRILL I DRLH I PROD 11:00 - 12:30 1.50 DRILL OTHR PROD 12:30 - 17:00 4.50 DRILL DRLH PROD 17:00 - 18:00 1.00 DRILL DRLH PROD 18:00 - 18:30 0.50 DRILL DRLH PROD 18:30 - 19:45 I 1.251 DRILL I CIRC I PROD 19:45 - 22:45 22:45 - 00:00 11 /15/2005 00:00 - 06:00 06:00 - 10:30 3.00 DRILL TRIP PROD 1.25 DRILL TRIP PROD 6.00 DRILL TRIP PROD 4.50 DRILL PULD PROD 10:30 - 16:30 16:30 - 17:00 17:00 - 18:00 6.00 DRILL TRIP PROD 0.50 RIGMNT RSRV PROD 1.00 DRILL TRIP PROD 18:00 - 19:30 I 1.501 DRILL (TRIP I PROD Drill 6 1/8" horz. section f/ 12,315'to 12,855' MD 71.48" TVD ADT - 8.53 hrs. WOB 7/9 k RPM 100 GPM 241 @ 2500 psi String wt. PU 205 SO 145 Rot 175 Torque onloff btm. - 10,500!9,500 ft. Ibs EGD-10.7 to 10.8 ppg Trouble shoot periscope tool -std back 1 std. MAD pass f/ 12,733' to 12,855' -tool responding OK Drill 6 1/8" horz. section f/ 12,855'to 13,132' MD/ 7,141' TVD. ADT=3.61 hr Trouble shoot log tools. Drilled from 13,132'to 13,146' MD17,141' TVD. ADT=0.2 hr TDT=3.81 hr Circa and cond. mud for trip. Checked flow, static. String wt. PUW=200K SOW=145K ROT=175K TQon/off=10K/9K SPR#1=20stk/610psi, 30stk/880psi SPR#2=20stk/560psi, 30stk/950psi all @ 13,146' and 1930 hrs Pumped out from 13,146' to 11,236' w! 230 gpm, 100 rpm, 2210 psi, 8K TO. POOH on TT from 11,236' to 10,764'. Checked flow, static. String wt. PUW=210K SOW=145K @ 10,764'. Continue to POOH w/ Schlumberger 6 1/8" BHA f! 10,740' to 363' - Flow check (static) -' Pumped dry jab @ 8850' Stand back HWDP, jars, & NM flex DC's -Break bit -Change out Periscope - MWD & bios controller on power drive & MU new bit - Surface test toots -RIH wl NM flex DC's -HWDP & jars to 364' * Note: Function test BOPE RIH w/ 6 1/8" Schlumberger steerable drilling system f1364' to 11,810' (filling pipe every 20 stds) Service TD -draw works -crown & iron roughneck Continue RIH f/ 11,810'to 12,955' Break circulation @ 3 bbls/min -stage pump up to 5 bbls/mni -Wash down & survey @ 12,954', 13,050' -MAD pass f/ 13,050' to 13,146' - 240 gpm @ 2400 psi Printed: 2/1!2006 2:15:14 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD4-319 Common Well Name: CD4-319 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date From - To Hours Code Code Phase 11/15/2005 19:30 - 00:00 4.50 DRILL DRLH PROD 11/16/2005 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 11/17/2005 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 16:15 4.25 DRILL DRLH PROD 16:15 - 17:45 1.50 DRILL CIRC PROD 17:45 - 00:00 6.25 DRILL TRIP PROD 11/18/2005 00:00-01:30 1.50 DRILL TRIP PROD 01:30 - 04:30 3.00 DRILL TRIP PROD 04:30 - 10:30 6.00 DRILL TRIP PROD 10:30 - 12:45 2.25 DRILL PULD PROD 12:45 - 14:15 1.50 DRILL PULD PROD 14:15 - 20:30 6.25 DRILL TRIP PROD 20:30 - 21:30 1.00 RIGMNT RSRV PROD Page 8 of 12 ~ Spud Date: 10/30/2005 Start: 11/1/2005 End: 11/1/2005 Rig Release: 11/30/2005 Group: Rig Number: 19 Description of Operations Drill 6 1/8" horn. section f/ 13,146'to 13,500' MD 7156' ND ADT - 2.7 hrs. WOB 5/10 k RPM 100 GPM 230 @ 2400 psi String wt. PU 210 SO 150 Rot 175 Torque on/off btm. - 11,000/9,500 ft. lbs. ECD - 10.5 to 10.7 ppg Drill 6 1/8" horz. section f/ 13,500' MD to 14,292' 7147' ND ADT - 7.46 hrs. WOB 6/9 k RPM 100. GPM 230 @ 2500 psi String wt. PU 210 SO 140 Rot 170 Torque onloff btm. - 11,500!10,500 ft. lbs. ECD - 10.6 to 10.9 ppg Drill 6 1/8" horz. section f/ 14,292' to 14,830' MD 7148" ND ADT - 7.29 hrs. WOB 3/10 k RPM 100!60 GPM 241 @ 2430 to 2610 psi String wt. PU 205 SO 140 Rot 170 Torque on/off btm. - 11,000/9,500 ft. lbs. ECD - 10.8 to 10.95 ppg Drill 6 1/8" horz. section f/ 14,830' to 15,470' MD 7148' ND ADT - 7.75 hrs. WOB 10/12 k RPM 100 GPM 258 @ 2840 psi String wt. PU 220 SO 130 Rot 170 Torque on/off btm. - 12,500/11,000 ft. lbs. ECD - 10.8 to 11.2 ppg Drill 6 1/8" horz. section f/ 15,470' to 15,903' MD 7149' ND ADT - 2.89 hrs. WOB 10120 k RPM 70 to 120 GPM 240 to 258 @ 2500 to 3000 psi String wt. PU 200 SO 130 Rot 160 Torque onloff btm. - 14,000/10,000 ft. lbs. ECD - 10.76 to 11.33 ppg ' Note: having problem with power drive rotary steerable tool Circulate hole clean for trip out -260 gpm @ 2970 psi @ 100 rpm 10,000 ft lbs. torque -Flow check {static) POOH - backreaming w/ pump @ 230 gpm w! 80 rpm - 11,000 torque f/ 15903' to 13,151' -tight spot @ 14,742' (25 k over) worked through tight hole f/ 14,702' to 14,694' (hole packing off) Re-survey as directed while coming out of hole (Flow checks were static) Backream from 13,151' to shoe (11,995') 223 gpm / 2150 psi / 80 rpm Monitor well, static. Pump out from 11,995' to 9,998' 233 gpm / 1820 psi Flow check well, static. POOH on trip tank from 9,998' to 364` -hole taking proper fill. Flow check well @ 1000', static. Stand back hwdp and flex collars -lay down MWD collar, Periscope and rotary steerable system -dump memory and initialise MWD collar Seals on Power Drive pistons failed. (Serviced Top Drive) PU new rotary steerable assembly, Periscope, Impulse MWD collar- MU bit and shallow test tools. RIH with flex collars and hwdp RIH with 4" drill pipe f/ 364' to 11,810' - fill pipe every 20 stands - monitordisplacement with trip tank. Cut & slip drill line 60' Printed: 2/1!2006 2:15:14 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: CD4-319 CD4-319 ROT -DRILLING Doyon Drilling Inc Doyon 19 Date From - To ~ Hours Code ~ Sub ~ Phase 11/18/2005 20:30 - 21:30 1.00 RIGMNT RSRVe I PROD 21:30 - 00:00 I 2.501 DRILL I TRIP I PROD X11/19/2005 ~ 00:00 - 01:00 ~ 1.00 ~ DRILL ~ TRIP ~ PROD 01:00 - 02:45 I 1.75 I DRILL I CIRC I PROD 02:45 - 12:00 I 9.251 DRILL I DRLH I PROD 12:00 - 00:00 I 12.001 DRILL I DRLH I PROD 111/20/2005 100:00 - 11:30 I 11.501 DRILL I DRLH I PROD 11:30 - 12:45 ~ 1.25 ~ DRILL ~ TRIP ~ PROD 12:45 - 16:00 I 3.251 DRILL I TRIP I PROD 16:00 - 17:45 I 1.751 DRILL I TRIP I PROD 17:45 - 18:15 0.50 DRILL TRIP PROD 18:15 - 19:30 1.25 DRILL REAM PROD Page9of12~ Spud Date: 10/30/2005 Start: 1111 /2005 End: 1111 /2005 Rig Release: 11/30/2005 Group: Rig Number: 19 Description of Operations String wt PU 215 SO 155 Rot 183 @ 50 rpm torque 9,000 40 rpm torque 8,500 Continue RIH f/ 11,810' to 14,725' -took wt @ 14,702' -work pipe to 14,725' Work pipe out f/ 14,725' to 14,673' wl rotary -Establish circulation wash & ream down f/ 14,673' to 14,769` @ 4 bbls /min @ 1640 psi w/ 50 rpm's @ 12,000 ft/Ibs torque -rotate down (no pump)f/ 14,769' to 14,960' w/ 50 rpm's @ 12,000 ft/Ibs torque -string taking wt 25 to 30 K while rotating down -Continue to RIH f! 14,960' to 15,818' Stage pumps up slowly to 235 gpm / 2420 psi / 100 rpm - 12,500 ft/Ibs torque -Wash down f/ 15,818' to 15,903' -Circulate btms up - No gas on btms up - mud wt. 9.6+ ppg Drill 6 1/8" horz. section f/ 15,903' to 16,256' MD 7138' TVD ADT - 5.68 hrs. WOB 8/13 k RPM 100 GPM 255 @ 2500 psi String wt. PU 225 SO 125 Rot 170 Torque on/off btm. - 13,000/12,000 ft. lbs. ECD - 11.0 to 11.1 ppg Drill 6 1/8" horn. section fI 16,256' to 16,854' MD 7148' TVD ADT - 7.54 hrs. WOB 8/13 k RPM 100 GPM 235 @ 2610 psi String wt. - PU 230 SO 125 Rot 170 Torque on/off btm. - 13,000/12,000 ft Ibs ECD-11.Oto 11.2 ppg Drill 6 1!8" horz. section f/ 16,854' to 17,241' MD 7143' TVD ADT - 8.43 hrs. WOB 8116 k RPM 100 GPM 248 @ 2700 psi String wt. - PU 235 SO 120 Rot 170 Torque onloff btm. - 13,500/12,000 ft Ibs ECD - 11.0 to 11.2 ppg Observed pressure loss from 2730 psi to 2330 psi in last 8 minutes drilling. Troubleshoot surface equipment -pressure test pumps and lines - no problems seen -suspect drill string washout. Flow check well, static. Pump out of hole - 126 gpm / 830 psi / 30 rpm @ 13K ftllbs from 17,241' to 15,914' -observed 1.5" vertical washout in pipe body 14 inches below tool joint on the top single of stand #163. Worked joint out of hole pulling 50K over -laid down joint. " Hole packing off while working through tight spots from 16,055' to 15,942' " P/U single and MU top drive -work pipe free with rotation -establish circulation and stage pumps up to 214 gpm / 2210 psi with full returns. RIH from 15,914', unable to pass 15,950', pick up and wash and ream from 15,914' to 16,105 - 126 gpm / 1070 psi / 40 rpm @ 12K ft/Ibs RIH f/ 16,105'to 17,155' w/ no problems Estabish circulation -Stage pumps up f/ 2,5 bbls/min to 5.5 bbls/min 980 to 2820 psi w/ 50 to 100 rpm 12,000 ft/Ibs torque -wash & ream f/ 17,155'to 17,241' 19:30 - 00:00 4.50 DRILL DRLH PROD Drill 6 1/8" horz. section f/ 17,241' to 17,415' MD 7145' TVD ADT - 2.81 hrs. WOB 8/15 k RPM 100 GPM 243 @ 2880 psi String wt. PU 230 SO 115 Rot 170 Printed: 2/1(2006 2:15:14 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD4-319 Common Well Name: CD4-319 Event Name: ROT -DRILLING Contractor Name: Doyon Drilling Inc Rig Name: Doyon 19 Date ~ From - To Hours Code ~ Code Phase 11/20/2005 19:30 - 00:00 4.50 DRILL DRLH PROD 111/21/2005 100:00 - 12:00 I 12.001 DRILL I DRLH I PROD 12:00 - 00:00 I 12.001 DRILL I DRLH I PROD 111/22/2005 100:00 - 07:00 I 7.001 DRILL I DRLH I PROD Start: 11 /1 /2005 Rig Release: 11/30/2005 Rig Number: 19 Page 10 of 12 Spud Date: 10/30/2005 End: 11 /1 /2005 Group: Description of Operations Torque on/off btm. - 14,000/13,000 ft Ibs ECD - 11.12 to 11.22 ppg Drill 6 1/8" horz. section f/ 17,415' to 17,911' MD 7143' TVD ADT - 7.89 hrs. WOB 8/18 k RPM 100 GPM 248 @ 2850 psi String wt. - PU 235 SO 120 Rot 170 Torque on/off btm. - 14,000/12,50D ft Ibs ECD - 11.0 to 11.3 ppg Drill 6 1/8" horz. section f/ 17,911' to 18,832' MD 7139' TVD ADT - 8.65 hrs. WOB 8/20 k RPM 70/100 GPM 260 @ 3250 psi String wt. PU 225 SO 120 Rot 170 Torque on/off btm. - 15,000/ 14,000 ft. lbs. ECD - 11.5 to 11.7 ppg Drill 6 1/8" horz. section f/ 18,382' to 18,683' MD 7133' TVD ADT - 5.14 hrs. WOB 8/18 k RPM 100 GPM 260 @ 3390 psi String wt. PU 235 SO 115 Rot 165 Torque onioff btm. - 15,000! 13,000 ft. Ibs. ECD - 11.5 to 11.7 ppg "' Crossed mapped fault @ 18,548' unable to build angle with rotary steerable, geologist called TD @ 18,683' 07:00 - 08:30 1.50 DRILL TRIP PROD Backream from 18,683' to 18,491' - 214 gpm ! 2580 psi ! 40 rpm Reduce pump rate and work through slight packoff problems from 18,558' to 18,540'. 08:30 - 12:00 3.50 DRILL CIRC PROD Circulate hole clean -pumped 35 bbls low vis sweep afiter first BU - no increase in cuttings with sweep back Conditioned mud @ 240 gpm / 2900 psi / 90 rpm @ 12.5K ft/Ibs initial ECD-11.55, final 11.33 12:00 - 17:30 5.50 DRILL TRIP PROD Pump out from 18,491' to 16,582', 184 gpm / 2000 psi / 70 rpm worked through tight spot from 18,355' to 18,348' -slight pack off. Re-survey five stations. 17:30 - 23:30 6.00 DRILL CIRC PROD Circulated and raised mud weight to 9.8 PPG for trip margin. 23:30 - 00:00 0.50 DRILL TRIP PROD Pump out from 16,582' to 16,296', 184 gpm / 1900 psi / 70 rpm . 11!23/2005 00:00 - 14:15 14.25 DRILL TRIP PROD POOH with pump from 16,296' to 11,980'. Worked through tight hole with multible pack offs @ 16,119' (stuck and worked free), to 15,940'. Continued POOH to next shale @ 14,870'. Packed off while backreaming. POOH with pump (no rotation) to 14,700'. POOH with pump @ 168 GPM and 50 RPM to 11,980'. 14:15 - 18:00 3.75 DRILL CIRC PROD Circulated and added casing lube to mud. Before tube Up Wt. 217 K, Dn Wt. 152 K, Rot Wt. 181 K. After lube Up Wt. 215 Dn. 155 Rot 1$0 K. 18:00 - 20:30 2.50 DRILL TRIP PROD POOH with pump @ 3 BPM from 11,980'to 10,093'. Monitored well. 20:30 - 00:00 3.50 DRILL TRIP PROD POOH on trip tank from 10,093' to 7,044'. 11!24!2005 00:00 - 03:15 3.25 DRILL TRIP PROD POOH from 7044' -set back hwdp and flex collars 03:15 - 04:30 1.25 DRILL PULD PROD LD BHA #7 -clear tools from rig floor 04:30 - 07:00 2.50 CMPLTN OTHR CMPLTN Move equipment for liner and liner running string onto rig floor - RU to run liner 07:00 - 07:15 0.25 CMPLTN SFTY CMPLTN Held Prejob safety and Opts meeting with crew 07:15 - 12:30 5.25 CMPLTN RUNT CMPLTN PU and RIH 167 jts of 4 1/2", 12.6#, L-80 Slotted and blank liner (6650') 12:30 - 13:45 1.25 CMPLTN OTHR CMPLTN Change running tools and RU to run 2 7/8" inner string 13:45 - 14:00 0.25 CMPLTN SFTY CMPLTN PU and RIH w/ 2 7/8" inner string Printed: 2/1/2006 2:15:14 PM ConocoPhi~lips Alaska Page 11 of 12 Operations Summary Report Legal Well Name: CD4-319 Common Well Name: CD4-319 Spud Date: 10/30/2005 Event Name: ROT -DRILLING Start: 11/1/2005 End: 11/1/2005 Contractor Name: Doyon Drilling Inc Rig Release: 11/30/2005 Graup: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours Code Phase Description ofi Operations Code 11/24/2005 14:00 - 21:00 7.00 CMPLTN PULD CMPLTN RIH and spaced out inner string to 3' above No Go nipple. 21:00 - 22:30 1.50 CMPLTN PULD CMPLTN Picked up Liner hanger and attempted to make it up, no success. Laid down hanger. The weight of the inner string would not allow the SLHT connection to turn. 22:30 - 00:00 1.50 CMPLTN PULD CMPLTN Broke out and Picked up swivel from Camfield Bushing and made it up on top of hanger. Made up Liner Hanger. 11/25/2005 00:00 - 02:00 2.00 CMPLTN RUNT CMPLTN RIH with Baker liner hanger -change running tools to 4" - PU 3 joints of hwdp - circ 1 pipe volume @ 1.5 bpm / 750 psi -attempted to rotate pipe, stalled at 6500 ft/Ibs 02:00 - 02:30 0.50 RIGMNT RSRV CMPLTN Service rig 02:30 - 03:45 1.25 RIGMNT RGRP CMPLTN Troubleshoot and repair Top Drive grapper system 03:45 - 04:45 1.00 CMPLTN RUNT CMPLTN RIH to 7200', picking up hwdp from shed 04:45 - 06:30 1.75 RIGMNT RGRP CMPLTN Continue to troubleshoot and repair grabber system 06:30 - 12:15 5.75 CMPLTN RUNT CMPLTN Continue to pick up 4" hwdp (33 jts total) rih with 4" drill pipe to 11,989' "Ran one WWT non rotating centralizer in the center of the first 97 joints above liner. 12:15 - 13:15 ~ 1.00 ~ CMPLTNI CIRC ~ CMPLTN 13:15 - 20:45 { 7.50 { CMPLTNI RUNT {CMPLTN 20:45 - 22:00 I 1.251 CMPLTNI PCKR I CMPLTN 22:00 - 00:00 I 2.00 I CMPLTNI PCKR I CMPLTN 11/26/2005 00:00 - 02:30 2.50 CMPLTN CIRC CMPLTN 02:30 - 04:15 1.75 CMPLTN TRIP CMPLTN 04:15 - 04:45 0.50 CMPLTN TRIP CMPLTN 04:45 - 07:00 2.25 CMPLTN CIRC CMPLTN 07:00 - 12:00 5.00 CMPLTN TRIP CMPLTN 12:00 - 18:30 6.50 CMPLTN TRIP CMPLTN 18:30 - 19:45 1.25 CMPLTN PULD CMPLTN 19:45 - 20:15 0.50 CMPLTN PULD CMPLTN 20:15 - 00:00 3.75 CMPLTN PULD CMPLTN 11/27/2005 00:00 - 04:00 4.00 CMPLTN TRIP CMPLTN 04:00 - 04:30 0.50 CMPLTN OTHR CMPLTN 04:30 - 09:45 5.25 WELCTL BOPE CMPLTN 09:45 - 10:00 0.25 CMPLTN OTHR CMPLTN 10:00 - 10:15 0.25 LOG SFTY CMPLTN 10:15 - 16:30 5.75 LOG ELOG CMPLTN 16:30 - 18:00 1.50 RIGMNT RSRV CMPLTN 18:00 - 18:30 0.50 CMPLTN RURD CMPLTN 18:30 - 20:00 1.50 CMPLTN RURD CMPLTN 20:00 - 21:45 1.75 CMPLTN RUNT CMPLTN Establish circulation - 1.5 bpm ! 950 psi -rotated liner @ 10 rpm / 11.5k ft/Ibs 153k Rot. PUW 238K SOW 150k RIH with liner from 11,989' to 18,521 worked through tight spots at 14,771 and 14786' with slight effort -worked through tight spot from 16,007' to 16,015' tough going - Continued to RIH to 18,521'. Dropped ball and presured up to 3000 psi to set liner hanger. Checked hanger with weight OK. Attempted to shear ball with 4,500 psi. No success. Blew down top drive, spaced out, and rigged up Dowell. Tested lines to 5,000 psi. Sheared ball with 4,800 psi. Estabilished circulation to displace with brine. Displaced well with 9.5 PPG brine. POOH from 18,500' to 17,810' Hole fill not correct. Observed well. RIH to 18,500'. Circulated and raised MW to 9.7 PPG. POOH with pump to 15,170'. POOH on trip tank to HWDP @ 7,568'. Laid down 33 jts. 4" HWDP. Rigged up to handle 2 7!8" tubing. POOH laid down running tools and 107 jts. inner string. POOH -laid down 105 joints of 2 7/8" tubing -clear tools -subs and running tools from rig floor Pull wear bushing Set test plug -test rams, choke, kill, manifold and surface safety valves to 200/5000 psi -tested annular preventor 200/3500 psi. Chuck Scheve (AOGCC) waived witnessing test. Pull test plug Install wear bushing Held safety meeting with drill crew and Schlumber loggers RU loggers -RIH with USIT tools, stopped @ 11,775' (78 degrees) Evalauate cement bond from 11775' to 9000' - TOC @ 9360', good bond throughout run -POOH with tool string -lay down tools and RD Schlumber Slip and cut drilling line -service drawworks and top drive Pulled wear bushing. Picked up Weatherford equipment and rigged up to run tubing. RIH with 4 1/2" completion to 940'. Printed: 2/1/2006 2:15:14 PM • ConocoPhiliips Alaska Page 12 of 12 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD4-319 CD4-319 ROT -DRILLING Doyon Drilling Inc Doyon 19 Spud Date: 10/30/2005 Start: 11/1/2005 End: 11/1/2005 Rig Release: 11/30/2005 Group: Rig Number: 19 Date From - To Hours Code Code Phase 11/27/2005 21:45 - 23:00 1.25 CMPLTN RURD CMPLTN 23:00 - 00:00 1.00 CMPLTN OTHR CMPLTN 11/28/2005 00:00 - 01:45 1.75 CMPLTN RUNT CMPLTN 01:45 - 12:00 10.25 CMPLTN RUNT CMPLTN 12:00 - 15:45 I 3.751 CMPLTNI RUNT I CMPLTN 15:45 - 18:00 I 2.251 CMPLTNI CIRC I CMPLTN 18:00 - 20:30 ~ 2.50 ~ CMPLTNI SOHO ~ CMPLTN 20:30 - 21:30 I 1.001 CMPLTNI DEQT I CMPLTN 21:30 - 22:15 0.75 CMPLTN RURD CMPLTN 22:15 - 00:00 1.75 CMPLTN NUND CMPLTN 11/29/2005 00:00 - 02:00 2.00 CMPLTN NUND CMPLTN 02:00 - 03:15 1.25 CMPLTN NUND CMPLTN 03:15 - 04:30 1.25 CMPLTN RURD CMPLTN 04:30 - 06:45 ~ 2.25 ~ CMPLTNI FRZP ~ CMPLTN 07:30 - 09:30 I P.OOI CMPLTNI DEQT I CMPLTN 09:30 - 11:30 ~ 2.00 ~ CMPLTNI RURD ~ CMPLTN 12:00-00:00 I 1o.00IDRLLTNIPULD (CMPLTN Description of Operations Hung sheve and rigged up to run Weatherford Encapsulated line. Testing and trouble shooting Weatherford control line. Troubleshoot Weatherford POD2 equipment Continue to run 4 1/2" completion equipment attaching one cannon Clamp perjoint to 8,540'. Continue to run 4 1/2" completion equipment attaching one cannon Clamp perjoint to 11,849'. Total of 270 clamps used. Made up top drive and washed down to confirm entry of liner hanger with tubing. Saw slight increase in pump pressure and tagged up. Noted discrepiency in tally depth. Confirmed tag up several times. Blew down Top drive. POOH 3 jts and made up 10' pup jt. RIH with 2 jts and made up tubing hanger with encapsulated line. Landed out string @ 11,847'. Ran in lock down screws and installed TWC valve. Tested hanger to 5,000 psi. Rigged down tubing. running tools and Weatherford equipment. PJSM and nippled down BOP. Terminate Weatherford POD2 gauge cable Install adaptor flange and tree -test same to 5000 psi for ten minutes RU test manifold -hardline to wellhead tubing and annulus valves - pressure test lines to 2500 psi Dowell pumped down tubing - 144 bbls of 9.4 ppg inhibited brine followed by 229 bbls of diesel -wellhead pressure after displacement = 850 psi RU Doyon lubricator and dropped packer setting ball and rod Set packer with 4800 psi - held pressure on tubing far 30 min. FSIP=4425 psi -bled tubing to 1600 psi -pressure tested annulus to 3500 psi for 30 min. - fina4 pressa.ire =3490 psi Secured well. Set BPV. Rigged down hard lines and squeeze manifold. Picked up tools. Rigged up to lay down drill pipe from derrick. laid down 357 Jts. 4" DP in mousehole. Laid down flex collars (Schlumberger) and 6 3/4" DC's. Rearranged derrick for rig move. Printed: 2{1!2006 2:15:14 PM ConocoPhillips Alaska, lnc. Alaska North Slope North Slope, Alaska CD4-319 Job No. AK-ZZ-0004025926, Surveyed: 8 November, 2005 Survey Report 20 December, 20D5 Your Ref: API 501032051600 Surface Coordinates: 5957442.46 N, 377824.39E (70° 17' 32.0873" N, 150° 59' 20.9320" VIA Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 55.50ft above Mean Sea Level sp~rry-sun ~RI~~i~+~ ~e=RV~~~.~ SurveyRef.•svy527 A Halliburton Company • • ConocoPhillips Alaska, Inc. Survey Report for CD4-319 Your Ref.• API 501032051600 Job No. AK-ZZ-0004025926, Surveyed: 8 November, 2005 Alaska North Slope Measured True Subsea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -55.50 0.00 0.00 N 0.00 E 167.00 0.250 207.000 111.50 167.00 0.32 S 0.17 W 246.00 1.750 192.000 190.49 245.99 1.66 S 0.49 W 349.00 2.800 200.000 293.40 348.90 5.56 S 1.68 W 414.85 4.230 203.090 359.13 414.63 9.31 S 3.18 W 502.68 7.050 199.740 446.52 502.02 17.36 S 6.28 W 595.29 10.700 199.610 538.01 593.51 30.81 S 11.08 W 684.43 12.780 200.830 625.28 680.78 47.83 S 17.37 W 773.42 15.060 201.160 711.65 767.15 67.81 S 25.04 W 864.14 18.010 201.090 798.61 854.11 91.89 S 34.34 W 959.29 22.910 200.520 887.73 943.23 122.98 S 46.14 W 1054.69 27.660 199.460 973.97 1029.47 161.27 S 60.03 W 1149,74 30.140 199.400 1057.17 1112.67 204.59 S 75.31 W 1244.43 30.730 199.420 1738.81 1194.31 249.83 S 91.25 W 1338.35 34.670 200.200 1217.83 1273.33 297.55 S 108.46 W 1435.24 38.430 201.190 1295.66 1351.16 351.51 S 128.87 W 1530.44 40.170 201.530 1369.32 1424.82 407.66 S 150.83 W 1624.41 41.830 201.170 1440.24 1495.74 465.08 S 173.27 W 1720.97 43.930 203.020 1511.00 1566.50 525.94 S 198.00 W 1816.13 45.990 200.650 1578.33 1633.83 588.35 S 222.98 W 1910.60 48.280 201.100 1642.59 1698.09 653.04 S 247.66 W 2005.89 50.880 200.980 1704.37 1759.87 720.75 S 273.70 W 2101.25 53.700 200.660 1762.70 1818.20 791.26 S 300.51 W 2195.98 55.970 201.260 1817.25 1872.75 863.57 S 328.21 W 2291.07 58.500 202.750 1868.71 1924.21 937.69 S 358.18 W 2385.85 59.100 203.110 1917.81 1973.31 1012.35 S 389.77 W 2480.87 59.200 201.600 1966.54 2022.04 1087.79 S 420.80 W 2575.86 58.820 197.950 2015.46 2070.96 1164.40 S 448.34 W 2671.08 59.060 196.980 2064.59 2120.09 1242.21 S 472.82 W 2765.83 59.140 199.720 2113.25 2168.75 1319.36 S 498.41 W 2861.62 57.170 200.190 2163.79 2219.29 1395.85 S 526.18 W 2956.76 58.660 198.520 2214.33 2269.83 1471.90 S 552.88 W 3052.00 57.860 200.530 2264.43 2319.93 1548.23 S 579.95 W 3136.98 58.040 200.500 2309.53 2365.03 1615.69 S 605.19 W 3226.00 57.570 200.860 2356.96 2412.46 1686.17 S 631.79 W North Slope, Alaska Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°I100ft) 5957442.46 N 377824.39 E 5957442.14 N 377824.22E 0.150 5957440.81 N 377823.87E 1.911 5957436.93 N 377822.62E 1.063 5957433.21 N 377821.05E 2.190 5957425.20 N 377817.83E 3.231 5957411.83 N 377812.81E 3.941 5957394.92 N 377806.25E 2.350 5957375.07 N 377798.25E 2.564 5957351.14 N 377788.56E 3.252 Vertical Section Comment 0.00 CB-SS-Gyro 0.09 0.10 0,35 MWD+IIFR+MS+SAG 0.94 2.08 3.65 5.82 8.66 12.13 5957320.25 N 377776.26E 5.154 16.40 5957282.19 N 377761.75E 5.001 21.05 5957239.12 N 377745.77E 2.609 25.88 5957194.15 N 377729.09E 0.623 30.91 5957146.72 N 377711.11E 4.219 36.60 5957093.10 N 377689.83E 3.928 43.96 5957037.31 N 377666.95E 1.842 52.33 5956980.26 N 377643.58E 1.784 60.86 5956919.81 N 377617.87E 2.535 70.82 5956857.81 N 377591.88E 2.790 80,67 5956793.53 N 377566.15E 2.449 89.70 5956726.26 N 377539.01E 2.730 99.35 5956656.19 N 377511.06E 2.969 109.10 5956584.34 N 377482.19E 2.452 119.31 5956510.72 N 377451.01E 2.969 131.30 5956436.58 N 377418.22E 0.712 144.74 5956361.65 N 377385.97E 1.368 157.45 5956285.50 N 377357.18E 3.318 166.51 5956208.10 N 377331.44E 0.908 172.30 5956131.37 N 377304.60E 2.483 179.33 5956055.35 N 377275.59E 2.098 188.63 5955979.74 N 377247.66E 2.160 197.00 5955903.86 N 377219.36E 1.982 205.65 5955836.82 N 377193.02E 0.214 214.58 5955766.78 N 377165.28E 0.629 224.14 • • 20 December, 2005 - 10:14 Page 2 of 8 DrillQuest 3.03,06.008 ConocoPhillips Alaska, inc. Survey Report for CD4-319 Your Ref: API 501032051600 Job No. AK 2Z-0004025926, Surveyed: 8 November, 2005 Alaska North Slope Measured True Subsea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) ~°/100ft) 3290.66 57.220 201.120 2391.80 2447.30 1737.02 S 651.30 W 5955716.25 N 377144,94E 0.639 231.34 3385.43 57.030 202.160 2443.24 2498.74 1811.01 S 680.65 W 5955642.76 N 377114.39E 0.943 242.76 3480.59 56.100 201.670 2495.68 2551.18 1884.68 S 710.29 W 5955569.57 N 377083.56E 1.068 254.54 3575.75 54.590 202.180 2549.79 2605.29 1957.29 S 739.52 W 5955497.44 N 377053.16E 1.647 266.15 3671.39 53.550 202.740 2605.91 2661.41 2028.86 S 769.10 W 5955426.37 N 377022.42E 1.186 278.35 3766.89 54.780 203.570 2661.82 2717.32 2100.04 S 799.55 W 5955355.69 N 376990.82E 1.468 291.49 3862.17 54.240 203.940 2717.13 2772.63 2171.05 S 830.80 W 5955285.20 N 376958.42E 0.649 305.45 3956.90 53.680 203.870 2772.87 2828.37 2241.08 S 861.84 W 5955215.69 N 376926.24E 0.594 319.43 4052.63 53.910 204.650 2829.41 2884.91 2311.50 S 893.58 W 5955145.79 N 376893.36E 0.700 333.99 4147.95 53.480 204.980 2885.85 2941.35 2381.22 S 925.81 W 5955076.60 N 376860.00E 0.530 349.21 4243.43 54.080 203.750 2942.27 2997.77 2451.39 S 957.59 W 5955006.96 N 376827.09E 1.214 363.87 4338.53 54.800 205.090 2997.58 3053.08 2521.83 S 989.58 W 5954937.05 N 376793.96E 1.374 378.67 4434.14 54.660 205.870 3052.78 3108.28 2592.29 S 1023.16 W 5954867.14 N 376759.24E 0.682 395.02 4529.18 54.480 206.770 3107.88 3163.38 2661.71 S 1057.49 W 5954798,29 N 376723.78E 0.795 412.35 4624.58 56.140 206.490 3162.17 3217.67 2731.83 S 1092.65 W 5954728.75 N 376687.49E 1.757 430.31 4718.74 57.390 208.740 3213.78 3269.28 2801.60 S 1129.16 W 5954659.58 N 376649.85E 2.399 449.68 4813.47 58.880 208.140 3263.79 3319.29 2872.34 S 1167.47 W 5954589.47 N 376610.39E 1.662 470.56 4908.80 58.970 208.860 3313.00 3368.50 2944.10 S 1206.43 W 5954518.36 N 376570.27E 0.654 491.85 5003.62 59.130 209.830 3361.77 3417.27 3014.98 S 1246.28 W 5954448.13 N 376529.27E 0.893 514.20 5099.05 60.470 209.170 3409.77 3465.27 3086.76 S 1286.89 W 5954377.02 N 376487.50E 1.526 537.08 5193.64 61.470 209.250 3455.67 3511.17 3158.95 S 1327.25 W 5954305.50 N 376445.97E 1.060 559.63 5288.32 61.540 206.530 3500.$5 3556.35 3232.49 S 1366.17 W 5954232.60 N 376405.87E 2.526 580.46 5383.71 61.220 205.320 3546.54 3602.04 3307.79 S 1402.78 W 5954157.90 N 376368.04E 1.163 598.63 5478.71 60.840 203.950 3592.55 3648.05 3383.34 S 1437.42 W 5954082.93 N 376332.17E 1.324 614.84 5574.01 60.970 203.770 3638.89 3694.39 3459.49 S 1471.11 W 5954007.33 N 376297.25E 0.214 629.97 5669.51 61.040 201.770 3685.19 3740.69 3536.51 S 1503.43 W 5953930.85 N 376263.68E 1.833 643.59 5764.70 61.310 199.700 3731.09 3786.59 3614.50 S 1532.96 W 5953853.35 N 376232.89E 1.926 654.25 5860.03 60.010 198.100 3777.80 3833.30 3693.11 S 1559.88 W 5953775.19 N 376204.70E 2.000 662.23 5955.27 58.750 197.450 3826.31 3881.81 3771.16 S 1584.90 W 5953697.56 N 376178.41E 1.447 668.50 6049.54 57.750 197.270 3875.91 3931.41 3847.67 S 1608.82 W 5953621.45 N 376153.25E 1.073 674.05 6145.53 56.320 197.340 3928.14 3983.64 3924.55 S 1632.78 W 5953544.96 N 376128.05E 1.491 679.55 6240.79 55.530 196.940 3981.52 4037.02 3999.95 S 1656.03 W 5953469.95 N 376103.57E 0.899 684.71 6335.63 55.740 197.650 4035.05 4090.55 4074.70 S 1679.31 W 5953395.59 N 376079.08E 0.656 690.04 6430.97 57.180 197.350 4087.73 4143.23 4150.49 S 1703.20 W 5953320.20 N 376053.96E 1.533 695.74 6525.96 59.510 197.610 4137.57 4193.07 4227.60 S 1727.49 W 5953243.49 N 376028.42E 2.464 701.51 North Slope, Alaska Comment • • 20 December, 2005 - 10:14 Page 3 of 8 DrillQuest 3.03.06.008 ConocoPhillips Alaska, lnc. Survey Report for CD4-319 Your Ref: API 501032051600 Job No. AK-ZZ-0004025926, Surveyed: 8 November, 2005 A-aska North Slope Measured Depth (ft) 6621.32 6717.22 6812.50 6907.90 7003.40 Incl. 59.760 60.510 61.030 60.730 60.880 True Azim. 196.690 195.840 194.080 195.960 195.740 7098.36 7193.52 7289.10 7384.23 7479.49 7574.58 7670.36 7765.42 7861.02 7956.09 8051.30 8145.30 8241.04 8336.28 8431.14 8526.38 8621.65 8716.91 8812.43 8908.14 9003.04 9098.62 9193.72 9289.37 9384.66 9479.28 9574.79 9670.21 9765.58 9860.73 61.140 61.080 61.270 62.220 62.660 63.090 64.310 64.040 63.220 62.060 60.760 59.250 58.210 57.620 57.950 57.940 56.950 55.000 54.080 53.180 51.490 49.200 46.820 44.060 40.450 38.610 38.190 39.050 39.390 39.280 195.140 195.540 196.230 196.450 196.980 196.630 196.460 196.730 196.400 197.040 196.930 196.340 196.590 195.450 194.130 192.580 195.210 198.750 202.220 206.360 210.990 215.010 219.740 223.610 227.690 234.420 240.810 247.780 253.730 261.850 Sub-Sea Depth (ft) 4185.78 4233.53 4280.06 4326.49 4373.07 4419.10 4465.07 4511.16 4556.19 4600.26 4643.62 4686.06 4727.47 4769.93 4813.62 4859.18 4906.17 4955.87 5006.46 5057.03 5107.58 5158.85 5212.16 5267.59 5324.36 5382.36 5443.37 5507.01 5574.13 5644.66 5717.67 5792.55 5867.14 5941.05 6014.69 Yertical Depth (ft) 4241.28 4289.03 4335.56 4381.99 4428.57 4474.60 4520.57 4566.66 4611.69 4655.76 4699.12 4741.56 4782.97 4825.43 4869.12 4914.68 4961.67 5011.37 5061.96 5112.53 5163.08 5214.35 5267.66 5323.09 5379.86 5437.86 5498.87 5562.51 5629.63 5700.16 5773.17 5848.05 5922.64 5996.55 6070.19 Local Coordinates Northings Eastings (ft) (ft) 4306.22 S 1751.75 W 4386.06 S 1775.04 W 4466.38 S 1796.50 W 4546.87 S 1818.09 W 4627.07 S 1840.86 W 4707.13 S 1862.97 W 4787.48 S 1885.02 W 4868.02 S 1907.94 W 4948.43 S 1931.51 W 5029.31 S 1955.80 W 5110.33 S 1980.27 W 5192.64 S 2004.72 W 5274.64 S 2029.16 W 5356.74 S 2053.58 W 5437.60 S 2077.86 W 5517.55 S 2102.29 W 5595.55 S 2125.59 W 5674.03 S 2148.79 W 5751.58 S 2171.06 W 5829.18 S 2191.54 W 5907.71 S 2210.19 W 5985.65 S 2229.46 W 6061.15 S 2252.48 W 6134.02 S 2279.69 W 6204.24 S 2311.36 W 6270.13 S 2347.36 W 6331.84 S 2387.39 W 6388.01 S 2430.22 W 6438.93 S 2475.48 W 6483.75 S 2521.21 W 6521.61 S 2567.95 W 6553.36 S 2617.98 W 6579.13 S 2671.58 W 6598.97 S 2728.46 W 6611.71 S 2787.30 W Global Coordinates Northings Eastings (ft) (ft) 5953165.28 N 376002.89 E 5953085.83 N 375978.30 E 5953005.86 N 375955.54 E 5952925.74 N 375932.64 E 5952845.92 N 375908.57 E 5952766.22 N 375885.16 E 5952686.24 N 375861.82 E 5952606.09 N 375837.59 E 5952526.07 N 375812.71 E 5952445.60 N 375787.11 E 5952364.99 N 375761.33 E 5952283.09 N 375735.55 E 5952201.49 N 375709.78 E 5952119.81 N 375684.03 E 5952039.35 N 375658.43 E 5951959.80 N 375632.71 E 5951882.19 N 375608.14 E 5951804.10 N 375583.67 E 5951726.92 N 375560.14 E 5951649.67 N 375538.40 E 5951571.45 N 375518.48 E 5951493.83 N 375497.95 E 5951418.72 N 375473.70 E 5951346.30 N 375445.31 E 5951276.60 N 375412.50 E 5951211.31 N 375375.44 E 5951150.25 N 375334.41 E 5951094.79 N 375290.67 E 5951044.61 N 375244.59 E 5951000.54 N 375198.14 E 5950963.44 N 375150.79 E 5950932.51 N 375100.25 E 5950907.62 N 375046.23 E 5950888.70 N 374989.04 E 5950876.92 N 374930.00 E North Slope, Alaska Dogleg Yertical Rate Section Comment (°/100ft) 0.873 706.90 1.097 711.07 1.702 713.35 1.750 715.71 0.255 719.29 0.617 722.26 0.373 725.10 0.663 728.74 1.019 733.06 0.676 737.96 0.558 743.00 1.284 747.72 0.382 752.50 0.912 757.25 1.359 762.15 1.369 767.39 1.696 772.01 1.109 776.39 1.188 780.10 1.228 782.06 1.379 782.01 2.548 782.71 3.698 787.62 3.112 797.21 3.607 811.77 4.252 831.53 4.027 856.17 4.463 884.84 4.078 917.07 4.757. 951.18 4.925 987.88 4.178 1029.20 4.645 1075.38 3.960 1126.12 5.408 1180.40 • • 20 December, 2005 - 10:14 Page 4 of 8 DrillQuest 3.03.06.008 ConocoPhillips Alaska, Inc. Survey Report for CD4-319 Your Ref: API 501032051600 Job No. AK-ZZ-0004025926, Surveyed: 8 November, 2005 Alaska North Slope North Slope, Alaska Measured True Subsea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°I100it) 9955.85 38.190 267.100 6088.91 6144.41 6617.47 S 2846.49 W 5950872.13 N 374870.72E 3.638 1236.65 10050.93 37.430 272.220 6164.05 6219.55 6617.84 S 2904.74 W 5950872.70 N 374812.48E 3.396 1293.23 10146.16 38.490 276.600 6239.14 6294.64 6613.31 S 2963.11 W 5950878.18 N 374754.20E 3.040 1351.06 10241.18 39.810 281.960 6312.85 6368.35 6603.60 S 3022.26 W 5950888.85 N 374695.21E 3.822 1410.85 10336.37 40.120 287.040 6385.83 6441.33 6588.30 S 3081.41 W 5950905.11 N 374636.32E 3.443 1471.94 • 10431.70 41.560 289.460 6457.95 6513.45 6568.76 S 3140.59 W 5950925.61 N 374577.45E 2.244 1534.04 10524.97 43.270 292.350 6526.81 6582.31 6546.29 S 3199.34 W 5950949.03 N 374519.08E 2.780 1596.39 10620.21 44.770 295.230 6595.30 6650.80 6519.58 S 3259.88 W 5950976.72 N 374458.99E 2.626 1661.47 10714.31 47.960 300.170 6660.25 6715.75 6487.88 S 3320.09 W 5951009.40 N 374399.29E 5.090 1727.39 10809.77 49.850 305.040 6723.02 6778.52 6449.10 S 3380.64 W 5951049.15 N 374339.39E 4.324 1795.27 10904.73 53.650 309.270 6781.81 6837.31 6404.03 S 3439.99 W 5951095.18 N 374280.77E 5.314 1863.45 10999.26 57.030 314.220 6835.59 6891.09 6352.24 S 3497.92 W 5951147.91 N 374223.69E 5.596 1931.80 11094.68 61.620 317.840 6884.27 6939.77 6293.16 S 3554.83 W 5951207.90 N 374167.75E 5.811 2000.84 11190.08 66.940 322.260 6925.67 6981.17 6227.27 S 3609.92 W 5951274.68 N 374113.74E 6.964 2069.69 11285.21 71.170 326.190 6959.68 7015.18 6155.20 S 3661.80 W 5951347.58 N 374063.04E 5.886 2136.85 11380.17 73.930 330.030 6988.16 7043.66 6078.30 S 3709.62 W 5951425.25 N 374016.47E 4.830 2201.18 11475.66 76.460 332.640 7012.56 7068.06 5997.30 S 3753.89 W 5951506.96 N 373973.53E 3.742 2263.00 11570.64 77.390 336.790 7034.06 7089.56 5913.67 S 3793.39 W 5951591.23 N 373935.39E 4.367 2320.80 11666.12 78.080 340.160 7054.35 7109.85 5826.89 S 3827.62 W 5951678.55 N 373902.58E 3.524 2374.19 11761.43 78.150 339.730 7073.98 7129.48 5739.27 S 3859.60 W 5951766.67 N 373872.03E 0.448 2425.59 11855.60 82.140 340.920 7090.09 7145.59 5651.93 S 3890.82 W 5951854.51 N 373842.22E 4.416 2476.19 11948.33 11970.89 88.430 89.960 341.220 342.500 7097.71 7098.03 7153.21 7153.53 5564.55 S 5543.12 S 3920.79 W 3927.81 W 5951942.36 N 5951963.91 N 373813.68E 373807.01E 6.791 8.842 2525.58 2537.37 • Tie-On Point (Anadrill) 12038.48 91.810 342.540 7096.98 7152.48 5478.66 S 3948.11 W 5952028.69 N 373787.76E 2.738 2572.05 12128.52 87.670 340.120 7097.39 7152.89 5393.38 S 3976.92 W 5952114.42 N 373760.34E 5.326 2619.83 12226.28 88.110 341.230 7100.99 7156.49 5301.20 S 4009.25 W 5952207.12 N 373729.51E 1.221 2672.63 12321.52 89.390 343.240 7103.07 7158.57 5210.53 S 4038.30 W 5952298.25 N 373701.94E 2.502 2721.88 12417.29 90.390 344.960 7103.25 7158.75 5118.42 S 4064.54 W 5952390.77 N 373677.20E 2.077 2768.73 12513.55 90.310 347.700 7102.67 7158.17 5024.90 S 4087.29 W 5952484.65 N 373655.98E 2.848 2812.52 12609.96 90.000 349.360 7102.41 7157.91 4930.42 S 4106.46 W 5952579.43 N 373638.35E 1.752 2853.05 12705.59 90.870 350.740 7101.68 7157.18 4836.23 S 4122.98 W 5952673.87 N 373623.36E 1.706 2890.93 12800.30 90.580 350.380 7100.48 7155.98 4742.82 S 4138.51 W 5952767.53 N 373609.34E 0.488 2927.68 12894.58 90.790 349.920 7099.35 7154.85 4649.93 S 4154.64 W 5952860.66 N 373594.73E 0.536 2964.88 12990.87 91.600 350.520 7097.35 7152.85 4555.06 S 4170.99 W 5952955.79 N 373579.92E 1.047 3002.76 13087.17 90.040 351.060 7095.97 7151.47 4460.02 S 4186.40 W 5953051.07 N 373566.06E 1.714 3039.76 20 December, 2005 - 10:14 Page 5 of 8 DrillQuest 3.03.06.008 ConocoPhillips Alaska, /nc. Survey Report for CD4-319 Your Ref: APl 501032051600 Job No. AK-ZZ-0004025926, Surveyed: 8 November, 2005 A-aska North Slope Global Coordinates Northings Eastings (ft) (ft) 5953141.98 N 373554.58 E 5953237.13 N 373544.10 E 5953332.11 N 373533.47 E 5953427.30 N 373521.81 E 5953520.62 N 373512.24 E 5953615.45 N 373504.52 E 5953710.63 N 373495.44 E 5953806.90 N 373489.40 E 5953901.46 N 373485.59 E 5953998.40 N 373480.47 E 5954093.95 N 373475.64 E 5954189.38 N 373472.24 E 5954285.21 N 373466.95 E 5954379.08 N 373451.85 E 5954472.76 N 373428.74 E Dogleg Rate (°/100ft) 2.748 0.697 1.433 1.345 3.412 Vertical Section North Slope, Alaska Measured True Subsea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 13178.82 88.120 352.690 7097.44 7152.94 4369.31 S 4199.35 W 13274.58 88.760 352.880 7100.05 7155.55 4274.34 S 4211.38 W 13370.16 90.070 352.480 7101.02 7156.52 4179.55 S 4223.55 W 13466.07 91.090 351.690 7100.05 7155.55 4084.56 S 4236.76 W 13559.93 92.070 354.740 7097.46 7152.96 3991.40 S 4247.84 W 13655.27 95.030 354.090 7091.56 7147.06 3896.71 S 4257.10 W 13750.98 88.940 353.150 7088.25 7143.75 3801.69 S 4267.73 W 13847.48 89.210 357.810 7089.80 7145.30 3705.53 S 4275.33 W 13942.14 88.690 355.710 7091.54 7147.04 3611.05 S 4280.68 W 14039.24 88.900 356.380 7093.58 7149.08 3514.20 S 4287.37 W 14134.92 89.440 355.970 7094.97 7150.47 3418.74 S 4293.75 W 14230.42 90.880 358.090 7094.70 7150.20 3323.38 S 4298.70 W 14326.42 89.780 353.720 7094.15 7149.65 3227.65 S 4305.56 W 14421.57 90.410 346.150 7093.99 7149.49 3134.03 S 4322.17 W 14518.06 90.590 344.270 7093.15 7148.65 3040.75 5 4346.80 W 14612.35 88.670 341.950 7093.76 7149.26 2950.54 S 4374.19 W 14707.77 88.960 344.500 7095.73 7151.23 2859.21 S 4401.72 W 14803.34 93.950 343.460 7093.30 7148.80 2767.41 S 4428.08 W 14898.18 93.530 342.860 7087.12 7142.62 2676.83 S 4455.50 W 14993.69 88.520 339.660 7085.41 7140.91 2586.44 S 4486.17 W 15088.49 87.780 338.330 7088.47 7143.97 2497.98 S 4520.13 W 15184.02 90.410 338.420 7089.98 7145.48 2409.20 S 4555.33 W 15278.61 88.160 337.260 7091.16 7146.66 2321.61 S 4591.00 W 15374.48 88.970 335.940 7093.56 7149.06 2233.65 S 4629.06 W 15469.84 89.380 333.100 7094.93 7150.43 2147.59 S 4670.08 W 15566.80 89.440 330.460 7095.93 7151.43 2062.16 S 4715.92 W 15662.47 89.860 328.480 7096.52 7152.02 1979.76 S 4764.51 W 15758.04 90.280 328.470 7096.40 7151.90 1898.30 S 4814.48 W 15852.45 89.860 330.280 7096.28 7151.78 1817.06 S 4862.58 W 15947.87 90.090 330.520 7096.33 7151.83 1734.09 S 4909.71 W 16044.27 92.550 330.750 7094.11 7149.61 1650.11 S 4956.96 W 16139.10 92.860 330.860 7089.63 7145.13 1567.42 S 5003.17 W 16234.59 91.550 328.920 7085.96 7141.46 1484.88 S 5051.03 W 16330.86 89.960 335.380 7084.69 7140.19 1399.81 S 5095.98 W 16424.90 88.690 335.840 7085.79 7141.29 1314.18 S 5134.81 W 3.178 6.438 4.836 2.285 0.723 0.709 2.684 4.694 7.983 1.957 5954563.40 N 373402.82E 3.194 5954655.17 N 373376.78E 2.689 5954747.38 N 373351.92E 5.333 5954838.40 N 373325.98E 0.771 5954929.27 N 373296.78E 6.223 5955018.27 N 373264.26E 1.605 5955107.61 N 373230.51E 2.755 5955195.77 N 373196.27E 2.676 5955284.33 N 373159.64E 1.615 5955371.06 N 373120.03E 3.009 5955457.21 N 373075.58E 2.723 5955540.39 N 373028.33E 2.116 5955622.66 N 372979.69E 0.440 5955704.67 N 372932.93E 1.968 5955788.39 N 372887.15E 0.348 3073.36 3107.05 3140.85 3175.69 3208.05 3238.99 3271.33 3300.99 3328.07 3357.01 3385.33 3412.23 3441.06 3478.91 3524.47 3572.01 3619.94 3666.84 3714.49 3765.25 3818.78 3873.58 3928.57 3985.96 4045.79 4110.17 4176.53 4244.00 4309.60 4374.67 5955873.13 N 372841.26E 2.563 4440.09 5955956.56 N 372796.41E 0.347 4504.18 5956039.87 N 372749.89E 2.450 4569.86 5956125.65 N 372706.34E 6.910 4633.28 5956211.91 N 372668.90E 1.436 4690.89 Comment • • 20 December, 2005 -10:14 Page 6 of 8 DrillQuest 3.03.06.008 ConocoPhillips Alaska, lnc. Survey Report for CD4-319 Your Ref.• APl 501032051600 Job No. AK ZZ-0004025926, Surveyed: 8 November, 2005 A-aska North Slope Measured True Subsea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings l~) (ft) (ft) (ft) (ft) (ftl (ft) 16519.62 88.910 341.700 7087.78 714328 1225.94 S 5169.08 W 5956300.69 N 372636.06 E 16616.04 88.090 345.930 7090.30 7145.80 1133.40 S 5195.94 W 5956393.66 N 372610.71 E 16711.46 89.880 342.800 7091.99 7147.49 1041.54 S 5221.65 W 5956485.92 N 372586.50 E 16807.23 89.840 345.640 7092.23 7147.73 949.39 S 5247.70 W 5956578.49 N 372561.96 E 16902.62 88.750 348.300 7093.40 7148.90 856.47 S 5269.20 W 5956671.74 N 372541.97 E 16997.59 89.610 345.850 7094.76 7150.26 763.92 S 5290.44 W 5956764.62 N 372522.24 E 17094.14 92.140 346.990 7093.29 7148.79 670.09 S 5313.10 W 5956858.81 N 372501.10 E 17189.10 88.920 352.140 7092.41 7147.91 576.75 S 5330.29 W 5956952.41 N 372485.43 E 17283.90 91.090 350.830 7092.40 7147.90 483.00 S 5344.33 W 5957046.38 N 372472.92 E 17379.81 90.300 353.010 7091.24 7146.74 388.06 S 5357.81 W 5957141.53 N 372460.98 E 17475.61 90.140 353.470 7090.87 7146.37 292.93 S 5369.08 W 5957236.83 N 372451.26 E 17569.66 90.130 353.920 7090.65 7146.15 199.44 S 5379.41 W 5957330.47 N 372442.45 E 17666.31 90.730 354.380 7089.92 7145.42 103.30 S 5389.26 W 5957426.76 N 372434.16 E 17761.50 90.270 354.640 7089.09 7144.59 8.55 S 5398.37 W 5957521.64 N 372426.60 E 17857.29 90.300 356.200 7088.62 7144.12 86.93 N 5406.02 W 5957617.24 N 372420.50 E 17953.50 91.010 358.350 7087.52 7143.02 183.02 N 5410.59 W 5957713.39 N 372417.49 E 18048.33 90.200 354.110 7086.51 7142.01 277.61 N 5416.82 W 5957808.07 N 372412.79 E 18144.32 90.430 354.110 7085.99 7141.49 373.10 N 5426.67 W 5957903.70 N 372404.50 E 18239.64 90.650 354.110 7085.09 7140.59 467.91 N 5436.46 W 5957998.66 N 372396.26 E 18332.83 90.640 355.730 7084,04 7139.54 560.72 N 5444.71 W 5958091.60 N 372389.52 E 18428.74 91.690 357.500 7082.09 7137.59 656.44 N 5450.37 W 5958187.39 N 372385.41 E 18524.59 91.270 354.380 7079.61 7135.11 752.01 N 5457.15 W 5958283.06 N 372380.18 E 18683.23 91.270 354.380 7076.10 7131.60 909.85 N 5472.68 W • 5958441.13 N 372367.22E All data is in Feet (US Survey) unless othervvise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 283.390° (True). Based upon Minimum Cu rvature type calculations, at a Measured Depth of 18683.23ft., The Bottom Ho le Displacement is 554 7.80ft., in the Direction of 279.439° (True). North Slope, Alaska Dogleg Vertical Rate Section Comment (°/100ft) 6.190 4744.67 4.467 4792.23 3.778 4838.51 2.966 4885.19 3.013 4927.62 2.734 4969.72 2.874 5013.49 6.395 5051.83 2.674 5087.20 2.417 5122.30 0.508 5155.30 0.479 5186.99 0.782 5218.84 0.555 5249.64 1.629 5279.19 2.353 5305.89 4.552 5333.86 0.240 5365.56 0.231 5397.03 1.738 5426.55 2.145 545422 3.283 5482.95 0.000 5534.62 Projected Survey • • 20 December, 2005 -10:14 Page 7 of 8 DrillQuest 3.03.06.008 ConocoPhillips Alaska, lnc. Survey Report for CD4-319 Your Ref: API 501032051600 Job No. AK 2Z-0004025926, Surveyed: 8 November, 2005 Alaska North Slope Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11970.89 7153.53 5543.12 S 3927.81 W 18683.23 7131.60 909.85 N 5472.68 W Comment Tie-On Point (Anadrill) Projected Survey From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 349.00 348.90 CB-SS-Gyro 349.00 348.90 18683.23 7131.60 MWD+IIFR+MS+SAG North Slope, Alaska • • 20 December, 2005 - 10:14 Page 8 of 8 DrillQuest 3.03.06.008 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Jim Regg(a~admin.state.ak.us: Bob Fleckenstein(cDadmin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc FIELD /UNIT /PAD: Alpine CD4 DATE: 11 /29/2005 OPERATOR REP: David Burley AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4-319 In'. T e N TVD 6,938' Tubing 1,600 1,920 1,920 1,900 Interval I P.T.D. 205-148 Test T e P Test si 3500 IA 820 3,575 3,510 3,490 P/F P Notes: OA MIT Report Form Revised: 03/18/04 CD4-319 MIT Form .xls • • 10-Jan-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD4-319 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,970.89' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 18,683.23' MD ap5-~ ~-$ PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn; Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ 17~,(~~ Signed Please call me at 273-3545 if you have any que tions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service 0 6. Permit to Drill Number: 205-14$ ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-319 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20516-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ~ or Continuation ^ or Final ^ 305-373 12/7/2005 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 389* 389 totals (bbls): 2005 / atn 12618 100 0 12718 13 12/19/2005 12/31 /2005 CD4-208, CD4-318 2006 / 1st 0 0 0 0 2006 / 2nd 0 0 0 0 2006 / 3rd 0 0 0 0 Total Ending Report is due on the 20th volume 12618 100 389 13107 13 (bbls>: of the month following the final month of the quarter. Ex: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and in~ectivit test I hereby certify that the foregoin is true and correct to the best of my knowledge. Signature: ~ 1 Date: ~ ~t '2- `0 6 Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 r Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth Well ~ Job # ~~j1~~\ /~~""~ NO. 3648 ~A(~ ~ 9 2~~6 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 011S.Ci0f1~M18~01! A~B~~iC73SC 333 West 7th Ave, Suite 100 i Ancfior~ Anchorage, AK 99501 Field: Alpine Color Log Description Date BL Prints CD CD4-319 11072940 USIT 11/27105 1 CD4-208 11166740 USIT 12/22/05 1 SIGNED: DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. 01 /05/06 • • ~ ~ ~ ~ a ~ ~ ' ~ ~ ~ ~ ~ ~ ~°°', s ~ FRANK H. MURKOWSK/, GOVERNOR ~-7~ OI~ L>•isj/ ~ ~ ~ 333 W. 7T" AVENUE, SUITE 100 COI~TSER~'A'I~IO1Q CO1rII~iISSI01~ ANCHORAGE, ALASKA 99501-3539 ? PHONE (907) 279-1433 Chip Alvord s- Alpine Drilling Team Leader ConocoPhillips Alaska P.O. Box 100360 Anchorage, AK 99510-0360 Re: CRU CD4-319 Sundry Number: 305-373 Dear Mr. Alvord: FAX (907) 276-7542 ~o~- ~ 48 Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. Approval of this request does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annulus of a single well or to use that well for disposal purposes for a period longer than one year. 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, ~~ Dan T. Seamount Commissioner -f-~i DATED this day of December, 2005 Encl. Note to File CD4-319 (205-148...305-373) Colville River Unit (Nanuq-Kuparuk) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. This well is the first new development well on CD4 pad about 4 miles south of the Alpine facility. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 125 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 84% XS of the calculated hole volume. --On the initial leak off test, the pressure slope hardly changed to the determined LOT point at 18.4 EMW. Minimal fluid was pumped in. The pressure declined during the observation period to about 14.7 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. Lead and tail slurries were used to place cement above the shallower Nanuq-Nanuq sand. --An infectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 16.1 EMW. The pressure declined with additional pumping to 14.4 EMW. During the observation period, the pressure declined to 13.2 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within '/4 mile radius of CD4-319. There is only one within '/4 mile of the surface shoe. The surface shoe of exploration well Nanuq 5 is approximately 1230' distant. An examination of the cementing information for this well did not reveal any problem that would preclude granting CPA's request for CD4-319. Based on examination of the submitted information, 1 recommend approval of ConocoPhillips' request for the subject well. 9~C~.~ ,, ~ ~'`~ Tom Maunder, PE Sr. Petroleum Engineer December 7, 2005 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\051207--CD4-319.doc ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 5, 2005 • Alaska Oil and Gas Conservation Commission 333 West 7`i' Avenue, Suite 100 Anchorage, Alaska 99501-3539 ConocoPhillips -~ d .~ ~ _e ..~, ~. ~, - - ~~ __...;r 1 Re: Application for 5undry Approval for Annular Disposal of Drilling Waste on well CD4-319 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-319 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD4-319 approximately December 13, 2005 or as soon as a permit is available. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within '/4 mile radius at AOGCC: Nanuq 3; Nanuq 5 12. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (16.1 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.4 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Vern Johnson at 265-6081; Chip Alvord can also be reached by calling 265-6120. S' er y, c% v ' Vern Johnson Drilling Engineer cc: CD4-319 Well File Chip Alvord Anadarko Sharon Allsup-Drake ATO-1 goo ~ts-~ ~ ~ L ~ ~~~-~- ~ --~ ~~ ATO-1530 ~~~~~ ~~ 6,ya ~S I ~~ ! ~ ~~$-~ STATE OF ALASKA C"~ ALASKA OIL AND GAS CONSERVATION COMMISSION DES 0 `i ~~~i5 ANNULAR DISPOSAL APPLICATION 20 AAC 25.oso Alaska ~dl ~ has ~atts~ amrrlissiar~ 1. Operator 3. Permit to Drill ~ Name: Number: 205-148 ConocoPhillips Alaska 4. API Number: ' 50-103-20516-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-319 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: 1°Jriuq 5 Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1770' MD / 1 600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2296 PSI 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- completion fluids, diesel, formation fluids associated with the contaminated drilling mud 16. Estimated start date: , act of drilling a well, drill rig wash fluids, domestic waste water, any added water 13-Dec-05 needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and any other fluids associated with drilling a well. 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) ^ FIT Records w/LOT Graph Surf. Casing Cementing Data 0 Other 0 previous authorization for new product cleanup fluids for CD1 and CD2 egoing is true and correct to the best of my knowledge. 18. I hereby certify that the for / Signature: ~ L-~ ~~ J~ Title: J~ ~ 1'r ~~'`~ti-~~", (,,«~•!` _ ~ _ Printed Phone N b lL(~ ~ °'~ Name: Chip Alvord um er: 265-6120 Date: Commission Use Only Conditions of approval: C~iMp~t Ut~CSc `~'t C ~~. c~~ LOT review and approval: r r - ~l a'~ Approval number: ~~' ~ -~'-z .3 Subsequen orm required: ~ APPROVED BY Appro d b ; i~/ COMMISSIONER THE COMMISSION Date:, - G °~ ~ ~~ ~ ~ ~~ ~ R~DMS AFL ~~~ a ~ 2005 Form 10-403RD Rev. 6/2004 INSTRUCTIONS ON REVERSE Submit in Duplicate • AOGCC ReEUlations. 20 AAC 25.080 (bl 1 Desi ation of the well or wells to receive drillin wastes: CD4-319 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached snap indicating wells within 114 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste maybe drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids. associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD 1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2296 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT(FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N1A d th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. NIA 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a swnmary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4-208 CD4-318, CD4-209, CD4-320, CD4-210, CD4-211 will be enerated. 15 If the operator proposes not to comply with a limitation NIA established in (d) of this section, an explanation of why co fiance would be ' rudent. 16 Any additional data required by the commission to confum N/A containment of drillin waste. • Well CD4-319 Date 12/5/2005 on a .~ U (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.3952 psi/ft Header Pressure (for wells on gas lift) 0 psi 2,400 TVD version i.o - ~m ~os Pburst8s% - PHydrostatic +PApplied - PFormation 4,888 = ( 2,400 * 0.052 * MW,,,ax ) + 1500 - (0.4337 * 2,400 ) MWmax = 35.5 PPg Surface CaSing String Size 9.625 in Weight 40 ppf Grade L 80 rbursaoo°r° 5,750 Ps' Pburst85°ro 4,888 psi Depth of Shce 2,400 ft FIT/LOT @ Shce 18.4 ppg or 2,296 psi F[T/LOT for Annulus 16.1 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 9,542' MD 5,821' TVD Maximum Fluid Density avoid Coll apse of 2nd Casing String Pcollapse85% - PHydrostatic +PApplied - PGasGradient - PHeader 4,599 = ( 5,821 * 0.052 * M W n,a,~ ) + 1,500 - (0.3952 * 5,821) - 0 MWmax = 17.8 PPg 4.5 "Tubing 2nd Casing String Size 7 in 7,153 TVD Weight 26 ppf Grade L 80 1'collapse100% 5,410 Psl Pcollapse85% 4,599 psi Top of Cement 5,821 ft Gas Gradient 0.3952 psi/ft Max Surf. Pressure 1,500 psi Header Press 0 psi Pmax avowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable - ( 2,400 * .052 * 18.4 ) Pmax allowable - 2,296 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". • Pressure Calculations for Annular Disposal o+ on C !: ,y R U' ' I N ~p • CC)i'"C?CC~-P~ 1 ~ I 1 S Casing Detail 9 5/8" Surface Casin_p Well: CD4-319 Date: 10/30/2005 Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN DEPTH LENGTH TOPS Doyon 19 RKB to Landing Ring 36.24 Ff~C Gen V Hanger 2.22 36.24 Jts 3 to 83 81 Jts 9-518" 40# L-80 BTC Csg 3080.73 38.46 Weatherford Float Collar 1.50 3119.19 Jts 1 to 2 2 Jts 9-518" 40# L-80 BTC Csg 73.17 3120.69 Ray Oii Tools "Silver Bullet" Float Shoe 2.26 3193.86 3196.12 TD 12 1/4'" Surface Hole 3206.12 {} joints in the pipe shed. Run 8 joints - 7 joints stay out Use Best-o-Life 2000 pipe dope MU torgue - 8600 ft/Ibs Remarks: Up Wt - 170 k Dn Wt- 130k Block Wt - 75k • Hill • • ConocoPhillips Alaska Page 1 of s Cementing Report Legal Well Name: CD4-319 Spud Date: Common Well Name: CD4-319 Report #: 1 Report Date: 11/2/2005 Event Name: ROT -DRILLING Start: 11/1!2005 End: Cement Job Type: Primary.. Prima S ueeze 0 en Hole S ueeze Casin Plu Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 3,196 (ft) SQ TMD: (ft) TMD Set: Top Set: (ft) Date Set: 11/2/2005 SQ Date: Date Set: BTM set: (ft) Csg Type: Surface Casing SQ Type: Csg Type: Plug Date: Csg Size: 9.625 (in.) SQ TMD: Plug Type: SQ Date: Drilled Out: Cmtd. Csg: Surface Casing Cmtd. Csg: Cmtd. Csg: Gmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jim Pipe Movement: Rediprr~ca~ng Pipe Movement Rot Time Start: Time End: RPM: Init Torque: (ft-Ibf) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Rec Time Start:03:55 Time End: 08:00 SPM: 1 Stroke Length: 20.0 (ft) Drag Up: 160 (Ibs) Drag Down: 135 (Ibs) Stage No: 1 of 1 Type: Cement Casing Start Mix Cmt: 06:51 Disp Avg Rate: 6.80 (bbl/min) Returns T00 Volume Excess %: 400.00 Start Slurry Displ : 06:53 Disp Max Rate: 7.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: 125 Start Displ: 07:59 Bump Plug: Y Cmt Vol to Surf; .12x..00 (bbp Time Circ Prior End Pumping: 08:40 Press Prior: 630 (psi) To Cementing: 2.00 End Pump Date: 11/2/2005 Press Bumped: 1,200 (psi) Ann Flow After: N Mud Circ Rate: 294 (gpm) Top Plug: Y Press Held: 2 (min) Mixing Method: Tub Mud Circ Press: 450 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Densometer Mud Data Type: Spud Mud Density: 9.7 (ppg) Visc: 78 (s/qt) PV/YP: 18 (cp)/19 (Ib1100ftZ) Gels 10 sec: 5 (Ib/100ft2} Gels 10 min: 13 (Ib/100ft2) Bottom Hole Circulating Temperature: (°F) Bottom Hole Static Temperature: (°F} Displacement Fluid Type:Mud Density: 9.7 (ppg) Volume: 236.40 (bbl) Stage No; 1 Slurry No: 1 of 4 Sfurry Data Fluid Type: FLUSH Description,;,J~iozan w er w/nut plug Class: Purpose: Wash & MAR Slurry Interval: (ft) To: (ft) Cmt Vo • 40.0 (bbl Density: 8.30 (ppg) Yield: (ft'/sk) Mix Water: (gal) Water Source: Slurry Water Vol: (bbl) Other Vol: Q Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (°!°) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Pfintetl: 71/32005 7:13:Otl AM • ConocoPhillips Alaska Page 2 of 3 Cementing Report Legal Well Name: CD4-319 Spud Date: Common Wel! Name: CD4-319 Report #: 1 Report Date: 11/2/2005 Event Name: ROT -DRILLING Start: 11/1/2005 End: Stage No: 1 Slurry No: 2 of 4 Slurry Data Fluid Type: Spacer Descriptio UDPUSH XL Class: Purpose: SPACER Slurry Interval: (ft) To: (ft) Cmt Vol• 45.0 (bblfi' Density: 10.50 (ppg) Yield: (ft'/s k) Mix Water: (gal) Water Source: Slurry I: (s ff Water Vol: (bbl) Other Vol: () Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No: 1 Slurry No: 3 of 4 Slurry Data Fluid Type: LEAD Description: ASLite Class: Purpose: PRIMARY Slurry Interval: 2,707.00 (ft}fo: (ft) Cmt Vol: 4Q6.0 (bbl) Density: 10.70 (ppg) Yield: 4.45 (ft'/sk) Mix Water: 20.72 (gal) Water Source: LAKE Slurry Vo1~11 (sk) Water Vo1:252.0 (bbl) Other Vol: () Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No: 1 Slurry No 4 of 4 Slurry Data Fluid Type: TAIL Description: Class: G Purpose: PRIMARY Slurry lnterval: 3,196.00 (ftJfo: 2,707.00 (ft) Cmt Vol: 48.0 (bbl) Density: 15.80 (ppg) Yield: 1.17 (ft'/sk) Mix Water: 5.10 (gal) Water Source: LAKE Slurry Vo1234 (sk) Water Vo1:28.0 (bbl) Other Vol: () Foam Job: N Test Data T ime Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F} Printed: 11/3/2005 7:13:08 AM • Conocol'hillips Alaska Page 3 of 3 Cementing Report Legal Well Name: CD4-319 Spud Date: Common Well Name: CD4-319 Report #: 1 Report Date: 11/2/2005 Event Name: ROT -DRILLING Start: 11/1/2005 End: Casing Test Shoe Test Liner Top Test Test Press: 2,500 (psi) Pressure: (ppge) Liner Lap: For: 30 {min) Tool: N Pos Test: (ppge) Tool: N Cement Found between Open Hole: (ft) Neg Test: (ppge) Tool: N Shoe and Collar: N Hrs Before Test: Hrs Before Test: Cement Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (ft) Under Pressure: (psi) How Determined: Bond Quality: TOC Sufficient: Y Cet Run: N Job Rating: Good Bond Quality: If Unsuccessful Detection Indicator: Temp Survey: N Remedial Cementing Required: N Hrs Prior to Log: Number of Remedial Squeezes: Remarks Establish circulation @ 2.5 bbls/min & stage pumps to 6 bbls/min. -Circulate and condition for cement job -ICP - 350 psi FCP - 440 psi - PU wt. 160 SO wt 135 Held pre job safety meeting Demented 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker -Switched over to Dowel{ -Pumped 3 bbls water -Tested lines to 2750 psi -Dropped btm plug -Mixed & pumped 50 bbls 10.5 ppg MudPush spacer @ 5 bblslmin @ 170 psi - Mixed & pumped 10.7 ppg lead slurry (Arctic Set Lite) @ 7.5 bbls/min @ 240 psi to 350 psi -Observed nut plug marker Qshakers w/ 385 bbls lead slurry pumped -Pumped down surge can -pumped total of 406 bbls lead slurry -Switched to tail slurry mixed & pumped 48 bbls -15.8 ppg (Class G w/ .2% DO-46, .3% D065, 2% S001) @ 5.2 bbls/min - 320 psi -Dropped top plug w/ 20 bbls water Reciprocated pipe while pumping until just prior to beginning tail slurry -hole becoming sticky -set down onto landing ring for remainder of job Switched back to rig pumps & displaced cement w/ 216.4 bbls 9.7 ppg mud @ 7 bbls /min ICP 300 psi -pre bump pressure 640 psi - Slow rate to 4 bbls ! mins for last 32 bbls of displacement -bumped plug w! 1200 psi - Checked floats OK - CIP @ 0840 hrs. -Full returns through out job w/ 125:bbls cement to surface. rnniea: iusicwo i.~u.uo'.m • • Page 1 of 2 ConocoPhillips Alaska:, Inc.. Daily Dlrilling Report WELL NAME JOB NUMBER EVENT CODE 24 HRS PROG TMD TVD DFS REPT NO. DATE CD4-319 ODR 3,206.0 2,401.0 3.75 7 11/2(2005 SUPERVISOR RIG NAME 8. NO. FIELD NAME / OCS NO. AUTH MD DAILY TANG CUM. TANG Lar Hill/Z. Kuenzuler Do on Drillin Inc 19 AI ine 18,748.0 0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD CUM INTANG W/ MUD Pickin u drill i e. 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST W/ MUD M!U BHA, RIH, cut drill line, drill out shoe, FIT. 10/29/2005 424,347 1,161,820 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINGE INSP LEAKOFF AFE AUTH. CLAYSTONE 10093005 LAST SURVEY: DATE TMD INC AZIM LAST CASING NEXT CASING LAST BOP PRES TEST 11/1/2005 3,136.98 58.040 200.500 16.000 in 114.0 ft 9.625 in 3,199.0 ft DENSITY(ppg) 10.15 PP ECD MUD DATA DAILY COST 0 CUM COST 0 FV PV/YP GELS WUHTHP FC/T.SOL OILNVAT %Sand/MBT Ph/pM Pf/Mf CI Ca H2S LIME ES 300 37/78 35/70 10.0/ 3/ / 0.3/30.0 8.9/ 0.05/ OPERAT IONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 00:45 0.75 CASE P RUNC SURFAC RIH w/ 9.625" casing from 496' to 1,530'. 00:45 01:30 0.75 CASE P CIRC SURFAC Circ'd one casing volume @ 2 BPM. 01:30 03:00 1.50 CASE P RUNC SURFAC RIH w/ 9.625" casing from 1,530' to 3,196'. PUW=170K SOW=125K @ 3,196'. 03:00 03:45 0.75 CASE P RURD SURFAC RID casing equipment. R/U cement head. 03:45 06:00 2.25 CEMENT CIRC SURFAC Circ'd and cond. mud for cement job. 06:00 08:45 2.75 CEMENT PUMP SURFAC Held PJSM, Cemented 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/nut plug as marker -Switched over to Dowell -Pumped 3 bbls water - Tested lines to 2750 psi -Dropped btm plug -Mixed & pumped 50 bbls 10.5 ppg MudPush spacer @ 5 bbls/min @ 170 psi -Mixed & pumped 10.7 ppg lead slurry (Arctic Set Lite) @ 7.5 bbls/min @ 240 psi to 350 psi -Observed nut plug marker @ shakers w/ 385 bbls lead slurry pumped -Pumped down surge can -pumped total of 406 bbls lead slurry -Switched to tail slurry mixed & pumped 48 bbls -15.8 ppg (Class G w/ .2% DO-46, .3% D065, 2% S001) @ 5.2 bbls/min - 320 psi -Dropped top plug w/ 20 bbls water. Reciprocated pipe while pumping until just prior to beginning tail slurry -hole becoming sticky -set down onto landing ring for remainder of job. Switched back to rig pumps & displaced cement w/ 216.4 bbls 9.7 ppg mud @ 7 bbls /min ICP 300 psi -pre bump pressure 640 psi -Slow rate to 4 bbls /mins for last 32 bbls of displacement -bumped plug w/ 1200 psi - Checked floats OK - CIP @ 0840 hrs. -Full returns through out job w/ 125 bbls cement to surface. 08:45 09:00 0.25 CEMENT OTHR SURFAC Checked floats, held. 09:00 09:30 0.50 CASE P DEQT SURFAC Successfully tested 9.625" casing to 2500 psi for 30 mins. 09:30 10:45 1.25 CEMENT RURD SURFAC Blew down cement line, R/D cement head, washed down floor. 10:45 12:00 1.25 WELCTL EQRP SURFAC N/D BOPs diverter. 12:00 13:30 1.50 WELCTL EQRP SURFAC N/D surface diverter system, flowline and mousehole. Removed diverter, removed hydril and secured. Removed from cellar. 13:30 14:45 1.25 WELCTL EQRP SURFAC Installed casing head and tested metal-to-metal seals w. FMC. Installed accumulator valve on wellhead. 14:45 16:15 1.50 WELCTL EQRP SURFAC N/U BOPs, bell nipple, flow line, turnbuckle, mousehole, and service lines. 16:15 18:15 2.00 WELCTL ~OIP EQRP SURFAC Installed test plug and tested. Leaked. Tightened lower flange bolts on wellhead adapter assembly, packing on lockdowns, test ports on wellhead. Retested, good. 18:15 23:00 4.75 WELCTL ROPE SURFAC Tested BOPs. Hydril to 250 & 3500 psi -Pipe rams ,blind rams, choke & kill • Page 2 of 2 ConocoPhillips Alaska,lnc. Daily Drilling Report WELL NAME CD4-319 JOB NUMBER EVENT CODE ODR 24 HRS PROG TMD 3,206.0 ND 2,401.0 DFS 3.75 REPT NO. 7 DATE 11/2/2005 OPERATIONS SUMMARY FROM' .TO HOURS CODE TROUBLE SUB 'PHASE DESCRIPTION 18:15 23:00 4.75 WELCTL BOPE SURFAC line valves, choke manifold valves, floor safety & dart valves, TD IBOP valves to 250 & 5000 psi -Performed accumulator closure test -Witnessing of test waived by Jeff Jones of AOGCC. Blow down kill & choke lines - RD test equipment. Pulled test plug. 23:00 23:30 0.50 WELCTL EQRP SURFAC Installed wear bushing and L/D test joint. 23:30 00:00 0.50 CASE P NUND SURFAC P/U and install short bails and elevators. 24 HR SUMMARY: Ran casing to TD @ 3196'. Cemented and performed casing test to 2500 psi for 30 min. N/D diverter, N/U BOPs and tested. PERSON NEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS ConocoPhillips Company Halliburton -Sperry-Sun Fairweather E&P Service 1 M-I Drilling Fluids 3 Doyon Drilling Inc 24 Swaco 4 ACI -Arctic Catering 5 Dowell 2 Halliburton -Sperry-Sun 2 FMC Corporation Wellhe 1 Halliburton -Sperry-Sun 2 PRA -Petroleum Resour 1 MATERIALS /CONSUMPTION ITEM UNITS USAGE ON HAND ITEM UNITS USAGE ON HAND Fuel Rig gals 2,960 10,003 Fuel Camp gals 400 2,960 Water, Drilling bbls 590 1,210 Water, Potable bbls 120 480 RESERVOIR AND INTERVAL DATA RESERVOIR NAME ZONE TOP BASE COMMENTS CD2-19A CD4-319 2495 0 0.0 .._. _._~. „,o,onno ~., n~ac enn PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-319 Rig: Devon 19 Date: Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Hill/Kuenzler Pump used: #2 Mud Pump ~ Strokes ~ 0.1005 Bbls/5trk ~ 8.00 strk/min ~ Type of Test: OpenholeTest LOT/FIT ~ Pumping down drillpipe. ~ Casing Test Pressure In tegrit Test Hole Size: $-3/4" ~ Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 36.2 Ft 3196.0 Ft-MD 2400.0 Ft-TVD 3223.0 Ft-MD 2412.0 Ft-TVD Strks si Min psi Strks psi Min psi Casing Size and Description: usE PICK LIST ~ ~ 0 0 0 2500 0 0 0.00 1060 Casin Test Pressure int e rit -Test 85 1 25f30 25 0.25 1000 Mud Weight: 9.7 ppg Mud Weight: 9.6 ppg 4 200 2 2300 4 110 0.50 950 Mud 10 min Gel: 13.0 Lb/100 Ft2 Mud 10 min Gel: 14.0 Lb/100 Ft2 6 400 3 2500 6 280 1.00 925 Test Pressure: 2500.0 psi Rotating Weight: 130.0 Lbs 8 600 4 2500 8 425 1.50 8 Rotating Weight: 130.0 Lbs Blocks/Top Drive Weight: 74.0 Lbs 1(3 725 5 2500 103 550 2.00 ~S. Blocks/Top Drive Weight 74.0 Lbs Desired PIT EMW: 18.(3 ppg 12 875 6 2500 12 650 2.50 825 Estimates for Test: 0 bbls Estimates for Test: 1048 si 0 bbls ~ 14 1100 7 2500 14 750 3.00 800 ~ ~ 16 1280 8 2500 16 825 3.50 775 EMW =Leak-off Pressure + Mud Weight = 1100 PIT 15 Second 18 1450 9 2500 18 925 4.00 75J + 9.6 0.052 x TVD 0.052 x 2400 Shut-in Pressure, psi 20 1680 10 2500 2Cl 1025 4.50 725 EMW at 3196 Ft-MD (2400 Ft-TVD) = 18.4 ~al-t loon 22 1~ao 15 2500 22 1100 5.00 725 3000 Lost 0 psi during test, held 24 2080 20 2500 5.50 7030 100% of test pre ssure. = 26 2480 25 250Q 6 00 700 - . __ -- ~-~~ 28 2; 30 30 25003 6.50 080 2500 - a w rs .. s. c .w._ ~ ._~ ~E.y ~ 7.00 670 J - 7.50 670 8 00 660 . 2000 - - 8 50 650 w - . ~C -- - 9.00 650 9.50 640 y 1500 ~ w 10.00 ~ `_ - a 1000 500 0 0 1 2 3 0 5 10 1 5 2 0 25 3 0 ~~CASING TEST Barrels L Shut-In tim EAK-OFF TEST O PIT Poi e, M nt inutes Volume Pum ed Volume Bled Back Vol Pu ume m ed Vol Bled ume Back s s s s Comments: f'oin# picked by° program 18.4 PO rICJJUIC 11 ILCl~lll~/ 1 CJII.i U'i-J IC JUIIQI,C I-J Summary ~~~~~~~~"~~~~~ ~ Casing Detail Well: CD4-319 7" Casin_g Date: 11/6/2005 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Rayon 19 RKB 34.61 FMC t.~en V Hanger 1.71 34.61 Jts 3 to 281 279 Jts 7" 26# L-8® BTCM Csg 11871.63 36,32 V1/eatherfard Float Cellar 1.25 11907.85 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 84.26 11909.10 Ray Oll Tools "'Slluer Bullet" Flaat Shoe 1.50 11993.36 11994,86 Tl~ 8-3i4'" 1-{ale 12005,J0 8-314" 4a1e TD ~ 12,4f1' SID / 7'152" t) 7£e ha 11,994.85' E1lD 17152' Tel ~ °* ,' Cetrlszers, 2 :~ht blade cetralsaer ane per 1t an yts '1'14 ~°` €ht blade centrls~er arse perlt an its. 27,0tt,2Cl9 Stasgt blade cent. ane eery ether last `s 1 ~ - 279 TQp ss _;. ;. g; m1 $y~£3Ei ~ CYICd' S y~V ~ L Yid ~~ , _s _n ec1 - 281 tatal its. to resn l ` ' its. taut tag tap of jt. #/ 10 c(~z? 11 X557` Use Run & Seal i e do e average mare p torque 8Q(70 ft!lbs Remarks: l}p'lVt - 370 k Dn V`dt - i 65 k Blaclt VVt - 75k Supervisor. /ctcey I urtzulr • • ConocoPhillips Alaska Page ~ of 3 Cementing ...Report Legal Well Name: CD4-319 Spud Date: Common Well Name: CD4-319 Report #: 2 Report Date: 11/10!2005 Event Name: R07 -DRILLING Start: 11/1/2005 End: Cement Job Type:, Primary .Prima S ueeze O en Hole S ueeze Casin Plu Hole Size: 8.750 (in) Hole Size: Hole Size: Hole Size: TMD Set: 11,995 (ft) SO TMD: (ft) TMD Set: Top Set: (ft) Date Set: 11/10/2005 SO Date: Date Set: BTM set: (ft) Csg Type: Production Casing SQ Type: Csg Type: Plug Date: Csg Size: 7.000 (in.) SO TMD: Plug Type: SO Date: Drilled Out: Cmtd. Csg: Production Casing Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jim Thompson Pipe Movement: Reciprocating Pipe Movement Rot Time Start: Time End: RPM: Init Torque: {ft-Ibf) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Rec Time Start:07:00 Time End: 10:45 SPM: Stroke Length: 25.0 (ft) Drag Up: 325,000 (Ibs) Drag Down: 160,000 (Ibs} Stage No: 1:of 1 Type: Cement Casing Start Mix Cmt: 09:26 Disp Avg Rate: 6.50 (bbl/min) fisftrtrts: 100 Volume Excess %: 40.00 Start Slurry Displ : 09:26 Disp Max Rate: 6.50 (bbl/min) Total Mud Lost: (bbl) Meas. From: N!A Start Displ: 09:48 Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 11:05 Press Prior: 700 (psi) To Cementing: 2.00 End Pump Date: 11/10/2005 Press Bumped: 1,200 (psi) Ann t"IowAfter: N Mud Circ Rate: 252 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: Mud Circ Press: 650 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Mud Data Type: Non-Disp. LS Density: 9.8 (ppg) Visc: 39 (s/qt) PV/YP: 9 (cp)/18 (IbJ100ftZ) Gels 10 sec: 9 (Ib/100ftZ) Gels 10 min: 11 (Ib1100ft2) Bottom Hole Circulating Temperature: (°F) Bottom Hole Static Temperature: ( °F) Displacement Fluid Type:Mud Density: 9.8 (ppg) Volume: 436.00 (bbl} .Stage No: 1 Slurry No: 1 `of 4 Slurry Data _ . ,, ...... Fluid Type: FLUSH Descrip ' : CW100 Class: Purpose: Preflush Slurry Interval: 7,676.00 (ft}1"o: 6,183.00 (ft} Cmt ol : 40.0 (bbl) Density: 803.00 (ppg) Yield: (ft'/s k) Mix Water: (gat) Water Source: Slur Vol: (sk) Water Vol: (bbl) Other Vol: () Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi} Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (Psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) n__~_~. wn i~~i~nnc 7.~fG.l1~~hA • • ConocoPhillips Alaska Paget of 3 Cementing.. Report Legal Well Name: CD4-319 Spud D ate: Common Well Name: CD4-319 Report #: 2 Report Date: 11/10/2005 Event Name: ROT -DRILLING Start: 1 1/1/2005 End: Stage No: 1 Slurry No: 2 of 4 Slurry Data Fluid Type: Spacer Descripti : lV1UDP+ SH XL Class: Purpose: SPACER Slurry Interval: 9,542.00 (ftjro: 7,676.00 (ft) Cmt V :50.0 (b6 Density: 10.50 (ppg) Yield: (ft'/sk) Mix Water: (gaq Water Source: Slurry ol: (sk) Water Vol: (bbl) Other Vol: Q Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No:' 1 Slurry No: 3 of 4 Slurry Data Fluid Type: LEAD Description: LiteCRETE Class: Purpose: ZONAL ISOL Slurry Interval: 11,495.00 (fip: 9,542.00 (ft) Cmt Vol:: 77.8 (bbl) Density: 11.00 (ppg) Yield: 3.35 (ft'/sk) Mix Water: 11.22 (gal) Water Source: •Slurry Ye~1:130 (sk) Water Vol: 35.0 (bbl) Other Vol: Q Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No: 1 SlurryNo: 4 of 4 Slurry Data Fluid Type: TAIL Description: Class: G Purpose: SHOE INTEG Slurry Interval: 11,995.00 (ftp: 11,495.00 (ftlCmt Vol: 23.1 (bbl) Density: 15.80 (ppg) Yield: 1.16 (ft'/sk) Mix Water: 5.09 (gal) Water Source: Slurry Vo1:111 (sk) Water Vo1:13.4 (bbl) Other Vol: Q Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) • ConocoPhillips Alaska Page 3 of 3 .Cementing Report Legal Well Name: CD4-319 Spud Date: Common Well Name: CD4-319 Report #: 2 Report Date: 11/10/2005 Event Name: ROT -DRILLING Start: 11/1/2005 End: .Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) Pressure: (ppge) Liner Lap: For: 30 (min) Tool: N Pos Test: (ppge) Tool: N Cement Found between Open Hole: (ft) Neg Test: (ppge) Tool: N Shoe and Collar: N Hrs Before Test: Hrs Before Test: Cement Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (ft) Under Pressure: (psi) Flow Determined: Bond Quality: TOC Sufficient: N Cet Run: N Job Rating: Bond Quality: If Unsuccessful Detection Indicator: Temp Survey: N Remedial Cementing Required: N Firs Prior to Log: Number of Remedial Squeezes: Remarks Cement 7" casing as follows: Pumped 5 bbls CW-100 -Tested lines to 3700 psi -Pumped 35 bbls CW-100 @ 5 bbls/min @ 560 psi - Mixed & pumped 50 bbls 10.5 ppg MudPush XL spacer @ 5 bbls/min @ 560 psi -Dropped btm plug -.Mixed & pumped 77.8 bbls 11.0 ppg lead slurry LiteCrete @ 6 bbls/mins @ 560 psi -Mixed & pumped 23 bbls 15.8 ppg tail slurry (class G w/ additives) @ 4.4 bbls/min @ 350 psi -Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 436 bbls 9.8 ppg LSND mud @ 6.5 bbls / min @ 460 to 770 psi -slowed pumps to 3.5 bbls/min for last 35.9 bbls 570 psi top 700 psi bumped plug w/ 1200 psi -check floats OK - CIP @ 11:05 hrs. -Full returns through out job -reciprocated pipe until half of lead slurry out of shoe ~.._._.. „~„nnnc v~oa•nc nnn • Page 1 of 2 ConocoPhiilips Alaska, Inc. Daily Drilling Report WELL NAME CD4-319 JOB NUMBER EVENT CODE ODR 24 HRS PROG TMD 12,005.0 ND 7,152.9 DFS 10.75 REPT NO. 14 GATE 11/9/2005 SUPERVISOR D. Micke /Z. Kuenzler RIG NAME 8 NO. FIELD NAME / OCS NO. Do on Drillin Inc 19 AI ine AUTH MD 18,748.0 DAILY TANG CUM. TANG 0 0 CURRENT STATUS Runnin 7" casin ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD 0 CUM INTANG WI MUD 0 24 HR FORECAST Cement, L/D 5", PJU 4" DP. PATE OF LAST SAFETY MEETING 11/9/2005 DAILY TOTAL 123,391 CUM COST W/ MUD 2,468,309 LITHOLOGY MEDIUM SAND JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF 18.38 AFE 10093005 AUTH. LAST SURVEY: DATE TMD !NC AZIM 11/8/2005 12,005.00 89.960 344.000 LAST CASING 9.625 in 3,196.0 ft NEXT CASING 7.000 in 11,995.0 ft LAST BOP PRES TEST 11/2/2005 DENSITY(ppg) 9.80 PP ECD 9.80 MUD DATA Di41LY COST 0 CUM COST 0 FV PV/YP GELS WL/HTHP FClf.SOL OILNJAT °J°Sand/MBT Ph/pM Pf/Mf Ct Ga H2S LIME ES 40 9/24 9112 3.4/8.4 1 / / 122.5 8.8/ BHa No. 3 BHA /HOLE CONDITIONS Blr No. 3 BHA WT. BELOW JARS STRING WT. UP STRING WT. DN STRING WT. ROT TORQUE /UNITS BHA LENGTH 1,961.68 ITEM DESCRIPTION NO JTS LENGTH O.D. LD. CONN SIZE. CONN TYPE Bit 1.20 8.750 Mud Motor 25.07 6.750 4.490 Drill Collar -Hang Off Jt 9.14 6.750 3.125 Stab -Non Mag 1.96 6.750 1.920 6 3/4" RLLwDGR+EWR+PWD 21.11 6.700 1.920 Stab -Non Mag 2.19 6.760 1.920 6 3/4" HCIM 6.98 6.760 1.920 Nukes 27.14 6.750 1.920 NM 6 314" TM HOC 10.00 6.750 3.250 6 314" Float sub 2.48 6.750 2.813 DC - NM 31.04 6.688 2.813 DC - NM 31.03 6.813 2.813 DC -NM 31.05 6.813 2.813 HWDP 3 90.41 5.000 3.000 6.25 DNT Jars 32.41 6.125 2.313 HWDP 14 419.87 5.000 3.000 Drill pipe 2 63.47 5.000 4.276 Ghost Reamer 6.90 6.500 2.875 Drill pipe 32 1,078.62 5.000 4.276 Ghost Reamer 6.09 6.650 2.875 Drill pipe 2 63.52 5.000 4.276 BITS .'BIT /RUN SIZE MANUF. TYPE SERIAL NO. JETS OR TFA DEPTH 1N DATE dN I-O-D-L-B-G-O-R 3 / 3 8.750 HUGHES-CHR DP1010 7101139 16116116/161161 10,652.0 11/6!200 0-0-NO-A-D-I-NO-TD BIT OPERATIONS BIT I RUN WOB RPM GPM PRESS P BIT HRS 24Hr DIS7 24Hr ROP CUM HRS CUM DEPTH CUM ROP OPERATIONS SUMMARY .FROM TO HOURS CODE. TROUBLE SUB PHASE DESCRIPTION 00:00 06:00 6.00 DRILL P TRIP INTRM1 Continue POOH on TT f! 9126' to 740' -Flow check (static) -Pumped dry job @ 8650' -Stand back HWDP 06:00 08:30 2.50 DRILL P PULD INTRM1 PJSM on handling RA sources -Stand back NM flex DC's -Remove RA v....~..a~ ~1/~nnnnF 7~~n~Sd AAA • • page 2 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME CD4-319 JOB NUMBER EVENT CODE ODR 24 HRS PROG TMD 12,005.0 TVD 7,152.9 DFS 10.75 REPT NO. 14 DATE 11/9/2005 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION. 06:00 08:30 2.50 DRILL P PULD INTRMI sources from MWD -down load MWD - LD BHA 08:30 11:00 2.50 DRILL P OTHR INTRM1 Pull wear bushing -Set test plug -Change saver sub in TD & change top pipe rams to 7" -test. rams to 250 & 5000 psi -Pull test plug -set thin wall wear bushing 11:00 13:00 2.00 CASE P OTHR INTRMI RU tro run 7" casing -Held PJSM 13:00 16:30 3.50 CASE P RUNC INTRMI Run 7" 26# L-80 MBTC casing as follows: FS (Ray Oil Tools sliver bullet) 2 jts. csg - FC (Weatherford) 2 jts. casing (all connecetions made up w/ BakerLoc - fill pipe & check floats) 71 jts. csg (75 jts. total) to 3188' 16:30 17:00 0.50 CASE P CIRC INTRM1 Circualte casing volume -stage pumps up to 4.5 bblslmin. @ 290 psi 17:00 20:45 3.75 CASE P RUNC INTRM1 Continue running 7" 26# L-80 MBTC casing f/ 3188' to 6,380' (150 jts). 20:45 21:45 1.00 CASE P CIRC INTRM1 CBU staged pump up from 3.3 bpm w! 430 psi to 4.5 bpm w! 370 psi. String wt. PUW=185K SOW=140K 21:45 00:00 2.25 CASE P RUNC INTRM1 Cont'd RIH w 7" casing from 6,380' to 8,001' (188 jts). String wt. PUW=235K SOW=150K 24 HR SUMMARY: L/D BHA, R/U for 7" casing run. Ran 7" casing to 8,001', PERSbN NEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS ConocoPhillips Company M-I Drilling Fluids 3 Fairweather E&P Service 1 Swaco 4 Doyon Drilling Inc 25 Dowell 2 ACI -Arctic Catering 5 FMC Corporation Wellhe 1 Halliburton -Sperry-Sun 2 PRA -Petroleum Resour 1 Halliburton -Sperry-Sun 2 Schlumberger 3 MATERIALS /CONSUMPTION ITEM UNITS USAGE ON HAND ITEM UNITS' USAGE. ON HAND Fuel Rig gals 2,938 10,370 Fuel Camp gals 400 3,280 Water, Drilling bbls 360 Water, Potable bbls 390 RESERVOIR AND INTERVAL DATA RESERVOIR NAME ZONE TOP BASE COMMENTS CD2-19A CD4-319 0 0 • • Page 1 of 2 'ConocoPhllips Alaska., Inc. Daily Drilling Report WELL NAME CD4-319 JOB NUMBER EVENT CODE ODR 24 HRS PROG TMD 12,005.0 TVD 7,152.9 DFS 11.75 REPT NO. 15 DATE 11/10/200 SUPERVISOR D. Micke /Z. Kuenzler RIG NAME & NO. Do on Drillin Inc 19 FIELD NAME / OCS NO. AI ine AUTH MD 18,748.0 DAILY TANG 0 CUM. TANG 0 CURRENT STATUS P/U 4" DP to stand back. ACCIDENTS LAST 24 HRS.? DAILY INT W!O MUD 0 CUM INTANG W/ MUD 0 24 HR FORECAST Finish P/U 4" DP, R/U and test BOPS, M/U clean out BHA. DATE OF LAST SAFETY MEETING 11/9/2005 DAILY TOTAL 400,958 CUM COST W/ MUD 2,869,267 LITHOLOGY MEDIUM SAND JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF 18.38 AFE 10093005 AUTH. LAST SURVEY: DATE TMD INC AZIM 11/8/2005 12,005.00 89.960 344.000 LAST CASING 9.625 in 3,196.0 ft NEXT CASING 7.000 in 11,995.0 ft LAST BOP PRES TEST 11/2/2005 DENSITY(ppg} 9.80 PP ECD 9.80 MUD DATA DA1LY COST' 0 CUM COST 0 FV PVlYP GELS WUHTHP FCff.SOL OIUWAT %Sand/MBT Ph/pM Pf/Mf CI Ca H2S LIME ES 39 9/18 9/11 3.6/8.8 1/ / 122.5 8.51 / OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 01:30 1.50 CASE P RUNC INTRM1 Continue running 7" 26# L-80 csg f/ 8001' to 9569' (225 jts. total) 01:30 03:00 1.50 CASE P CIRC INTRMI Establish circulation -circulate btms up @ 4 bbls/min ICP 600 psi FCP 450 psi 03:00 06:30 3.50 CASE P RUNC INTRMI Continue running 7" 26# L-80 csg f/ 9569' to 11,958' - PU hanger & landing jt. & land casing w/ shoe @ 11994.86' - FC @ 11907.85' - No problems running casing - no tight spots & no losses 06:30 07:00 0.50 CASE P OTHR INTRM1 LD Frank's fill up tool - RU cement head & lines 07:00 09:00 2.00 CEMENT CIRC INTRM1 Establish circulation -stage pumps up to 6 bbls/min -circulate & condition for cement job - ICP 730 psi FCP 620 psi reciprocate pipe PU 325 k SO 165 k Held pre job meeting with crew on cementing operation 09:00 11:00 2.00 CEMENT PUMP INTRMI Cement 7" casing as follows: Pumped 5 bbls CW-100 -Tested lines to 3700 psi -Pumped 35 bbls CW-100 @ 5 bbls/min @ 560 psi -Mixed & pumped 50 bbls 10.5 ppg MudPush XL spacer @ 5 bbls/min @ 560 psi -Dropped btm plug -Mixed & pumped 77.8 bbls 11.0 ppg lead slurry LiteCrete @ 6 bbls/mins @ 560 psi -Mixed & pumped 23 bbls 15.8 ppg tail slurry (class G w/ additives) @ 4.4 bbls/min @ 350 psi -Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 436 bbls 9.8 ppg LSND mud @ 6.5 bbls /min @ 460 to 770 psi -slowed pumps to 3.5 bbls/min for last 35.9 bbls 570 psi top 700 psi bumped plug w/ 1200 psi -check floats OK - CIP @ 11:05 hrs. -Full returns through out job -reciprocated pipe until half of lead slurry out of shoe 11:00 12:00 1.00 CASE P MIT INTRMI Checked float, holding. Tested casing to 3500 psi for 30 mins. 12:00 13:00 1.00 CEMENT PULD INTRMI R/D cement and casing equip. UD landing jt. 13:00 14;00 1.00 CASE P DEQT INTRMI Pulled 7" wear ring. Installed 9.625"X7" packoff, energized lock downs and tested seals to 5000 psi for 10 mins. w/FMC. 14:00 15:00 1.00 WELCTL EQRP INTRMI Held PJSM. Changed ram to 3.5"X6" variable. 15:00 15:30 0.50 DRILL P OTHR INTRM1 Installed short wear bushing. 15:30 19:15 3.75 DRILL P PULD INTRMI UD 5" DP via mouse hole. 19:15 20:00 0.75 DRILL P PULD 1NTRM1 Move 6.75" DCs, UD jars, repositioned HW in derrick. 20:00 00:00 4.00 DRILL P PULD 1NTRM1 Cont'd to UD 5" DP via mousehole. 24 HR SUMMARY: Landed 7" casing w/ shoe @ 11,995'. Cement casing w/ full returns. Installed packoff, C/O rams, UD 5" DP. rnncea: i u i u~wn rto:~+ r,m • ConocoPhillips'Rlaska, Inc. Daily Drilling Report Page 2 of 2 WELL NAME CD4-319 JOB NUMBER EVENT CODE ODR 24 HRS PROG TMD 12,005.0 TVD 7,152.9 DFS 11.75 REPT NO. 15 DATE 11/10/200 PERSON NEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS ConocoPhillips Company 1 M-I Drilling Fluids 3 Fairweather E&P Service 1 Swaco 4 Doyon Drilling Inc 24 Dowell 2 AC1 -Arctic Catering 5 FMC Corporation Wellhe 1 Halliburton -Sperry-Sun PRA -Petroleum Resour 1 Halliburton -Sperry-Sun Schlumberger 5 MATERIALS /CONSUMPTION ITEM UNITS USAGE ON HAND ITEM UNITS USAGE ON HAND Fuel Rig gals 2,826 15,944 Fuel Camp gals 480 2,800 Water, Drilling bbls 1,575 Water, Potable bbls 390 RESERVOIR AND INTERVAL DATA `.RESERVOIR NAME ZONE TOP BASE COMMENTS CD2-19A CD4-319 1960 0 Prin[etl: 71/11/LUUS /:15:54 HM PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Mame: CD4-319 Rig: Dcyc~rt 19 Date: 11I10I2005 Volume Input Pump Rate: Drilling Supervisor: _14uenzlcrl~rlickey Pump used: Cement Unit _ ~ Barrels ~ Bbls/Strk ~ I g~s Bbl/min ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casing Test Pressure In te rity Test Hole Size: 8-3/4" ~ Casing Shoe Depth Hole De th Pum pin Shut-in Pumping Shut-in RKB-CHF: 34.6 Ft 3,196 Ft-MD 2,400 Ft-TVD 9,542 Ft-MD 5,821 Ft-TVD Bbls si Min psi Bbls psi Min psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 50 0 505 Chan es for Annula r Ade ua c Test Pressure Int e rit Test 1 0.5 81 0.25 490 uter casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 157 0.5 475 Description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 212 1 460 ize is that drilled below outer casing. 4 2 278 1.5 4 timated TOC for Hole Depth. 5 2.5 333 2 4 Enter inner casing OD at right Desired PIT EMW: 14.5 ppg 6 3 394 2.5 444 Estimates for Test: 587 psi 0.6 bbls 7 3.5 444 3 439 - ~ ~ 8 4 500 3.5 ` 439 EMW =Leak-off Pressure + Mud Weight = 787 PIT 15 Second 9 4.5 550: 4 439 + 9 8 0.052 x TVD 0.052 x 2400 Shut-in Pressure, psi 10 5 601 4.5 434 EMW at 3196 Ft-MD (2400 Ft-TVD) = 16.1 490 15 5.5 646 5 434 looo ~ l 20 6 697 5.5 429 L~ I 25 6.5 747` 6 429 - - ~ 30 7 787- 6.5 ' 429 7.5 813 7 429 8 661 7.5 424 8 5 586 8 424 - . W ~ 9 576 8.5 424 ~ 9.5 570. 9 ' 419 ~ 10 570 5 9 419 y 500 w ~ - 10.5 570 . 10 n. ~ ~ ~ hW { 0 2 4 6 8 1 0 1 2 0 5 10 1 5 20 2 5 3 0 0 "~~CA SING TEST Barrel s L EAK-OFF TE ST Shut-In tim O PIT Poi e, Minute nt s Vol Pum ume ed Vol Bled ume Back Vol Pu ume m ed Volume Bled Back S S S S Comments: 9 5/8" ~atlrl`~3C~ aSfri~ S~IC}~ L{~T - 1 ~.4 ppc~ ~-' ConocoPhillips Nasky HALLIBURTON Sperry Drilling Services c_ 0 0 m t 1= 0 z L 5 0 N ~~ a~M.noa r~.oirm.i~am iro.a.r~ °'°°'°`° P ~ ~co"`a~ Ground ~e~ei. 19 00 RKB Doyo~ 19 i~ 551011 (HKBS51 h .~Mvc MSL~ Northing/ASP Y' S95]M1215 Fzsting'ASP %. 3Pfl2G.39 Project: Colville River Unit Site: Alpine CD4 Well: CD4319 Wellbore: CD4.319 Survey: CD4-319 i ~sas s®a4 9x aae _ ~isss wmm r ~ a ~mr aeon ~~ ~+rz -3600 -2700 -1800 -900 0 900 1800 2700 3600 WesK-Y~~(+) (~ ~) SURFACE CASING SHOE SEPARATION FROM CD4-319 CD4-319 x Y Surfarp Casino Shna ASP 4 Coordinates NAD 2Z 377174.72 5955790.42 ells Nanuk 1 Nanuk 2 Details @ AOGCC n n Ann. Disp. Permit # ermit Date ource well Ann. Vol. "*** tart Date nd Date is ance from Object wells Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments xp ora ion Exploration P&A'd Nanu 3 1729 376499.69 5957381.96 11.8 1781 Ex )oration Nanu 5 1237 378326.61 5956241.68 14.9 2393 15.1 CD2-319 ~ 0 .377174.72 5955790.42 18.4 2400 16.1 CD4-208 Current) drillin 'Lateral distance in feet, between surface casing shoes, in the X-Y plane " AS of December 5, 2005 Note that this sheet is not the definitive record for annular disposal volumes ~J STATE OF ALASKA "" 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ~~m re~g~~~adrr:i:~.stute.ak.t~s• aa~cc ,pr;_Er€~~as b:v~ad:~nin.s~tae.ak.us br:i~ ecker~stAin;~adrr:i:~.stute.ak.~~~• Contractor: Doyon Rig No.: 19 DATE: 11/27/2005 Rig Rep.: Krupa/Lupton Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley/Hill Field/Unit & Well No.: Colville Rv CD4-319 PTD # 2Q5-348 Operation: Drlg: x Test: Initial: Test Pressure: Rams: 250/5000 Workover: Weekly: Annular: 250/3500 Explor.: Bi-Weekly x Valves: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Annular Preventer 1 13-5/8 Pipe Rams 1 3-1/2x 6 Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P TEST DATA Test Result P P FLOOR SAFETY VALVES: Quantity Test Resu Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Resu System Pressure 3000 P Pressure After Closure 1625 P 200 psi Attained 30 P Full Pressure Attained 2 min 35 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2150 Test Result P P Test Results Number of Failures: 0 Test Time: 4.5 Hours Components tested 28 Repair ar replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: dim re~Ob~3~adr~:i:~.stute.a>i.u• Remarks: BOPE tested good. 24 HOUR NOTICE GIVEN YES X NO Waived By Chuck Scheve Date 11/25/05 Time 7:OOpm Witness BurleylKrupa Test start Finish BOP Test (for rigs) BFL 11/09/04 Doyon19 11-27-05 CD4-319.x1s '~ STATE OF ALASKA ~ ~~~iosioa OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ~i~ re~g y~~:in.stat~.ak.u~~ br:l~ eckenst°in;~adrr:i:~.stute.ak.tt~~ Contractor: Doyon Rig No.: 19 DATE: 11/11/2005 Rig Rep.: Welsh / Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 ~ Rep.: Mickey/Kuenzter FieldlUnit & Well No.: Colville Rv CD4-319 PTD # 205-148 Operation: Drlg: x Workover: Explor.: Test: Initial: Weekly: Bi-Weekly x Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-118 P HCR Valves 2 3-118 P Kitl Line Valves 1 3-1l8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results FLOOR SAFETY VALVES: Quantity Test R Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 2900 P Pressure After Closure 1600 P 200 psi Attained 28 P Full Pressure Attained 2 min 08 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2200 Number of Failures: 0 Test Time: 7.25 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North S{ope Inspector 659-3607, follow with written confirmation to Superviser at:~im.__ re~~:~3ad~:i:~state.ak.ix Remarks: BOPE tested good. Had to rebuild test pump/pump manifold 24 HOUR NOTICE GIVEN YES X NO Date 11!102005 Time 8:30 Test start 12o0pm Finish Waived By Lou Gremaldi Witness Mickey /Welsh BOP Test (for rigs) BFL 11/09/04 Doyon19 11-11-05 CD4-319.x1s STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to: dim re~~~yadrri:~.state.a>~.us~ ua~ca pr~.~d~ae b:~~ad¢~in.stae.ak.us br§ ~ ecl~er~sten :~adrr:in.stute.a>i.~1s~ Contractor: Doyon Rig No.: 19 DATE: 11/2/2005 Rig Rep.: Krupa /Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Hill/Kuenzler Field/Unit & Well No.: Colville Rv CD4-319 PTD ~IIt:1~6-~48 Operation: Drlg: x Workover: Explor.: Test: initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/5000 Annular: 250!3500 Valves: 250/5000 TEST DATA i MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. j Standing Order Posted P BOP STACK: Quantity Size ~ Annular Preventer 1 13-5/8 ~ Pipe Rams 1 3-1/2x 6 Lower Pipe Rams 1 3-1/2x 6 j Blind Rams 1 blinds Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1 /8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Test Result Quantity Test R P Upper Kelly 1 P P Lower Kelly 1 P P Ball Type 1 P Inside BOP 1 P Test Result CHOKE MANIFOLD: P Quantity Test R P No. Valves 16 P P Manual Chokes 1 P P Hydraulic Chokes 1 P Test Results ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 2950 P Pressure After Closure 1550 P 200 psi Attained 33 P Full Pressure Attained 2 min 34 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2200 j Number of Failures: 0 Test Time: 4.75 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: dim re~~ ~adn:instute.ak.us Remarks: Good test 24 HOUR NOTICE GIVEN YES X NO Date 11!01!05 Time 6:OOam Test start 6:15pm 11/~ Finish Waived By Jeff Jones Witness Kuenzler /Grazulis BOP Test (for rigs) BFL 11/09/04 Doyon19 11-02-05 CD4-319.x1s Re: CD4-319 intermediate casing cement • • Subjectf Re: CD4-319 intermediate casing cement Froth: Thomas Maunder <tom maunder@admin.state.ak.us=~ Date: Tue, Ol Nov 2005 14:49:1.3 -0900 To: ".lohnson, Vern" ~~-Vern.JohnSOn~a;conocox~hilli~s.cum,=~ C:C: "Noel. Brian" =~=Brian.'~~o~l+'uconocophilli~is.conl~-, "G~iliunas, 1•lizabeth C" <=E?IizabcCh.C'.Galiun~isr«conocophillips.com:= Vern, ~~~ Thanks for the notification of the change. Nothing further is neede in the well file. Tom Maunder, PE AOGCC Johnson, Vern wrote, On 11/1/2005 2:45 PM: Tom, ~~ d. I will put a copy of this message As discussed today, we plan to make a change to our intermediate casing cement program on CD4319. The program, as described in the permit to drill, indicated 484 sx of 15.8 ppg Class G cement. Equivalent circulating density models show that a single slurry pumping operation will have ECD near the fracture gradient of the Kuparuk sands. To reduce ECD, we plan to pump a lightweight (11 ppg LiteCrete) slurry ahead of 500 ft MD of 15.8 ppg class G cement. Planned top of cement will remain the same (500' above the Nanuq sands). Let me know if you have any questions or concerns. Vern Johnson 907-265-6081 1 of I 11/1/2005 2:49 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Submit to: t:~rn_rrr;:ndcr~r?a;irrrin.st.:^.ai~.:;v aup r `>;;di,~O.. ~;~wrvt;8~n'EI'1.::tB:°.:2K.:_S isC>:7.-_f~C::;k£?rl:ic:In~(,E.:i173ii: ;ii;~It. al~.ii;E Date: 29-Oct-05 Operation: Development x Exploratory: Drlg Contractor. Doyon Rig No. 19 PTD 2f?5_i'48 Rig Ph. # 670-4300 Operator: Conoco Phillips Alaska Inc. Oper. Rep Field/Unit & Weli No.: CD4-319 Rig Rep. Location: Sec. 24 T. T11 N R. R4E Hill Krupa/Lupton Merdian UM At ~.`'T..~ .... 1~ ......... . MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: P Systems Pressure: 3050 psig Housekeeping: P (Gen.) Drlg. Rig: P Pressure After Closure: 1600 psig Reserve Pit: N/A Flare Pit: N!A 200 psi Attained After Closure: min 28 sec. Systems Pressure Attained: 2 mim 36 sec. DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: 4 2150 si avera e Diverter Size: 20 in. psig Divert Valve(s) Full Opening: YES Vave(s) Auto & Simultaneous: YES MUD SYSTEM INSPECTION: Light Alarm Vent Line(s) Size: 16 in. Trip Tank: P P Vent Line(s) Length: 85 ft. Mud Pits: P P Line(s) Bifurcated: N/A Flow Monitor: P P Line(s) Down Wind: YES Line(s) Anchored: YES GAS DETECTORS: Light Alarm Turns Targeted /Long Radius: N/A Methane P P Hydrogen Sulfide: P P ': ' :: `:.`:::. j _ ff .D \FERTER SC ..E~IATIG ...... . . = s RIG 19 SUB Div. Vent line Non Compliance Items 0 Repair Items Withir N/A Day (s) And contact the Inspector @ 659-3607 Remarks: Test went ood AOGCC REP.: Witnessing waived by Jeff Jones OPERATOR REP.: Larry Hill Diverter Test (for rigs) BFL 11/20/00 Diverter Test CD4-319 Doyon 19, 10-29-05.x1s [Fwd: Re: [Fwd: CD4 new pad data]] Subject: [F~~•d: Re: [Fwd: CD4 new pad data]] From: Thomas Maunder <toril maunder@,admin.state.ak.us> Date: Wed, 26 Oct Z(i05 10:36:59 -0804 'ho: Brian Noel <E3rian.~oc(u co~lorophillips.con>>, Vern Johnson °-Vcrn.Johnsonla:ci~i~oco~~hillips.com~. Brian and Vern, Your proposal regarding mud logs and e logs at Nanuq is acceptable. Tom Maunder, PE AOGCC -------- Original Message -------- Subject:Re: [Fwd: CD4 new pad data] Date:Wed, 26 Oct 2005 10:32:11 -0800 From:Stephen Davies <steve davies~czlad7nn.state.ak.us> Organization:State of Alaska To:Thomas Maunder <tortn maunder~;admin_state.ak.us> References:<435FAC3 E.406()303(uadn~in.state.ak.us> Tom, Regarding 20 AAC 25.071 and the CD4 pad: ®~- ~~1~ 1. When I reviewed the permit application for CD4-319, I checked the offset exploratory wells and found that Nanuq 3 and 5 along with nearby Nanuk 2 all have mud logs and cuttings samples from conductor to TD. So, it is not necessary for the operator to provide a mud log or cuttings samples for CD4-319. 2. The proposed logging program will satisfy the regulation. Thanks, Steve Davies AOGCC Thomas Maunder wrote: > Steve, > What are your thoughts. I think what they propose is acceptable. > Tom > -------- Original Message -------- > Subject: CD4 new pad data > Date: Tue, 25 Oct 2005 16:34:22 -0800 > From: Noel, Brian <Brigs;.NOelyco.nocop:~ill_i.ps.com> > To: tom maunder@admin.state.ak.us > CC: Johnson, Vern <Vern.Jol_z:som~cnnocophilli s.com> > Tom - > Since Nanuq #3 and #5 (two exploration wells that are part of the CD4 > pad well rows do not have electric logs covering the surface hole, we > plan to obtain gr/res/d-n from conductor shoe to TD in the Kuparuk > sand for 7" production casing. 1 of 2 10/27/2005 10:10 AM [Fwd: Re: [Fwd: CD4 new pad data]] > Nanuq #3 and #5 have mud logs from conductor shoe to TD, so hadn't > planned to catch any samples on CD4-319. > Is this an acceptable plan to meet 20 AAC 25.071 for a new drill site > development? > Thanks - Brian > -----Original Message----- > *From: * Moothart, Steve R *Sent: * Monday, October 24, 2005 11:11 AM > *To: * Noel, Brian > *Subject: * Nanuk Mud logs > Brian, > I show we gathered mud logs from surface on all of the Nanuq wells to > date > Steve 2 of 2 10/27/2005 10:10 AM Re: Colville River CD4-319 ConocoPhillips Alaska, Inc. Permit No: 205-148 Surface Location: 2973' FNL, 419' FEL, SEC. 24, T 11 N, R4E, UM Bottomhole Location: 1723' FNL, 398' FEL, SEC. 23, T11N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you. from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with. an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager}. DATED this~day of October, 2005 cc: Department of Fish & Game. Habitat Section w/o encl. STATE OF ALASKA ~ASKA OIL AND GAS CONSERVATION C MMISSION PERMIT TO DRILL 20 AAC 25.005 ~~ ~~~ 1a. Type of Work: Drill ~ Redrill 1b. Current Well Class: Exploratory ~ Development Oil ~ Multiple Zone Re-entry ~ Stratigraphic Test ~ Service ~ Development Gas ~ Single Zone 2. Operator Name: 5. Bond: Blanket ~ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180: CD4-319 3. Address: 6. Proposed Depth: 12. Field/Pool(s): PO Box 100360, Anchorage AK 99510-0360 MD: ~ g~48 ~ TVD: 7 ~ 20 Colville River Field .~ ~,, ~~ ~ 4a. Location of Well (Governmental Section): 7. Property Designation: Oil Pool ~ ~ ~ ~ Surface: 2973' FNL, '419 FEL, Sec. 24, T11 N, R4E, UM ' 380077, 384209 L ~ t\v k~~t~ Top of Productive Horizon: ~.) j~ u~ 8. Land Use Permit: 13. Approximate Spud Date: 3020' FNL, 4409' FEL, Sec. 25R1E, UM / iv~ ~~ ADL 38077 2~-0~~-{)~ Total Depth: , 0 9. Acres in Property: 14. Distance to Nearest ` 1723' FNL, 398° FEL, Sec. 23, T11 N, R4E, UM 2560 Property: 72867' FNL AJL39J676 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface:x- 377825 y- 5957442 ~ Zone- q. (Height above GL): 36.7 feet Within Pool: Planu 3 ~ 929' " 16. Deviated wells: Kickoff depth: 300 feet ~ 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3226 ' Surtace: 25'14 ` 18. Casing Program: Setting Depth Quantity of Cement Size Specifications Top Bottom c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 77 37 37 114 114 Portland Cement 12.25" 9.625" 40# J-55 BTC-M 2800 37 37 2837 2402 597 Sx AS Lite & 230 sx Litecrete 8.75" 7" 26# L80 BTG-M 12012 37 37 ~ 12049 7132 484 Sx 15.8 ppg class G 6.125" 4.5" 12.6# L80 SLHT 11865 ~1 0 *~~~ ~T .JAS Slotted liner 6.125" 4.5" 12.6# L80 IBT-M 18706 32 2 Tubing \\Cti`l ~ \~ ~" 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat ~ Diverter Sketch ~ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. Johnson 265-0681 Printed Name Chip Alvord Title Alpine Drilling Team Leader ~Y t 05 D t 7 O ~ ' t~ ~ - e - c a Phone 907-265-6120 Signature Commission Use Only Permit to Drill ~~ ~ API Number: ' Permit Approval See cover fetter for other uirements e Number: ~ ~ ~ 50- f~~_ ,~ /~ '~ `-~U Date: ~ .- . r q Conditions of approval : Clt. r Ct_~~h V-«- Q ~t3-t+~ ~ ^~ A! ~ ~ ~ ~ y ~'~ ~~ 1~l•T ~ ~y~~~-- S ple required Yes [] No Mud log required Yes ~ No ~~~`~ o n sulfide measures `\ Yes ~ No ,~ Directional survey r quired Yes ~ No ~>C•~ct~ t~t3~Cf.~'~t~~Z<~ Jn~~~ ~~ i`~ ZSS~ Other: - r ~~vn~~~CS'T ~cti~ ~ APPROVED BY THE COMMISSION Date: ~~ ~ Q Appro Form 10-401 Revised 06/2004 / Q~~ ~ d ZOQ~ bmit inDuplicate C n P i 0 oco hill ps Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 07, 2005 Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-319 Dear Sir or Madam: ConocoPhilfi s p R~~~~1 ~~ oCT ~ ~` 2005 Alaska Oil & Gas Cans, Commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Nanuq CD4 drilling pad. The intended spud date for this well is 10/21/2005. It is intended that Doyon Rig 19 be used to drill the well. ~~,, po.~-~~ ~ "~ ~~~, f ~ o CD4-319 will be drilled to penetrate the reservoir horizontally. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as slotted liner injector. At the end of the rig work program, the well will be flowed back to mitigate reservoir damage. ~ After drilling another well on the pad, a pulse test will be conducted with CD4-319 as a source well and 10000 bbls of seawater will be pump to gather reservoir data. The well will then be closed in awaiting completion of well work and facilities construction that wiN allow the well to begin injection fourth quarter 2006. It is also requested that the packer placement requirement be relaxed to place the completion packer +/- +/- 250 ft TVD above the Kuparuk reservoir. This will place the completion at a maximum inclination less than 65° and allow access to the completion with standard wireline tools for future intervention. 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 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 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. 3. Diagram of diverter set up. If you have any questions or require further information, please contact Vern Johnson at 265- 6081 or Chip Alvord at 265-6120. Si .rely, ~y'~/o ~ Vern Johnson Drilling Engineer • ~ Attachments cc: CD4-319 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation • • CD4-319 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1 /4" Hole / 9-5/8" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G o sin le shots, travelin c tinder dia rams Gas Hydrates - Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in : Low Increased mud weight Surface Formations >2000' ND Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-3/4" Hole / 7" Casino Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' ND increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low - Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECDj monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin wei hted swee s. Abnormal Reservoir Medium ~ BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers OR161NAL • • Fiord : CD4-319 Procedure 1. Move on Doyon 19. 2. Drill 12-'/." hole to the surtace casing point as per the directional plan. (DirectionaUMWD). 3. Run and cement 9-5/8" surface casing. 4. Install and test BODE to 5000 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Pick up and run in hole with 8-3/4" drilling BHA. 8. Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 9. Run and cement 7" casing as per program. 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. 10. BOPE test to 5000 psi. 11. 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 11.0 ppg EMW. 12. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 16. Circulate the hole clean and pull out of hole. 17. Run lower completion with slotted liner and liner hanger, 18. Rig up a-line and run a cement evaluation log ----1-~ 19. Run 4-%, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrel, tubing conveyed pressure gauges, packer and stinger assembly. Sting in, space out and land hanger. 20. Install 2 way check and pressure test hanger seats to 5000 psi. Nipple down BOP. 21. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 22. Circulate tubing to diesel and install freeze protection in the annulus. 23. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 24. Set BPV and secure well. Move rig off. ORIGINAL n Well Proximity Risks: • Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. Nanuq 5 is the closest well. Well separation is 137' @ 250' MD. Drillins~ Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Kuparuk reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. 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. DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint - 12 '/4" Intermediate hole to 7" casing point - 8 3/<" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 ppg r 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 API 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 J gel spud mud is recommended for the surface interval. Keep flow line 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 circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low 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 Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with t 30PP6 calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL CD4 - 319 Nanuq Kuparuk Injector Completion Sperry Sun 16" Insulated Conductor to Directional Plan WP05 -114' 10/06/05 4-'/i' 12.6 ppf L-80 IBT Mod. Tubing 3.813" DB Landing Nipple, Special Drift Circulate diesel and/or above nipple to 3.843" (Drift ID=3.833") corrosion inhibitor before setting packer after 9-5/8" 40 ppf L-80 BTCM Surface Casing tubing is spaced out and 3199' MD / 2402' TVD landed. Upp er Completion: Tom IyQ ltgm 1) Tubing Hanger 32' 32' 2) 4-1/2", 12.6#/ft, IBT-Mod Tubing 3) Camco DB nipple 2300' 1931' 4) 4-1/2", 12.6#/ft, IBT-Mod Tubing 5) HES 3.813 X nipple 10840' 6767' 6) 4-1/2", 12.6#/ft, IBT-Mod Tubing w/ special Clearance couplings (2) 7) Weatherford 7500 psi mPOD2 Gauge and Gauge Carrier ID=3.958", OD=6.145" 10940' 6822' 8) 4-1/2", 12.6#/ft, IBT-Mod Tubing w/ special Clearance couplings (2) 9) Camco KBG2- GLM (3.909" ID) 11040' 6874' 10) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) 11 ~ Baker Premier Packer 11140' 6921' 12) 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) 13) HES "XN" (3.725")- 64.9° inc 11200' 6947' 14) 4-1/2", 12.6#/ft, IBT-Mod +/- 18 jts 15) BOT Stinger with Fluted 1/VLEG/ stinger 11897' 7125' Stung into tieback extension 10', bottom at 11910' Lower Com lep lion: Too MD j~[Q lI@1Tt 16) Baker 5" x 7" Flexlock Liner Hanger 11900' 7126' 17) 4-1/2", 12.6#/ft, SLHT Tubing +/- 4 jts 18) 4-'/s' 12.6#/ft L-80 SLHT liner w/ blank across shale and slots across sand 19) Baker Shoe w/ packoff bushing 18738' 7120' Top of cement ~ 9466' MD / 5790' TVD Top Reservoir at +/- Nanuq 9996' MD / 6192' TVD Kuparuk 11924' MD / 7128' TVD 4 Yi' 12.6#/ft L-80 IBT Mod Slotted liner Pattern: 7" 26 ppf L-80 BTC Mod Production Casing @ +/-87° 12049' MD, 7129' TVD OR161NAL TD 6-1/8" hole 18748' MD / 7120' TVD ' • CD4-319 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 in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 3199 / 2402 14.5 1087 1571 7" 12050 / 7132 16.0 3227 ~ 2509 N/A 18748 / 7120 16.0 3221. N/A NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASPS 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) - 0.1]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./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 - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D =[(10.9x0.052)-0.1]x 114=53 psi OR ASP =FPP - (0.1 x D) = 1087 - (0.1 x 2402') = 846.7 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052} - 0.1] x 2402 = 1571 psi OR ASP =FPP - (0.1 x D) = 3227 - (0.1 x 7132') = 2514 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3221 - (0.1 x 7120') = 2509 psi ~.~.~ : , ; ~ • Cementing Program: 9 5/8" Surface Casing run to 3199' MD / 2402' TVD. Cement from 3199' MD to 2699' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2989' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1795' MD). Lead slurry: (2699'-1795') X 0.3132 ft3/ft X 1.5 (50% excess) = 424.7 ft3 below permafrost 1795' X 0.3132 ft31ft X 4 (300% excess) = 2248.8ft3 above permafrost Total volume = 424.7 + 2248.8 = 2673.5 ft3 => 597 Sx @ 4.48 ft3/sk System: 597 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk -----~ 7" Intermediate Casing run to 12050' MD /7132' TVD Cement from 12050' MD to 9466+/-' MD (minimum 500' MD above top of Nanuq reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (12050' -9466) X 0.1503 ft3/ft X 1.4 (40% excess) = 543.7 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 543.7 + 17.2 = 560.9 ft3 => 484 Sx @ 1.16 ft3/sk -_ System: 484 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D 167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additives are BWOrCemne{nt ~~V~1~~~ • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD4 Plan: CD4-319 -Slot 19 Plan: CD4-319 Plan: CD4-319wp05 Proposal Report 06 October, 2005 HA~~.~~ul~-roN Sperry Drilling Services ~~~G~NAL `' CaM la8°r, Matfwtl: MMkrem, Curvature Philli C E"or Sysbm: ISCWSA ScarM.Untl TravCyWWerNOrth Project: con7illeRiverUnit onoco ps Error Surface: Ellfptlcal COnlc w.,,l,q Method: Itulea l]aeed Site: Alpine CD4 I ~' !1'r.3.:ii43 ~~MaprotlcM°dNnBOCM2005CON~) Well: PIan:CD4319 Wellbore: Plan: CD4319 HALLIBUFiTON car«"'e Le°eo 19.ooc 31p~,,,~1~ Pl CD4 RKB. Doyat 79 ~a 55.100fI (RKf}55.1 R attwe MSI.) an: - ~•~~~ V orlhiny'ASP Y: `.8 57 4 41 828 2 Spenry Drilling Services E,SsngASPx 3776za.7n3 ANNOTATIONS = T1iD MD Annotation ___..- 36100 36100 SHL; 2973' FNL 8 419' FF1; Ser24T11N4204E 25DA00 250.000 Begin Oir; 3° DLS, 0° TFO, 250' M0, 250' 7VD 1871.025 2197.328 Start Sai; 58° INC, 7197 MD, 1877 TVD 2402000 3199.780 9{Y8" Csg R; 3199' MD, 2407 TVD 5246118 8690.691 n Dir, 4° OLS, 130° TFO, 8630' MD, 5245 TVD = 7132101 120x9.000 7' Pt; 12049' MD, 7137 TVD; 3020' FNL 84409' FEL; Set7ST11Nf204E 7132100 12049.571 Tar (11ee11; 12099' MD, 7132' TVD 7120100 18746099 Target (Tcel; 18748' MD, 7120' TVD, 1723' FNL &398' FEL; S0r13-Ti iNJi04E sFCr1oN oera-s Sac MD Fte __._Aa_-~ ND +N/S +E/•yy aa9 ha,x VSec Target _..- '_ 1 36100 0000 08000 3610D 0000 0000 OAD 00000 0!100 2 2`u.00D OA00 00000 25gA0D OtpO OlpO 000 00000 0.000 E 3 2'1973 X420 210AZi6 1877.Q15 8SL489 3'17AW 300 00000 711AB2 '- 4 863Q~1 5642D 7YIOA2ri5 5276.118 ~988.Si1 .730.447 080 00000 78321Y1 v 5 1~1 90103 340.0706 7132100 X380 'i9fl9b73 400 130.58'11 7b9fl4,S3 CDO,?t9AgOlFlaeJ 6 18748.099 90103 340.0706 7'12n100 1251.515 b2'H.7® 0.00 Q0000 540fi5B2 Q74319ap0lTOe ~ SHL; 2973' FNL 8 419' FEL; Sec24-T` Begin Dir, 3° DLS, 0° TFO, 250' MD, 2f - - c r° ^? O °o ~~ : r L d ~° ~° d c ' ? d 2 i €~ Base Permafrost Start Sail; 58° INC, 219T MD,187T T! C~0 -- + ~ 9518" Csg Pt; 3199' MD, 2402' TVD C-30 CA31NO DETAll9 ~ No TVD e0 Name 91za . `'-'~ 1 2/02.000 ]199.]e091e' 932 2 7112.101 12069.000 T 7 ] 7uo.loo 1e76a.o9e 61rz• a-1rz /K-3 Basal K-3 ~ K-2 Base K-2 Begin Dir, 4° DLS,130° TFO, 8630' MD, 5246' TVD Albian 97 - Afbian 96 7" Csg Pt;12049' MD, 713T TVD; 3020' FNL &4409' FEL; Sec25-T71 Na204E Top HRZ Base HRZ _ K-1 \ I -Kuparuk D Kuparuk C FQfdJA1e7J iCR cEiads NO TWPdIh M7Vd~+ Fp,reli0n 1 780.100 787.151 ELise Pemdh°st 2 7205.100 2823.7% C-00 3 2605.100 3205.700 CJO d 7773.100 39(18 dOJ C27 5 3&17.700 5959.233 K3 6 4066.100 6377.019 Basal K3 7 0107.100 60x9.987 K2 8 4211.100 6654.300 Base K2 9 5653.700 9549.963 Albian 97 10 6192700 99%.628 ARian% 11 6636.100 10%6224 T~F4~ 12 B99G.1 W 11373.736 Base HRZ 13 7055.100 11505.1 i3 K-1 t4 7o96.too ttfis>_e4z wr~a,l,kD 15 7128.100 11923.530 Kuparuk C 76 1.C0 Target (Heel); 12049' MD, 7132' TVD ~ i Target (Tce);18748' MD, 7120' TVD,1723' FNL 8 398' FEL; S7:c23 T11 N-R04E sooo -lsoo o 1590 3000 4500 9000 7500 9oge Vertical Section at 283.39° (1500 ft/in) C~Y.~Illm Matlcd: Mlninurn Oxv~ E~tlc~Cank ConocoPhillips ~ ~~ O~°delk Dion: lN.D 1917 Rb10CW CfXAb1 P.;a::ka rn.,.m M~a.c eovooa4 r°unC Level: 19.000 HALLIBURTON J RKB, Drym19®55.1opt(RK&w.tllaboveMSy e«lmngnsP v: ~s7441.6zez Sperry Drilling Services ~1kq'nsv x: 377au.7173 Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD4319 Welll3ore: Plan: CD4-319 Plan: CD4319wp05 ANNOTATgNS TVD MD MroUUm 36.100 36.100 SHL; 2973' FNL 8 419' FEL; Sec24T11 N-R04E 250.000 250.000 Begin Dir; >° DLS, 0° TFO, 250' M0, 250' TVD 1877.025 2197.328 Start Sail; 58° INC, 2197 M0, 1877' ND 2402.000 3199.780 9.578" Csg Pt; 3199' MD, 2402' TVD 5246.118 8630.691 n Dir; 4° OLS, 130° TFO, 8630' MD, 5246' TVD 7132.10112049.000 7" sg Pt; 12049' MD, 7137 TVD; 3020' FNL 84409' FEL; $ec2ST11N4204E 7132.10012049.571 Target (F1eel1; 12049' MD, 7137 ND 7120.10018748.099 Tag7e1 (ioel; 18748' MD, 7120' TVD, 172J' FNL 8398' FEL; Set23•T11N1t04E SECTgN DEfALS Cpq-g19Wpp5 ~~ Target (Tce); 18748' MD, 7120' TVD,1723' FNL &398' FEL; Sec23 711 N-R04E Sec MD Inc Aa TND ai4IS +EHN DLe9 TFa~ VSec Taget 1 36.100 0.000 0.0000 36.100 0.000 0.000 0.00 0.0000 0.000 2 250.000 0.000 0.0000 250.000 0.000 0.000 0.00 0.0000 0.000 3 2197.328 58.420200.4255 1877.025 4752489 317.469 3.00 0.0000 111.492 4 8630.1 58.420200.42555246.1184988.541-2230.147 0.00 0.0000 783203 512049.571 90.103349.0706 7132.1004325.3803989.673 4.001305611 2648.453 CD4319wpOM1 FUeI 6 18748.099 90.103349.0706 7120.100 1251.6354259.709 0.00 0.0000 5406.582 CD4.319wpOM1Tce SHL; 2973' FNL 8 419' FEL; Sec24-711 N-R04E Begin Dir, 3° DLS, 0° TFO, 250' MD, 250' TVD Start Sail; 58° INC, 2197 MD,187T TVD C O O t L ~'' O Z w 7 O N ~' TVD GYAl1EfN9 C ra too w r1... sm. 1 2lYme ]6i1e0 9'd 9Q! z 7172101 1Ta0m r 7 z 7tl610U ta410Ye ~,Q ~1rz T' Csg Pt; 12049' MD, 7132' TVD; 3020' FNL &4409' FEL; Sec25-711 Na204E Begin Dir; 4° DLS,130° TFO, 8630' MD, 5245 TVD FoRMn110N rop DEra~; Na NDpaOr MDPath Fomk-rtia 1 780.100 787.154 Base 7p,~~.r. ti, 2 2205.100 2823.795 Cd0 3 24os.1oo 3zos.7oo c3o 4 2773.100 7908.404 C-20 5 3847.100 5959.233 KJ 8 4066.100 6377.419 Basal K3 7 4104.100 6449.981 K-2 8 4211.100 6654.300 Base K-2 9 5853.100 9549.%3 Albian 97 10 6192.100 9996.428 Albian 96 11 6836.10010966.224 Tap HRZ 12 6996.10011323.736 Base HRZ 13 7055.10011505.113 K-0 14 7098.10011687.842 Kuparuk D 15 7128.10011923.530 Kuparuk C 16 LCU 43000 -7500 4000 -4500 3000 -1500 0 1500 soon West(-)/East(+) (15001t/in) ConocoPhillips Alaska .Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD4-319 Welibore: Plan: CD4-319 .Design: CD4-319wp05 Sperry Drilling Services Planning Report -Geographic Local Co-oMinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: HALLIBURTt~N Sperry Drilling Services Well Plan: CD4-318 -Slot 19 Doyon 19 ~ 55.100ft (RKB=55.1 ft above MSL) Doyon 19 (~ 55.100ft (RK6=55.1 ft above MSL) True Minimum Curvature Project .Colville River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Wall Plan: CD4-319 -Slot 19 Well Position +N/S 0.000 ft Northing: 5,957,441.8282 ft Latitude: 70° 17' 32.081" N +E/-W 0.000 ft Easting: 377,824.7173 ft Longitude: 150° 59' 20.922" W Position Uncertainty 0.000 ft Wellhead Elevation: ft Ground Level: 19.000 ft Wellbore Plan: CD4-319 Magnetics Model Name Sample Date Declination Dip Ansle Field Strength BGGM2005 10/6/2005 23.5522 80.6167 57,496 Ditslgn CD4-319wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.100 Vertical Section:. Depth From (TVD) +N/-S +E/-W Direction (tt) (~t) (f~) (°) 36.100 0.000 0.000 283.3855 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO lft) (°? (°) (ft) (ft) (ft) {°/700ft) (°t700ft) (°/t00ft) (°) 36.100 0.000 0.0000 36.100 0.000 0.000 0.00 0.00 0.00 0.0000 250.000 0.000 0.0000 250.000 0.000 0.000 0.00 0.00 0.00 0.0000 2,197.328 58.420 200.4255 1,877.025 -852.489 -317.469 3.00 3.00 0.00 0.0000 8,630.691 58.420 200.4255 5,246.118 -5,988.541 -2,230.147 0.00 0.00 0.00 0.0000 12,049.571 90.103 348.0706 7,132.100 -5,325.380 -3,989.673 4.00 0.93 4.35 130.5811 18,748.099 90.103 349.0706 7,120.100 1,251.635 -5,259.709 0.00 0.00 0.00 0.0000 10/6/2005 3:22:27PM Page 2 of 8 COMPASS 2003.11 Build 50 Sperry Drilling Services ConocoPhillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-oMinate Reference: Company: ConocoPhillips Alaska Inc. TVD Reference: Project: Colville River Unit MD Reference: Site:. Alpine CD4 North Reference: Well: Plan: CD4-319 Survey Calculation Method: Wellbore: Plan: CD4-319 Design: CD4-319wp05 • HALLIBURTON Sperry Drilling Services Well Plan: CD4-319 - Sbt 19 Doyon 18 ~ 55.100ft (RKB=55.1 ft above MSL) Doyon 19 ~ 55.100ft (RKB=55.1 ft above MSL) True Minimum Curvature Planned Survey CD4-318wp05 .Map Map. MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting. DISEY Vert Section ifti (°) C) (ft) (ft) (ft) (~) Ift} (~ (°MOOft) (ft)- 36.100 0.000 0.0000 36.100 -19.00 0.000 0.000 5,957,441.8282 377,824.7173 ' 0.00 0.00 SHL; 2973' FNL & 419' FE L; Sec24-T11 N-R04E 100.000 0.000 0.0000 100.000 44.90 0.000 0.000 5,957,441.8282 377,824.7173 0.00 0.00 199.999 0.000 0.0000 199.999 144.90 0.000 0.000 5,957,441.8282 377,824.7173 0.00 0.00 250.000 0.000 0.0000 250.000 194.90 0.000. 0.000 5,957,441.8282 377,824.7173 0.00 0.00 Begin Dir; 3° DLS, 0° TFO , 250' MD, 250' TVD 300.000 1.500 200.4255 299.984 244.88 -0.613 -0.228 5,957,441.2188 377,824.4790 3.00 0.08 400.000 4.500 200.4255 399.846 344.75 -5.517 -2.055 5,957,436.3455 377,822.5734 3.00 0.72 500.000 7.500 200.4255 499.287 444.19 -15.312 -5.702 5,957,426.6124 377,818.7675 3.00 2.00 600.000 10.500 200.4255 598.044 542.94 -29.970 -11.161 5,957,412.0460 377,813.0718 3.00 3.92 700.000 13.500 200.4255 695.848 640.75 -49.452 -18.416 5,957,392.6864 377,805.5017 3.00 6.47 787.154 16.115 200.4255 780.100 725.00 -70.323 -26.189 5,957,371.9456 377,797.3915 3.00 9.20 Base Permafrost 800.000 16.500 200.4255 792.429 737.33 -73.704 -27.447 5,957,368.5865 377,796.0780 3.00 9.64 900.000 19.500 200.4255 887.524 832.42 -102.659 -38.231 5,957,339.8124 377,784.8267 3.00 13.43 1,000.000 22.500 200.4255 980.872 925.77 -136.239 -50.736 5,957,306.4431 377,771.7785 3.00 17.82 1,100.000 25.500 200.4255 1,072.216 1,017.12 -174.351 -64.929 5,957,268.5699 377,756.9692 3.00 22.80 1,200.000 28.500 200.4255 1,161.306 1,106.21 -216.891 -80.771 5,957,226.2967 377,740.4393 3.00 28.37 1,300.000 31.500 200.4255 1,247.899 1,192.80 -263.742 -98.218 5,857,179.7393 377,722.2343 3.00 34.49 1,400.000 34.500 200.4255 1,331.756 1,276.66 -314.776 -117.223 5,957,129.0254 377,702.4038 3.00 41.17 1,500.000 37.500 200.4255 1,412.649 1,357.55 -369.852 -137.734 5,957,074.2939 377,681.0026 3.00 48.37 1,600.000 40.500 200.4255 1,490.354 1,435.25 -428.821 -159.694 5,957,015.6949 377,658.0890 3.00 56.08 1,700.000 43.500 200.4255 1,564.660 1,509.56 -491.520 -183.043 5,956,953.3889 377,633.7259 3.00 64.28 1,800.000 46.500 200.4255 1,635.363 1,580.26 -557.777 -207.718 5,956,887.5468 377,607.9800 3.00 72.95 1,900.000 49.500 200.4255 1,702.268 1,647.17 -627.411 -233.649 5,956,818.3481 377,580.9220 3.00 82.06 2,000.000 52.500 200.4255 1,765.183 1,710.09 -700.231 -260.768 5,956,745.9853 377,552.6261 3.00 91.58 2,100.000 55.500 200.4255 1,823.965 1,768.87 -776.038 -288.998 5,956,670.6539 377,523.1697 3.00 101.49 2,197.328 58.420 200.4255 1,877.025 1,821.93 -852.488 -317.469 5,956,594.6817 377,493.4628 3.00 111.49 Start Sail; 58° INC, 2197 MD, 1877 TVD 2,200.000 58.420 200.4255 1,878.424 1,823.32 -854.622 -318.263 5,956,592.5622 377,492.6340 0.00 111.77 2,300.000 58.420 200.4255 1,930.793 1,875.69 -934.457 -347.994 5,956,513.2279 377,461.6123 0.00 122.21 2,400.000 58.420 200.4255 1,983.162 1,928.06 -1,014.291 -377.725 5,956,433.8935 377,430.5907 0.00 132.65 2,500.000 58.420 200.4255 2,035.532 1,980.43 -1,094.126 -407.455 5,956,354.5592 377,399.5691 0.00 143.09 2,600.000 58.420 200.4255 2,087.901 2,032.80 -1,173.961 -437.186 5,956,275.2249 377,368.5475 0.00 153.53 2,700.000 58.420 200.4255 2,140.270 2,085.17 -1,253.795 -466.916 5,856,195.8906 377,337.5259 0.00 163.88 2,800.000 58.420 200.4255 2,192.639 2,137.54 -1,333.630 -496.647 5,956,116.5563 377,306.5043 0.00 174.42 2,823.795 58.420 200.4255 2,205.100 2,150.00 -1,352.626 -503.721 5,956,087.6787 377,299.1227 0.00 176.90 C-40 2,900.000 58.420 200.4255 2,245.008 2,189.81 -1,413.464 -526.378 5,956,037.2220 377,275.4827 0.00 184.86 3,000.000 58.420 200.4255 2,297.377 2,242.28 -1,493.299 -556.108 5,955,957.8877 377,244.4610 0.00 795.30 3,100.000 58.420 200.4255 2,349.746 2,294.65 -1,573.134 -585.838 5,955,878.5533 377,213.4394 0.00 205.74 3,199.780 58.420 200.4255 2,402.000 2,346.90 -1,652.793 -615.504 5,955,799.3934 377,182.4860 0.00 216.16 9-5/8" Csg Pt; 3199' MD, 2402' TVD - 9 5/8" 3,200.000 58.420 200.4255 2,402.115 2,347.02 -1,652.868 -615.570 5,955,799.2190 377,182.4178 0.00 216.18 3,205.700 58.420 200.4255 2,405.100 2,350.00 -1,657.519 -617.264 5,955,794.6972 377,180.6497 0.00 216.78 C-30 3,300.000 58.420 200.4255 2,454.484 2,399.38 -1,732.803 -645.300 5,955,719.8847 377,151.3962 0.00 226.62 10/6/2005 3:22:27PM Page 3 of 8 COMPASS 2003.11 Build 50 fl~IGINAL ConocoPhillips Alaska .Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. PrgjeCt: Colville River Unit Site: Alpine CD4 Wells Plan: CD4-319 Wellbore: Plan: CD4-319 Design: CD4-319wp05 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: MALLIBURTQN Sperry Drilling Services Well Plan: CD4-319 -Slot 19 Doyon 19 ~ 55.100ft (RKB=55.1 ft above MSL) Doyon 19 ~ 55.100ft (RKB=55.1 ft above MSL) True Minimum Curvature Planned Survey CD4319wp05 Map Map. MD Inclination Azimuth TVD SEND +N/-S +EI•W Northing Fasting DLSEV Vert Section lft) (°) (°) (ft) Ift) (ft) (ft) (ft) (ft) (°/100fU (ft) 3,400.000 58.420 200.4255 2,506.853 2,451.75 -1,812.638 -675.031 5,855,640.5504 377,120.3746 0.00 237.06 3,500.000 58.420 200.4255 2,559.222 2,504.12 -1,882.472 -704.761 5,955,561.2161 377,089.3530 0.00 247.50 3,600.000 58.420 200.4255 2,611.591 2,556.49 -1,972.307 -734.492 5,955,481.8818 377,058.3313 0.00 257.95 3,700.000 58.420 200.4255 2,663.961 2,608.86 -2,052.142 -764.223 5,855,402.5475 377,027.3097 0.00 268.39 3,800.000 58.420 200.4255 2,716.330 2,861.23 -2,131.976 -793.853 5,955,323.2131 376,996.2881 0.00 278.83 3,900.000 58.420 200.4255 2,768.699 2,713.60 -2,211.811 -823.684 5,855,243.8788 376,965.2665 0.00 289.27 3,908.404 58.420 200.4255 2,773.100 2,718.00 -2,218.521 -826.183 5,955,237.2112 376,962.6593 0.00 280.15 C-20 4,000.000 58.420 200.4255 2,821.068 2,765.97 -2,291.646 -853.414 5,955,164.5445 376,934.2449 0.00 299.71 4,100.000 58.420 200.4255 2,873.437 2,818.34 -2,371.480 -883.145 5,855,085.2102 376,903.2233 0.00 310.15 4,200.000 58.420 200.4255 2,925.806 2,870.71 -2,451.315 -812.876 5,955,005.8759 376,872.2016 0.00 320.59 4,300.000 58.420 200.4255 2,978.175 2,923.07 -2,531.149 -942.806 5,954,826.5416 376,841.1800 0.00 331.03 4,400.000 58.420 200.4255 3,030.544 2,975.44 -2,610.984 -972.337 5,954,847.2073 376,810.1584 0.00 341.47 4,500.000 58.420 200.4255 3,082.913 3,027.81 -2,690.819 -1,002.068 5,954,767.8729 376,779.1368 0.00 351.91 4,600.000 58.420 200.4255 3,135.282 3,080.18 -2,770.653 -1,031.788 5,954,688.5386 376,748.1152 0.00 362.36 4,700.000 58.420 200.4255 3,187.651 3,132.55 -2,850.488 -1,061.529 5,954,609.2043 376,717.0936 0.00 372.80 4,800.000 58.420 200.4255 3,240.020 3,184.82 -2,930.323 -1,091.259 5,954,529.8700 376,686.0720 0.00 383.24 4,900.000 58.420 200.4255 3,292.389 3,237.29 -3,010.157 -1,120.990 5,954,450.5357 376,655.0503 0.00 393.68 5,000.000 58.420 200.4255 3,344.759 3,289.66 -3,089.992 -1,150.721 5,954,371.2014 376,624.0287 0.00 404.12 5,100.000. 58.420 200.4255 3,397.128 3,342.03 -3,169.827 -1,180.451 5,954,291.8670 376,593.0071 0.00 414.56 5,200.000 58.420 200.4255 3,449.497 3,394.40 -3,249.661 -1,210.182 5,954,212.5327 376,561.9855 0.00 425.00 5,300.000 58.420 200.4255 3,501.866 3,446.77 -3,329.496 -1,239.912 5,954,133.1884 376,530.9638 0.00 435.44 5,400.000 58.420 200.4255 3,554.235 3,499.13 -3,409.331 -1,269.643 5,954,053.8641 376,499.9423 0.00 445.88 5,500.000 58.420 200.4255 3,606.604 3,551.50 -3,489.165 -1,299.374 5,953,974.5298 376,468.9206 0.00 456.33 5,600.000 58.420 200.4255 3,658.973 3,603.87 -3,568.000 -1,329.104 5,953,895.1955 376,437.8990 0.00 466.77 5,700.000 58.420 200.4255 3,711.342 3,656.24 -3,648.834 -1,358.835 5,953,815.8612 376,406.8774 0.00 477.21 5,800.000 58.420 200.4255 3,763.711 3,708.61 -3,728.669 -1,388.566 5,953,736.5268 376,375.8558 0.00 487.65 5,800.000 58.420 200.4255 3,816.080 3,760.98 -3,808.504 -1,418.286 5,953,657.1925 376,344.8342 0.00 498.09 5,959.233 58.420 200.4255 3,847.100 3,792.00 -3,855.782 -1,435.906 5,953,610.2005 376,326.4592 0.00 504.27 K-3 6,000.000 58.420 200.4255 3,868.449 3,813.35 -3,888.338 -1,448.027 5,953,577.8582 376,313.8126 0.00 508.53 6,100.000 58.420 200.4255 3,820.818 3,865.72 -3,968.173 -1,477.757 5,853,498.5239 376,282.7909 0.00 518.97 6,200.000 58.420 200.4255 3,973.187 3,918.08 -4,048.008 -1,507.488 5,953,419.1896 376,251.7693 0.00 529.41 6,300.000 58.420 200.4255 4,025.557 3,970.46 -4,127.842 -1,537.219 5,953,339.8553 376,220.7477 0.00 539.85 6,377.419 58.420 200.4255 4,066.100 4,011.00 -4,189.649 -1,560.236 .5,953,278.4357 376,196.7312 0.00 547.94 Basal K-3 6,400.000 58.420 200.4255 4,077.926 4,022.83 -4,207.677 -1,566.949 5,953,260.5210 376,189.7261 0.00 550.30 6,449.981 58.420 200.4255 4,104.100 4,049.00 -4,247.579 -1,581.809 5,953,220.8682 376,174.2213 0.00 555.51 K-2 6,500.000 58.420 200.4255 4,130.295 4,075.19 -4,287.512 -1,596.680 5,953,181.1866 376,158.7045 0.00 560.74 6,600.000 58.420 200.4255 4,182.664 4,127.56 -4,367.346 -1,626.411 5,953,101.8523 376,127.6829 0.00 571.18 6,654.300 58.420 200.4255 4,211.100 4,156.00 -4,410.696 -1,642.554 5,953,058.7741 376,110.8383 0.00 576.85 ~ Base K-2 6,700.000 58.420 200.4255 4,235.033 4,179.83 -4,447.181 -1,656.141 5,953,022.5180 376,096.6613 0.00 581.62 6,800.000 58.420 200.4255 4,287.402 4,232.30 -4,527.016 -1,685.872 5,952,943.1837 376,065.6396 0.00 592.06 6,900.000 58.420 200.4255 4,339.771 4,284.67 -4,606.850 -1,715.602 5,952,863.8494 376,034.6180 0.00 802.50 7,000.000 58.420 200.4255 4,392.140 4,337.04 -4,686.685 -1,745.333 5,852,784.5151 376,003.5964 0.00 612.84 7,100.000 58.420 200.4255 4,444.509 4,389.41 -4,766.518 -1,775.064 5,952,705.1808 375,972.5748 0.00 623.38 10/6/2005 3:22:27PM Page 4 of 8 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD4-319 Wellbore: Plan: CD4-319 Design: CD4-319wp05 Sperry Drilling Services Planning Report -Geographic local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: HALLIBURTON Sperry Drilling Services Well Plan: CD4-319 -Slot 19 Doyon 19 (~ 55.100ft (RKB=55.1 ft above MSL) Doyon 19 ~ 55.100ft (RKB=55.1 ft above MSL) True Minimum Curvature Planned Survey CD4-319wp05 .Map Map. MD Inclination Azimuth ND SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (R) (°) (°) (ft) (ft) (ft) (ft) lft) (~) (°l100ft) lft! 7,200.000 58.420 200.4255 4,496.878 4,441.78 -4,846.354 -1,804.794 5,952,625.8464 375,941.5532 0.00 633.82 7,300.000 58.420 200.4255 4,549.247 4,494.15 -4,926.189 -1,834.525 5,952,546.5121 375,910.5316 0.00 844.28 7,400.000 58.420 200.4255 4,601.616 4,546.52 -5,006.023 -1,864.255 5,952,467.1778 375,879.5099 0.00 654.71 7,500.000 58.420 200.4255 4,653.986 4,598.88 -5,085.858 -1,893.986 5,952,387.8435 375,848.4883 0.00 665.15 7,600.000 58.420 200.4255 4,706.355 4,651.25 -5,165.693 -1,923.717 5,952,308.5092 375,817.4667 0.00 675.59 7,700.000 58.420 200.4255 4,758.724 4,703.62 -5,245.527 -1,953.447 5,952,229.1749 375,786.4451 0.00 686.03 7,800.000 58.420 200.4255 4,811.093 4,755.98 -5,325.362 -1,983.178 5,952,149.8406 375,755.4235 0.00 696.47 7,900.000 58.420 200.4255 4,863.462 4,808.36 -5,405.197 -2,012.909 5,952,070.5062 375,724.4019 0.00 706.91 8,000.000 58.420 200.4255 4,915.831 4,860.73 -5,485.031 -2,042.639 5,951,991.1719 375,893.3802 0.00 717.35 8,100.000 58.420 200.4255 4,968.200 4,913.10 -5,564.866 -2,072.370 5,951,911.8376 375,662.3586 0.00 727.79 8,200.000 58.420 200.4255 5,020.569 4,965.47 -5,644.700 -2,102.100 5,951,832.5033 375,831.3370 0.00 738.23 8,300.000 58.420 200.4255 5,072.938 5,017.84 -5,724.535 -2,131.831 5,951,753.1690 375,600.3154 0.00 748.68 8,400.000 58.420 200.4255 5,125.307 5,070.21 -5,804.370 -2,161.562 5,951,673.8347 375,568.2938 0.00 759.12 8,500.000 58.420 200.4255 5,177.676 5,122.58 -5,884.204 -2,191.292 5,951,594.5003 375,538.2722 0.00 769.56 8,600.000 58.420 200.4255 5,230.045 5,174.95 -5,964.039 -2,221.023 5,951,515.1660 375,507.2506 0.00 780.00 8,630.681 58.420 200.4255 5,246.118 5,181.02 -5,988.541 -2,230.147 5,951,480.8178 375,497.7298 0.00 783.20 Begin Dir; 4° DLS, 130° TFO, 8630' MD , 5246' ND 8,700.000 56.642 202.9449 5,283.328 5,228.23 -6,042.873 -2,251.739 5,951,436.8487 375,475.2595 4.00 791.63 8,800.000 54.170 206.7664 5,340.116 5,285.02 -6,117.554 -2,286.292 5,951,362.7448 375,439.5005 4.00 807.96 8,900.000 51.827 210.8269 5,400.312 5,345.21 -6,187.528 -2,324.709 5,951,293.4089 375,399.9551 4.00 829.13 8,000.000 49.633 215.1482 5,463.624 5,408.52 -6,252.458 -2,366.802 5,951,229.1786 375,356.8161 4.00 855.05 9,100.000 47.611 219.7485 5,529.744 5,474.64 -6,312.023 -2,412.366 5,951,170.3669 375,310.2936 4.00 885.58 9,200.000 45.784 224.6386 5,598.350 5,543.25 -6,365.834 -2,481.180 5,951,117.2604 375,260.6143 4.00 920.59 9,300.000 44.178 229.8240 5,669.107 5,614.01 -6,413.929 -2,513.005 5,951,070.1177 375,208.0202 4.00 959.90 9,400.000 42.820 235.2916 5,741.670 5,686.57 -6,455.774 -2,567.589 5,951,029.1686 375,152.7676 4.00 1,003.31 9,500.000 41.735 241.0163 5,815.687 5,760.58 -6,491.266 -2,624.667 5,950,994.6124 375,085.1256 4.00 1,050.82 9,549.963 41.302 243.9622 5,853.100 5,798.00 -6,506.563 -2,654.032 5,850,979.7960 375,065.5180 4.00 1,075.65 Albian 97 9,600.000 40.945 246.9546 5,890.796 5,835.70 -6,520.230 -2,683.959 5,850,866.6177 375,035.3750 4.00 1,101.60 9,700.000 40.469 253.0458 5,966.632 5,911.53 -6,542.527 -2,745.178 5,950,945.3207 374,973.8070 4.00 1,155.89 9,800.000 40.317 259.2156 6,042.825 5,987.72 -6,558.047 -2,808.025 5,950,930.8253 374,810.7214 4.00 1,213.54 9,900.000 40.493 265.3824 6,119.003 6,063.90 -6,566.715 -2,872.194 5,950,923.2020 374,846.4258 4.00 1,273.96 9,996.428 40.971 271.2520 6,192.100 6,137.00 -6,568.544 -2,935.029 5,950,922.3944 374,783.5740 4.00 1,334.66 Albian 96 10,000.000 40.994 271.4645 6,194.797 6,139.70 -6,568.488 -2,937.371 5,950,922.4881 374,781.2332 3.96 1,338.96 10,100.000 41.807 277.3886 6,269.836 6,214.74 -6,563.358 -3,003.241 5,950,928.6868 374,715.4613 4.00 1,402.22 10,200.000 42.913 283.0953 6,343.755 6,288.65 -6,551.352 -3,069.481 5,950,941.7682 374,649.4306 4.00 1,468.44 10,300.000 44.290 288.5424 6,416.193 6,361.09 -6,532.525 -3,135.769 5,950,861.6684 374,583.4627 4.00 1,538.29 10,400.000 45.913 293.7049 6,486.799 6,431.70 -6,506.970 -3,201.782 5,950,888.2905 374,517.8790 4.00 1,608.43 10,500.000 47.756 298.5740 6,555.228 6,500.13 -6,474.812 -3,267.198 5,951,021.5047 374,452.9991 4.00 1,679.51 10,600.000 49.792 303.1527 6,621.146 6,566.05 -6,436.207 -3,331.700 5,951,061.1494 374,389.1389 4.00 1,751.20 10,700.000 51.998 307.4538 6,684.232 6,629.13 -6,391.344 -3,394.972 5,951,107.0312 374,326.6098 4.00 1,823.13 10,800.000 54.352 311.4956 6,744.180 6,688.08 -6,340.440 -3,456.706 5,951,158.9268 374,265.7162 4.00 1,894.98 10,800.000 56.832 315.3000 6,800.696 6,745.60 -6,283.745 -3,516.602 5,951,216.5832 374,206.7549 4.00 1,968.37 10,966.224 58.537 317.7019 6,836.100 6,781.00 -6,243.145 -3,555.112 5,951,257.8005 374,168.9124 4.00 2,013.23 Top HRZ 11,000.000 59.422 318.8906 6,853.506 6,798.41 -6,221.534 -3,574.367 5,951,279.7196 374,150.0131 3.99 2,036.97 11,100.000 62.105 322.2912 6,802.353 6,847.25 -6,154.110 -3,629.720 5,951,348.0283 374,095.7672 4.00 2,106.43 10/6/2005 3:22:27PM Page 5 of 8 COMPASS 2003.11 Build 50 ORIGINAL • ~ ConocoPhillips Alaska :Database: EDM 2003.11 Single User Db .Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD4 Welk Plan: CD4-319 Wellbore: Plan: CD4-319 Design: C04319wp05 Sperry Drilling Services Planning Report -Geographic Local Co-oMinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: HALLIBURTQN Sperry Drilling Services Well Plan: CD4-319 - Sbt 19 Doyon 19 @ 55.100ft (RKB=55.1 ft above MSL) Doyon 19 ~ 55.100ft (RKB=55.1 ft above MSL) True Minimum Curvature Ptanned Survey CD4-318wp05 Map Map MD Inclination Azimuth TVD SS7VD +NlS +EI-W Northing Fasting DLSEY Vert Section (ft) (°) (°) (RI (ft) (R) (R) (ff) (fU (*/100ft) (ft1 11,200.000 64.867 325.5248 6,946.887 6,891.90 -6,081.802 -3,682.392 5,951,421.1767 374,044.2815 4.00 2,174.41 11,300.000 67.697 328.6136 6,987.223 6,932.12 -6,004.963 -3,732.126 5,951,488.8082 373,995.8069 4.00 2,240.58 11,323.736 68.378 329.3292 6,996.100 6,941.00 -5,986.099 -3,743.473 5,951,517.8521 373,984.7694 4.01 2,255.98 Base HRZ 11,400.000 70.582 331.5785 7,022.834 6,967.73 -5,923.965 -3,778.680 5,951,580.5448 373,950.5796 4.00 2,304.62 11,500.000 73.514 334.4392 7,053.655 6,998.56 -5,839.205 -3,821.827 5,851,665.9881 373,908.8197 4.00 2,366.21 11,505.113 73.666 334.5843 7,055.100 7,000.00 -5,834.777 -3,823.937 5,951,670.4493 373,906.7814 4.04 2,369.29 K-1 11,600.000 76.484 337.2139 7,078.539 7,024.44 -5,751.094 -3,861.356 5,951,754.7219 373,870.7310 4.00 2,425.07 11,647.664 77.812 338.5125 7,090.100 7,035.00 -5,708.043 -3,878.867 5,851,798.0487 373,853.9229 4.00 2,452.07 11,687.842 79.119 339.5953 7,098.100 7,043.00 -5,671.272 Kuparuk D 11,700.000 79.483 339.8189 7,100.357 7,045.26 -5,660.063 11,800.000 82.505 342.5737 7,116.009 7,060.91 -5,566.555 11,900.000 85.543 345.1907 7,126.419 7,071.32 -5,471.025 11,923.530 86.260 345.8040 7,128.100 7,073.00 -5,448.303 Kuparuk C 12,000.000 88.589 347.7862 7,131.535 7,076.43 -5,373.938 12,049.000 90.085 349.0558 7,132.101 7,077.00 -5,325.941 7" Csg Pt; 12049' MD, 71 32' TVD; 3020 ' FNL 84409' FEL; Sec25-T1 1 N-R04E - 7" 12,049.571 90.103 349.0706 7,132.100 7,077.00 -5,325.380 Target (Heel); 12049' MD , 7132' TVD -CD4-319wp04 Heel 12,100.000 80.103 349.0706 7,132.010 7,076.81 -5,275.866 12,200.000 90.103 349.0706 7,131.831 7,076.73 -5,177.680 12,300.000 90.103 349.0706 7,131.651 7,076.55 -5,079.494 12,400.000 90.103 349.0706 7,131.472 7,076.37 -4,981.308 12,500.000 90.103 349.0706 7,131.293 7,076.19 -4,883.122 12,600.000 90.103 349.0706 7,131.114 7,076.01 -4,784.936 12,700.000 90.103 349.0706 7,130.935 7,075.83 -4,686.750 12,800.000 90.103 349.0706 7,130.756 7,075.66 -4,588.564 12,900.000 90.103 349.0706 7,130.577 7,075.48 -4,480.378 13,000.000 90.103 349.0706 7,130.397 7,075.30 -4,392.192 13,100.000 90.103 349.0706 7,130.218 7,075.12 -4,284.006 13,200.000 90.103 349.0706 7,130.039 7,074.94 -4,195.820 13,300.000 90.103 348.0706 7,129.860 7,074.76 -4,087.634 13,400.000 90.103 349.0706 7,129.681 7,074.58 -3,999.448 13,500.000 90.103 349.0706 7,129.502 7,074.40 -3,901.262 13,600.000 90.103 349.0706 7,129.323 7,074.22 -3,803.076 13,700.000 90.103 348.0706 7,129.143 7,074.04 -3,704.890 13,800.000 90.103 349.0706 7,128.964 7,073.86 -3,606.704 13,900.000 90.103 348.0706 7,128.785 7,073.69 -3,508.518 14,000.000 90.103 349.0706 7,128.606 7,073.51 -3,410.332 14,100.000 90.103 349.0706 7,128.427 7,073.33 -3,312.146 14,200.000 80.103 349.0706 7,128.248 7,073.15 -3,213.960 14,300.000 90.103 349.0706 7,128.068 7,072.97 -3,115.774 14,400.000 90.103 349.0706 7,127.889 7,072.79 -3,017.588 -3,892.942 5,851,835.0403 373,840.4490 4.00 2,474.27 -3,897.075 5,851,846.3140 373,836.4887 3.98 2,480.89 -3,828.810 5,951,940.3180 373,806.2899 4.00 2,533.41 -3,956.407 5,952,036.2761 373,780.2516 4.00 2,582.37 -3,962.284 5,952,059.0884 373,774.7451 4.01 2,593.35 -3,979.731 5,952,133.7206 373,758.5106 4.00 2,627.54 -3,989.564 5,952,181.8674 373,749.4592 4.00 2,648.22 -3,889.673 5,952,182.4300 373,749.3600 4.00 2,648.45 -3,998.234 5,952,232.0887 373,740.8055 0.00 2,668.22 -4,018.194 5,852,330.5616 373,723.2452 0.00 2,710.39 -4,037.154 5,952,429.0346 373,705.8850 0.00 2,751.57 -4,056.114 5,952,527.5076 373,688.5248 0.00 2,792.74 -4,075.074 5,952,625.9806 373,671.1645 0.00 2,833.92 -4,094.034 5,852,724.4536 373,653.8043 0.00 2,875.09 -4,112.994 5,952,822.9266 373,636.4441 0.00 2,916.27 -4,131.954 5,952,921.3996 373,619.0838 0.00 2,957.44 -4,150.913 5,953,019.8726 373,601.7236 0.00 2,998.62 -4,169.873 5,953,118.3455 373,584.3634 0.00 3,039.79 -4,188.833 5,953,216.8185 373,567.0031 0.00 3,080.97 -4,207.783 5,953,315.2915 373,549.6429 0.00 3,122.14 -4,226.753 5,953,413.7645 373,532.2827 0.00 3,163.32 -4,245.713 5,953,512.2375 373,514.9224 0.00 3,204.49 -4,264.673 5,953,610.7105 373,497.5622 0.00 3,245.67 -4,283.633 5,953,709.1835 373,480.2020 0.00 3,286.84 -4,302.593 5,953,807.6565 373,462.8417 0.00 3,328.02 -4,321.553 5,853,906.1284 373,445.4815 0.00 3,368.19 -4,340.513 5,954,004.6024 373,428.1213 0.00 3,410.37 -4,359.473 5,854,103.0754 373,410.7610 0.00 3,451.54 -4,378.433 5,954,201.5484 373,393.4008 0.00 3,482.72 -4,397.393 5,954,300.0214 373,376.0406 0.00 3,533.90 -4,416.353 5,854,398.4944 373,358.6803 0.00 3,575.07 -4,435.312 5,954,496.9674 373,341.3201 0.00 3,616.25 10/6/2005 3:22:27PM Page 6 of 8 COMPASS 2003.11 Build 50 n~;r,INAL • ConocoPhillips Alaska :Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. .Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD4-318 Welltlore: Plan: CD4-319 Design: CD4-319wp05 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: HALLIBURTQN Sperry Drilling Services Well Plan: CD4-318 - Sbt 19 Doyon 19 cQ 55.100ft (RK6=55.1 ft above MSL) Doyon 19 ~ 55.100ft (RK6=55.1 ft above MSL) True Minimum Curvature Planned Survey CD4-319wp05 Map Nlep MD Inclination Azimuth ND SSTVD +N/S +E/.W Northing Fasting DLSEV Vert Section (ft) (°) (°) {ftl (ft) (ft) (ft) (~) lftl {°l100ft) (ftl 14,500.000 90.103 349.0706 7,127.710 7,072.61 -2,919.402 -4,454.272 5,954,595.4404 373,323.9598 0.00 3,657.42 14,600.000 90.103 349.0706 7,127.531 7,072.43 -2,821.216 -4,473.232 5,954,693.9133 373,306.5986 0.00 3,688.60 14,700.000 90.103 349.0706 7,127.352 7,072.25 -2,723.030 -4,492.192 5,954,792.3863 373,289.2394 0.00 3,739.77 14,800.000 90.103 349.0706 7,127.173 7,072.07 -2,624.844 -4,511.152 5,954,890.8583 373,271.8792 0.00 3,780.95 14,900.000 90.103 348.0706 7,126.994 7,071.89 -2,526.658 -4,530.112 5,954,989.3323 373,254.5189 0.00 3,822.12 15,000.000 90.103 348.0706 7,126.814 7,071.71 -2,428.472 -4,548.072 5,955,087.8053 373,237.1587 0.00 3,863.30 15,100.000 80.103 349.0706 7,126.635 7,071.54 -2,330.286 -4,568.032 5,955,186.2783 373,219.7884 0.00 3,904.47 15,200.000 90.103 349.0706 7,126.456 7,071.36 -2,232.100 -4,586.992 5,955,284.7513 373,202.4382 0.00 3,945.65 15,300.000 90.103 348.0706 7,126.277 7,071.18 -2,133.914 -4,605.952 5,955,383.2242 373,185.0780 0.00 3,986.82 15,400.000 90.103 349.0706 7,126.098 7,071.00 -2,035.728 -4,624.812 5,955,481.6972 373,167.7177 0.00 4,028.00 15,500.000 90.103 349.0706 7,125.918 7,070.82 -1,937.542 -4,643.872 5,955,580.1702 373,150.3575 0.00 4,069.17 15,600.000 90.103 348.0706 7,125.740 7,070.64 -1,839.356 -4,662.832 5,955,678.6432 373,132.8973 0.00 4,110.35 15,700.000 90.103 349.0706 7,125.560 7,070.46 -1,741.170 -4,681.792 5,855,777.1162 373,115.6370 0.00 4,151.52 15,800.000 90.103 349.0706 7,125.381 7,070.28 -1,642.984 -4,700.752 5,955,875.5892 373,098.2768 0.00 4,192.70 15,900.000 90.103 348.0706 7,125.202 7,070.10 -1,544.788 -4,719.711 5,955,974.0622 373,080.9166 0.00 4,233.87 16,000.000 90.103 349.0706 7,125.023 7,069.92 -1,446.612 -4,738.671 5,956,072.5352 373,063.5563 0.00 4,275.05 16,100.000 90.103 349.0706 7,124.844 7,069.74 -1,348.426 -4,757.631 5,956,171.0081 373,046.1961 0.00 4,316.22 16,200.000 90.103 349.0706 7,124.665 7,069.56 -1,250.241 -4,776.591 5,956,269.4811 373,028.8359 0.00 4,357.40 16,300.000 90.103 349.0706 7,124.486 7,069.39 -1,152.055 -4,795.551 5,956,367.9541 373,011.4756 0.00 4,398.57 16,400.000 90.103 349.0706 7,124.306 7,069.21 -1,053.869 -4,814.511 5,956,466.4271 372,984.1154 0.00 4,439.75 16,500.000 80.103 349.0706 7,124.127 7,069.03 -955.683 -4,833.471 5,956,564.9001 372,976.7552 0.00 4,480.92 16,600.000 90.103 349.0706 7,123.948 7,068.85 -857.487 -4,852.431 5,956,663.3731 372,959.3949 0.00 4,522.10 16,700.000 90.103 349.0706 7,123.769 7,068.67 -759.311 -4,871.391 5,856,761.8461 372,942.0347 0.00 4,563.27 16,800.000 90.103 349.0706 7,123.590 7,068.49 -661.125 -4,890.351 5,956,860.3191 372,824.6745 0.00 4,604.45 16,900.000 90.103 349.0706 7,123.411 7,068.31 -562.939 -4,909.311 5,956,958.7920 372,907.3142 0.00 4,645.82 17,000.000 90.103 349.0706 7,123.232 7,068.13 -464.753 -4,928.271 5,957,057.2650 372,888.9540 0.00 4,686.80 17,100.000 80.103 349.0706 7,123.052 7,067.95 -366.567 -4,947.231 5,957,155.7380 372,872.5938 0.00 4,727.87 17,200.000 90.103 348.0706 7,122.873 7,067.77 -268.381 -4,966.191 5,957,254.2110 372,855.2335 0.00 4,769.15 17,300.000 90.103 349.0706 7,122.694 7,067.59 -170.195 -4,885.151 5,957,352.6840 372,837.8733 0.00 4,810.33 17,400.000 90.103 349.0706 7,122.515 7,067.42 -72.009 -5,004.111 5,957,451.1570 372,820.5131 0.00 4,851.50 17,500.000 90.103 349.0706 7,122.336 7,067.24 26.177 -5,023.070 5,957,549.6300 372,803.1528 0.00 4,892.68 17,600.000 90.103 349.0706 7,122.157 7,067.06 124.363 -5,042.030 5,857,648.1030 372,785.7926 0.00 4,933.85 17,700.000 90.103 349.0706 7,121.978 7,068.88 222.549 -5,060.990 5,957,746.5759 372,768.4324 0.00 4,975.03 17,800.000 90.103 349.0706 7,121.798 7,066.70 320.735 -5,079.950 5,957,845.0489 372,751.0721 0.00 5,016.20 17,800.000 80.103 349.0706 7,121.619 7,066.52 418.921 -5,098.910 5,957,943.5219 372,733.7119 0.00 5,057.38 18,000.000 90.103 349.0706 7,121.440 7,066.34 517.107 -5,117.870 5,858,041.9949 372,716.3517 0.00 5,098.55 18,100.000 90.103 349.0706 7,121.261 7,066.16 615.293 -5,136.830 5,958,140.4679 372,698.9914 0.00 5,139.73 18,200.000 90.103 349.0706 7,121.082 7,065.98 713.478 -5,155.790 5,958,238.9409 372,681.6312 0.00 5,180.90 18,300.000 90.103 349.0706 7,120.903 7,065.80 811.865 -5,174.750 5,958,337.4139 372,664.2710 0.00 5,222.08 18,400.000 90.103 349.0706 7,120.724 7,065.62 809.851 -5,193.710 5,958,435.8869 372,646.8107 0.00 5,263.25 18,500.000 90.103 348.0706 7,120.544 7,065.44 1,008.037 -5,212.670 5,958,534.3598 372,629.5505 0.00 5,304.43 18,600.000 90.103 349.0706 7,120.365 7,065.27 1,106.223 -5,231.630 5,958,632.8328 372,612.1903 0.00 5,345.60 18,700.000 90.103 349.0706 7,120.186 7,065.09 1,204.409 -5,250.590 5,958,731.3058 372,594.8300 0.00 5,386.78 18,748.098 90.103 349.0706 7,120.100 7,065.00 1,251.635 -5,259.709 5,958,778.6700 372,586.4800 0.00 5,406.58 „ Target (Toe); 18748' MD, 7120' TVD, 1723' FNL $ 398' FEL; Sec23-T11 N-R04E - 4 1/2" -CD4-319wp04 Toe r 10/6/2005 3:22:27PM Page 7 of 8 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhillips Alaska :Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. `Project: Colville River Unit Site;. Alpine CD4 Well: Plan: CD4-318 Wellbore: Plan: CD4-319 Design: CD4-319wp05 Sperry Drilling Services Planning Report -Geographic focal Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: HALLIBURTON Sperry Drilling Ssrvices Well Plan: C04-318 - Sbt 18 Doyon 19 @ 55.100ft (RKB=55.1 ft above MSL) Doyon 19 (~ 55.100ft (RKB=55.1 ft above MSL) True Minimum Curvature Geologic Targets Plan: CD4-319 TVD Target Name +NI-S tE/-W Northing Fasting ~ (ft) -Shape ft ft (fq (ft) 7,132.100 CD4-319wp04 Heel -5,325.380 -3,989.673 5,952,182.4300 373,749.3600 - Point 7,120.100 CD4-319wp04 Toe 1,251.635 -5,258.709 5,958,778.6700 372,586.4800 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) lft) 1'7 ("1 3,199.780 2,402.000 9-518 12-114 12,049.000 7,132.101 7 8-1/2 18,748.098 7,120.100 4-1 /2 6-1/8 Prognosed Formation intersectbn Points __ Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) l°) (°) (ftl lftl (fq Narne 787.154 16.11 200.43 780.100 -70.32 -26.19 Base Permafrost 2,823.795 58.42 200.43 2,205.100 -1,352.63 -503.72 C-40 3,205.700 58.42 200.43 2,405.100 -1,657.52 -617.26 C-30 3,908.404 58.42 200.43 2,773.100 -2,218.52 -826.18 C-20 5,959.233 58.42 200.43 3,847.100 -3,855.79 -1,435.91 K-3 6,377.419 58.42 200.43 4,066.100 -4,189.65 -1,560.24 Basal K-3 6,449.981 58.42 200.43 4,104.100 -4,247.58 -1,581.81 K-2 6,654.300 58.42 200.43 4,211.100 -4,410.70 -1,642.55 Base K-2 9,549.963 41.30 243.96 5,853.100 -6,506.56 -2,654.03 Albian 97 9,996.428 40.87 271.25 6,192.100 -6,568.54 -2,935.03 Albian 96 10,966.224 58.54 317.70 6,836.100 -6,243.14 -3,555.11 Top HR2 11,323.736 68.38 329.33 6,986.100 -5,986.10 -3,743.47 Base HRZ 11,505.113 73.67 334.58 7,055.100 -5,834.78 -3,823.94 K-1 11,687.842 78.12 339.60 7,098.100 -5,671.27 -3,892.94 Kuparuk D 11,923.530 86.26 345.80 7,128.100 -5,448.30 -3,862.28 Kuparuk C 7,138.100 LC U 10/6/2005 3:22:27PM Page 8 of 8 COMPASS 2003.11 Build 50 ~~w~~ • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD4 Plan: CD4-319 Plan: CD4-319 CD4-319wp05 Anticollision Report 06 October, 2005 HALLIBURTON sperlry Dritling ~elrvices ORIGINAL J z r- ConacoPhillips A4rka HALLIBUFITON Sperry Drilling 8srviue s. o+e~. Plrn: tD1-IIt Pbn_C9LI16 ~%,~y yy ~'~ anew hw VIan: CU4)A cows ~ Hr~[.ru plrn'.CW-TII ( P1n:CW-21J ,~ \ J30 ~ , ~ ~ van: rnwns vm: waw y __, ~~Y~-. 1 - r i ~X ~ \ ~ /~ _ \ ~ M:CpLNitlt ~ Yw `i ~1 - ~ a'. ~ c ~ n:ca-m - 1 ~~ j ~~ -S, app ~ *~~ -~ ° 1 ~ 1 I ~ , . ~ ~ X-S- _1 ~ ,i ~ r;, ~ i j - ~-1 -' :An 1 .aim ~ T ~; T: 1 sr\ \ ~~5 55 y- '~f., ~~ • ~ 270 ~ ~ .; ~' 80 1 1 ~ 120 \ ~. \ \ \ 180 2Jp . 2(10 MO 320 210 ~ 150 - - _ J00 180 1 revellin; (~~IinJer :\:im olh (TFO+AZp ~°~ Ts Centre to Centre Separation ~~(Un~ Fran Cebur To MO - - n amc-er - ~.~~. ~ -rxm -,es, e , ,- '- -ri5u K~O~¢~5 -~ - ~i~'S0 .; - :,V.Y ':~;; •)550~Y~ .. ]5)SfMd a~+~1 ~d500 f..5 -f]3[.t X50-~tl5C0215e--E6tl vas. cp+xo9 vr°: coazlo s Critical Issues: 10' to tolerance line of CD4-320wp04 @ 400' 7' to tolerance line of CD4-217wp02 ~ 675' ~ 15' to tolerance line of CD4-217wp02 @ 800' TraS Aline (\ lie Orr ~\rimulh ITF()+_\LII °~ ° ~ C cnlrc In ('rnlrr ~rlrJ reline ~ ft in' SECTION DETAILS Sa MD for Ari TVD +N/-S +Fj-W DLeA TFrce VSee Trr8e1 I x.lpo o.aoo o.aooo x.lao o.ooo a.aoo p.oo o.olMp a.opu T Tsp.otlp o.aoo o.oooo no.ooo o.ooo poop o.oo o.oaM p.opo 3 TI9].3TA Stl.JTO IOII.J2<5 IM7.035 ASI.Jtl9 -31iA69 J.00 O.MNM IIlA9T J 8630.691 Stl.JTII 2011.J255 52J6.1IA -59tltl,x1 -22JO.IJ7 11.00 O.MNM 183.203 5 12019.J71 911.103 x9.11]116 1132.100 -5315.380 J9X9.673 J.00 110.5X11 26JSA53 CDJ•319np01 Hnl 6 I87J8.099 9U.I03 x9.0"U6 ]110.100 IT51.6}r .52r9.iU9 U.00 O.OOIM tJ06.5A2 CDIJ 19w pU./Ta 10/6/2005 3:16 PM ,~ ! ConocoPhillips Alaska Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Reference Site: Alpine CD4 Site Errors O.000ft Reference Well: Plan: CD4-319 Well Error: O.000ft Referents Wellbore Plan: CD4-319 Reference Design: CD4319wp05 Sperry Drilling Services Anticollision Report Local Co-oMinate Reference: Tt!D Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset 7YD Reference: • HALLIBURTON Sperry Drilling Services Well Plan: CD4-319 -Slot 19 Doyon 19 ~ 55.100ft (RKB=55.1 ft above MSL) Doyon 19 ~ 55.100ft (RKB=55.1 ft above MSL) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum CD4-319wp05 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.000ft Error Model: Depth Range: Unlimited Scan Method: Results Limited by: Maximum center-center distance of 5,000.OOOft Error Surface: Warning Levels evaluated at: 0.00 Sigma ISCWSA Trav. Cylinder North Elliptical Conic Survey Tool Program Date 1 0 /812 0 0 5 From To (ft) (ft) Survey (Wellbore) Tool Name Description 36.100 850.000 CD4-319wp05 (Plan: CD4-319) CB-GYRO-SS Camera based gyro single shot 850.000 18,748.099 CD4-319wp05 (Plan: CD4-319) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning -Site Name Depth Depth Distance ((t) from Plan Offset Well -Wellbore- Design lff}. (ft) tff) (ff) Alpine CD4 Nanuq 3 -Nanuq 3 -Nanuq 3 601.588 575.000 156.772 10.69 146.274 Pass -Major Risk Nanuq 5 -Nanuq 5 -Nanuq 5 252.291 250.000 141.649 4.63 137.022 Pass -Major Risk Plan: CD4-208 -Plan: CD4-208 -CD4-208 (wp04) 320.328 325.000 220.809 6.58 214.220 Pass -Major Risk Plan: CD4-209 -Plan: CD4-209 -CD4-209 (wp05) 320.724 325.000 200.813 6.60 194.218 Pass -Major Risk Plan: CD4-210 -Plan: CD4-210 -CD4-210 (wp04) 321.125 325.000 180.816 6.60 174.214 Pass -Major Risk Plan: CD4-211 -Plan: CD4-211 -CD4-211 (wp04) 321.531 325.000 160.811 6.61 154.203 Pass -Major Risk Plan: CD4-212 -Nanuq 5 -Nanuq 5 252.291 250.000 141.649 4.63 137.022 Pass -Major Risk Plan: CD4-212 -Plan: CD4-212 -CD4-212 (wp04) 252.291 250.000 141.649 4.66 136.995 Pass -Major Risk Plan: CD4-213 -Plan: CD4-213 -CD4-213 (wp03) 1,734.577 1,799.993 94.094 41.87 61.804 Pass -Major Risk Plan: CD4-214 -Plan: CD4-214 -CD4-214 (wp03) 322.777 325.000 100.830 6.63 94.203 Pass -Major Risk Plan: CD4-215 -Plan: CD4-215 -CD4-215 (wp03) 878.009 899.996 74.387 18.41 55.896 Pass -Major Risk Plan: CD4-216 -Plan: CD4-216 -CD4-216 (wp03) 323.625 325.000 60.889 6.64 54.248 Pass -Major Risk Plan: CD4-217 -Plan: CD4-217 -CD4-217 (wp02) 668.905 675.000 20.986 14.53 6.809 Pass -Major Risk Plan: CD4-318 (Horizontal) -Plan: CD4-318 -CD4 324.494 325.000 20.803 6.80 14.002 Pass -Major Risk Plan: CD4-318 (Horizontal) -Plan: CD4-318PB1 - CD 324.494 325.000 20.803 6.80 14.002 Pass -Major Risk Plan: CD4-320 (Horizontal) -Plan: CD4-320 -CD4 400.423 399.998 18.587 8.45 10.140 Pass -Major Risk Prelim: CD4-227 -Nanuq 3 -Nanuq 3 601.598 575.000 156.772 10.69 146.274 Pass -Major Risk Alpine Satellites Nanuk 2 -Nanuk 2 -Nanuk 2 4,360.403 2,850.000 780.883 108.12 693.758 Pass -Major Risk Nanuq 3 -Nanuq 3 -Nanuq 3 601.578 575.000 156.718 10.69 146.221 Pass -Major Risk Nanuq 5 -Nanuq 5 -Nanuq 5 252.291 250.000 141.648 4.55 137.096 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 10/6/2005 3:09:15PM Page 2 of 2 COMPASS 2003.11 Build 50 ~~~~ ~, ~an: CD4-319wp05 (Plan: CD4-319/Plan~4-319) Measwecl Depth [ft] - CD4-319wp05 CD2-37, CD2-37, CD2-37 V I7 CD2b0, CD21i0, CD260 Rig Surve95 v't Nanuk 2, Nanuk 2, Nar~uk 2 VO Nanuq 3, Narup 3, N~luq 3 VO - Na,mq 3, Nanuq 3, Nanuq 3 VO Nanuq 5, Nanuq 5, Nanuq 5 VO Nantq 5, Nanuq 5, Nanuq 5 VO ~ Plan: CD4-208, Plan: CD4-208, CDN+2ER(wp(RIyV~D4-209, Plan: CD47A9, CD4-209 (wp05) V Plan: ClY!-210, Plan: CD4-210, CD4+2tbCwpQ4~C~D4-21 I, Plan: CD421 I, CD4'~a~p0~1~VQ'D4-212, Nanuq 5, Nanuq 5 V~ Plan: CD4-212, Plan: CD4-212, CDMtri(wp~l~l~D4-213, Plan: CD4-213, CD4-213 (wp03) V Plyr. CD4214, Plan: CD4214, CD4y2t4~wp(0)u1(~D4-215, Plan: CD4215, CD44t7Ywp(ljlul[eD4-216, Plan: CD4-216, CD4~tldtwplOa~~DL217, Plan: CD4-217, CD4•itl~wp®~+(~DO-318 (HorizonFal), Plan: CD4-318, CD4-3 Plan: CD43 i 8 (Horizanal), Plan CCi~Mt8PBR44iix4F7488B I WpdBdAfiq, Plan: CO~L729, ~ Natiuq 3, Nanuq 3 VO GINAI W91BOf~ TARGEr DETPIS pAAP CO~OrdN4TFS7 ~/ COflOCO ( ~ 5 P ~~' m~ttn,.na.~.r,. ~~ ts~ ~"^tO"v° r""~~idr NOrMi Project: Colville River Unit ~~ CD4 Pad 15000 Cide TVD 0.000 +WS 0.002 +FJ-W Nortltirtg 0.003 58574118300 Fastlng 377824.7200 Shape Cite Radius: 15000.000 I I .,r ~ e.~,e Site: a ine CD4 P CDL319wp03 Fleel 7090.100 E014ffi5 X856540 X51490.9700 3738712000 PoiK ?ti :aka y m ~cofa~ ~~ ~ Well: Pldn: CD4319 CD4J19wp04Toe 7120.100 1251.635 5259.709 58587788700 372566A800 Poiu . Wellbore: Plan: CD4-319 ceaal9wposToecNCie 71zo.tao 12s1.63s 52s9.7o9 ses677sc7ao 372sesneoo c:cielrrad~,s:13zo.oool CD4J19wp03 Toe 7132100 -122.942 4994273 5957400A750 3728295210 Poirt - CD4J19.vp04 Fleel 7132100 5325.380 3969.673 5952782A300 373749.3600 PoFt HALLIBURTON ,.~~a i ~~oi to Iwo ~~~~ RKe ow~„9,=ss,t~t~~xe-ss,nano.e•a, Plan: CD4-319Wp05 coo-319„1waH~c:~~ 713z1oo s3zs.36o -3989.673 5952182.4300 373749.3600 c~r~~IR~i~s:l3zo.oool 4onhing~ASP Y: `A57d61.8282 Sperry Drilling Services Eastine'ASP%: 377624.7173 ANNOTATK)NS No annotation details fall on the welltbre. n. stn. 56' 9Ne r 7 ~ 4trz C O O O N t L O Z t 7 O -1000Q -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 West(-)/East(+) (2000 Win) 'O Spatial Calculator .~ Toe CD4-319wp05 ~° Toe CD2-60 Displacement (ft) 2-D Closure Angle (deg from True North) 2-D Closure Distance (ft in horizontal plane) 3-D Distance (ft) Coords. -ASP Subsea Lat. (Y) Dep. (X) (ft) 5958778.67 372586.48. 7120.00 5959048.60 371542.08 7376.00 N 252.92 NW 283.56 1078.72 11.08.68 W C] Spatial Calculator Page 1 of 1 (CD4-319wp05 Spatial Calculator.xls) 10/6/2005 3:20 PM Re: FW: CD4-319 • • Subject: fZe: FW: CL~--I- I ~~ From: Tl~umas ~laun~ler ~~tom maun~cr~~r ~~dmin.state.ak.us> Date: Sri, 1-4 Oct ~r~(i; 1 ~:51:~)_~ ~1ti(Jil To: "~,~oel. ~3rian" <~E3riai~.'~~~~cli~r con~cohhillir~s.~i~m., C'C: ",fohn~c~n, Vern" ~ ~'ern.I~~hmvnrueonocophi~G~~s.com.=~ Thanks Brian. Putting the "rectangle" in will help. That is something I do myself when I review the plots. It is important to look for anything that penetrates within 1/4 mile of the well's trajectory. Tom Maunder, PE AOGCC Noel, Brian wrote, On 10/14/2005 1:41 PM: Tom - Vern is out today, but here are the requested plots and an explanation on "distance to nearest well within the pool" mistake. To correct this oversight, future CD4 1/4 mile plots will depict the circles with a rectangle along the wellbore and show all wells. Spoke with our directional planner and be assured there wasn't a problem with any of the "anti-collision scans" done for drilling the proposed plan. Let us know if you need further information - Brian -----Original Message----- From: Potnis, Brij P Sent: Friday, October 14, 2005 10:23 AM To: Johnson, Vern Cc: Noel, Brian Subject: RE: CD4-319 Vern, Brian, The corrected plots are attached to this email. The incorrect close approach scan type that was originally used resulted in the higher number denoting the separation. Each scan type (traveling cylinder north, 3-d minimum distance and horizontal scan) has it's limiting cases and to correct this in the future I will be utilizing at least two different scan types and comparing results. However that issue is separate from why Nanuq 3 was excluded from the 1/4 mile radius plot. It was not the scan that failed, it was oversight on my behalf that ended up with Nanuq 3 being excluded from the 1/4 mile radius plot. In my attempt to make the plot a little easier to read I tried to exclude other wells that did not fall in the production/injection 1/4 mile zone, and Nanuq 3 slipped through by mistake. To avoid such a lapse in the future I intend to not exclude any wells in the plots, that way the plot will always be complete. Let me know if there are any other suggestions you have. Thanks and regards, Brij Potnis Well Design Sperry Drilling Services 1 of 4 10/17/2005 12:44 PM Re: FW: CD4-319 • • ConocoPhillips, ATO 1554 (907) 263-4104 Direct (907) 250-0132 Mobile -----Original Message----- From: Johnson, Vern Sent: Thursday, October 13, 2005 3:00 PM To: Potnis, Brij P Cc: Noel, Brian Subject: Fw: CD4-319 Brij, Could you please provide a more detailed explanation than the one I originally offered. Also, please forward the plot requested below to Brian and I. Vern -----Original Message----- From: Thomas Maunder [mai.'..to:tom rr~aur7.der..~ad.rcii.n.state.a.k.us Sent: Thursday, October 13, 2005 1:53 PM To: Johnson, Vern Cc: Steve Davies; Noel, Brian Subject: Re: CD4-319 Vern, Thanks for your reply. One request, could you please resubmit the "1/4 mile" information with Nanuq 3 included. It is surprising that the scanning process appears to have failed. Good that there are so few wells in the immediate area that this omission was discovered. If you don't mind, what "failed" in this instance?? Thanks much, Tom Maunder, PE AOGCC Johnson, Vern wrote, On 10/12/2005 4:24 PM: Tom, In answer to your questions I have listed the answers below. 1. You are correct, the distance to Nanuq 3 within the pool is closer than 1929'. An incorrect close approach scanning technique was originally used, yielding the higher number. The correct horizontal distance between the wells (CD4-319 and Nanuq 3) within the pool is 409'. 2. We currently plan on rigging up and testing a diverter for surface hole on CD4-319, as you suggest, we may apply for a waiver after we get more drilling history on the pad. 3. See attached email from Doug Knock, CD4 Geologist. Vern, The K-2 interval in the CD4 area is penetrated by the 4 Nanuq wells. Nanuk #1 is a straight hole less than 2000 feet from the pad. None of these wells meet the log cutoff criteria we have been using to identify 'significant hydrocarbon accumulations' in the K-2 interval at CD1 and CD2. These criteria are ten feet of sand with deep resistivity greater 2 of 4 10/17/2005 12:44 PM Re: FW: CD4-319 • • ', than 14 ohmms. We recently acquired core data across the K-2 interval in CD2-11. We are still evaluating this data and will not have significant core analysis results for about another month. Log analysis suggests the K-2 interval is shalier and of lower resistivity in the CD4 area as compared to CD1 or CD2. I suggest we evaluate each CD4 well using the criteria set up for CD1 and CD2 until we have developed a new log model tied to the CD2-11 core. Doug 4. Steve Davies requested further information regarding the planned pulse test; the well from which we expect to observe the pulse is CD4-318. This is the third well in this year's CD4 drilling program. We expect to spud CD4-318 in mid December, 2005. 5. Steve also asked about the planned flowback. we expect to flow back +/- 2500 bbl of fluid, 400-500 bbl of mud/brine, and +/- 2000 bbl of oil. The flowback will serve two purposes; obtain a representative reservoir sample, and lift off as much of the filter cake as feasible. Let me know if you have any further questions. Vern Johnson -----Original Message----- From: Thomas Maunder [mailt.o:t::om mat~nder~~admin.state.ak.us Sent: Wednesday, October 12, 2005 11:21 AM To: Johnson, Vern Cc: Noel, Brian; Alvord, Chip; Steve Davies Subject: CD4-319 Vern, Just starting to look at this application and I have a couple of questions. 1. On the 401, it is stated that Nanuq 3 is 1929' distant in the pool. By this statement it is beyond the 1/4 mile, however I would have thought it would have shown in the plot given the area of the plot. 2. There is no mention of a diverter waiver for CD4. I don't know if the prior wells had a diverter or not. A diverter might be necessary for the first couple of wells and then you can make application with sufficient information to exclude the diverter. You might have sufficient information to make that application now, I don't know. Unless you can provide information otherwise, a diverter will likely be required. 3. Nothing is mentioned about the K-2 "reservoir". In all the 3 of4 10/17/2005 12:44 PM Re: FW: CD4-319 • ', exploration wells, this zone was cemented and I understand a core was ', just obtained out of one of the Alpine wells. What is the status of the K-2? You might check with Jack Walker on this one. Thanks in advance, Tom Maunder, PE AOGCC 4 of 4 10/I7/2005 12:44 PM ~,,,,,,,,,,,,,,,,,,,,,,,,M,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,.,m,,,.,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,..,,,,,,a,,,,.,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, ~ ~~n~~QP~~II~~~ : 5~~~~8 6wrsys0ea~~'~ I Project: Colville RiverUni i ~~^~ a~rc~ ~d u ~ ~ Site: Alpine CD4 •~I-;-:.., t ~°ru` ~~"n° wla ' c~ Well: Plan: CD4-319 Wellbore: Plan: CD4-319 ~~ALL1~3L36~°i-D141 . . ~ ->10vY 1Ra6rsoeidSLJ ~ Plan: CD4319wp05 3 :.¢tfug. .. .~ :,8402 ;Sperry Drilling Services `.~' ~r x 5rmza717s 4000 ~pe1 l ~1 2ogl G~ _. TVD MD Arutotaton 56.109 55.988 SHL~ 297]' FNL$ dig' FEi~ Sce24-T11MiEp9E 250.800 250.908 9egin Dir, S° DCS, 0` TPO, 2513' MD, 258' 1VD 1877.025 2197.326 Start Sail; S8° INC, 2197' MD, 1577° TVD 24D2.808 3199.780 9fit8" Csg Pt, 5199` MD, 2402' TVD 5246.118 8650.691 Begin Dir; d' DLS, t50° TF4, 8538' MD, 5245' ND 7132.10112049.080 T' CSg Pt; t2049' MD, 7132' ND; 5028' FNl $4409' FEI; Sec25-T71N-R04E 7132.10812849.571 TargBt (Hee3); 12049' MD, 7152' TVD 7T 26.18018748.099 Tart {Tce); 18748' MD, 7120' 7VD, 1723` FNt $ 398' FEL; 5ec23-T11N4Y04E CASNG[IEfAlS C 2000 ~ 0 O O 0 N L r 0 Z t -2000 3 O N r o~rrs1 ~~ ~iDiYSC [Y °Y~$ 4~f-$~( 1~®£tf'61fN,2 ~8°SfSR'RJ ~18PC C,.Ci4 Pact 1 C t1.00R D.t~2 0.3 5957-041.83t3D 37T$24.72tKt Cireie {ic_1s:15aBi%t,~1Q) 'CB4319wpfl3Hee1 7P30.1~ E+~1'14.825 ,3S56.SdD 5961A~.9TQD 373871.2 Poird Ct'~319saPFklToe 7120.1E'~ 1~1.E35 -5Z'r~.709 5'}S87P8.57IXY S Poir~ '~C1b§~319nptAlToei'~rcle 71N}.1fkt 1251.6 ~s259.709 S95E3778.67£R9 3 Ci€cib:(Itat3iu5:132QfiIX1j ,t.~-31gv~f33Tc+e 7132.1fq -1?.2.tid2 6&eT.4IXap7Sp 37;52.4.&210 Po~ft '. ~::LkR319wp4d Heel 71321 W -53 -3573 58521 3737Q4.3 Point ~~ ~~ iisii~ 5 7 U , 35, 6 3 zi i~ t a~ { .ocmg arrnTx~s tb lVD 6fl Nape Sia 7 xmn6o x198760 858' sae x nssut 12ana66 r 7 3 7120.106 iWNDN 1 t2' 412 ~® ~C~~~~ -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 West(-East(+) (2000 ftlin) ~~nOC~7~~11~~f~5 . r~Js:,;r::1 s Sperry Drilling Services Nance CU4 Pad 150130 Circle Ctk6.319wp63 Heal CD i-319twpOM1 Tae G8~4-319wpo4 Toe Circle CCW-319v4aC#3 Tae Ct34.319w#a64 Hee! CtA4-319w}r64 Hee# Circle cr.)4-31 Prod rnt Plan: CD4208 Plan: CD4-210 Plan: CD4-213 ~ ~ ~ Plan: CD4-215 ..~ CD2-37 ,,~ CD4-319wp05 ~ CD2-60 `J ~\ Nanuq 3 CD4318wp07 CD4318PB1 wp08 Project: Colville River Unit Site: Alpine CD4 Well: Plan: CD¢319 Welltwre: Plan: CD4-319 Plan: CD4319wp05 Gnwn3 Lcxq; ~: <;.xxa acu~; [roo~ Y °° aE~x,awrv ss.3 e:mrnm ne#.y rw#m;, ~rnsc v: -- Rf TARGET C3E tAllS (t1tiP lUD +Ni-S +El-W 6.000 0.002 8.003 7696.100 -66'!4.825 -3855.540 7120.'!60 1251.635 •5259.709 7126.166 1251,535 -5255.765 71321 -122942 3 71321£30 -5325,386 -3989.673 7132.166 .5325.396 -3.4.673 7132,160 -5325.3$6 -3389.573 Nanuk 2 \ CD4216 (wp03) D4-217 (wp02) ~~ Narkhing Fasting Stwpe 5357441.8300 37782A.7266 Circle {fiacliUS: 1$666.006} 5351436,97 373871.2666 5958778.8766 372586.4866 5958778.5700 $729°E6.Ad' {W CiCC18 (CtaK#ii#5: 1326,Q06} 59574.0756 372823.5216 Point 5952182.4300 373743,3,3 Paint 5952182.43W 373749.36iM9 Ciealc (Radius: 1326.660} 59521 373743.36Q0 Rectangle {876!}.000x2546.666) 00 ~ -OO~ `'U • ~ SHARON K. ALLSUP-DRAKE 1113 CONOCOPHILLIPS AT01530 DATE ~ ^v t 62-14/311 AN HORAGE AK 99501 ~ PAY TO THE 5 ~ /~ f ~C~S~ ~ ' ~-~ ~ J~ (W. ~v ORDER Of l• j- / ,p, _/' ~L.ril~-r,~y.~c,~ C(~ ~ L~ G--l~ ~~/ ~c~---pOLtAR$ L' I oa , ~k~ 3 : ~ ~ CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars 200 White Clay Center Or., Newark, DE t911t _ 7 v~ ~-- _- __ ~'~ MEMO --- ------~ ------- --- --- --~:03LLOOL44~:2L847L90 7 9 2 7 611'LL~3 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~~~ (~~ 7 PTD# ~~~ ~ ~~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIS records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to ~ perforate and produce/infect is contingent ~~ ,~~ 1~~ ~ ".~//~~' ~ ~ .upon issuance of a conservation order approving a spacing exception. ~~ ~~~ (Companv Name) assumes ~ ~ the liability of any protest to the spacing ,( exception that may occur. : ~Q DRY DITCH ~ All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, NANUO UNDF OIL -120175 Well Name: COLVILLE RIV UNIT CD4-319 Program SER Well bore seg ^ PTD#:2051480 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType SER / PEND GeoArea 890 Unit 50360 On/Off Share On Annular Disposal ^ Administration 1 Permitfeeattached----------------------------- ------ ---- ----Yes---- _________-___----.__-----__--__------__--__-__- ------------------------ 2 Lease number appropriate_ - - - Yes . Surface location in ADL 380077, top-productive interval in ADL 384209, TD.alsoJocated in_ADL_380077: , - - - - _ 3 Uniquewell-n_ameandnumber- ------ - - - --- - Yes_ -- -- --~-- - -- -- -- ------------------------ 4 Well located in a_defined-pool - - N_o_ . - - - Nanuq Pool Rules not yet approved, until-then, well is located in_N_anuq Undef Oil_ Pool. 5 Well located proper distance-from drilling unit-boundary_ Yes . All affected leases lie wikhin_the Colville-River Unit 6 Well located proper di_stance_ from other wells_ - -- - - - - - - - - - - - - - - - -Yes . _ - . Nanuq 3,_ located -400' away, is suspended: cased, not perfed, cmt_plug set_at 51-55'--well not open_to pool._ 7 Sufficient acreage available in_drillingunit_______________________ _________Yes_ -_------_.--______ 8 If_deviated,is_wellboreplat_inc_luded__________________________ _________Yes-_- -------__--__--__-__-----_- 9 Operator only affected party- - - - - - - - - Yes _ - - - - 10 Ope[ato[hasappropriate_bondinforce ---- -- - - -- -- -- Yes -- --- -- -- - -- --- - - --- --- --- -- -- --- -- i 11 Permit can be issued withoutconseruaiionorder___________________ _________Yes-___ .--------_____________------__-__ Appr Date 12 Permit_canbeissuedwithoutadministrativ_e_appCOVaI---------------- ---------Yes-___ ____--_--------__-____-__----------_------__-----_---__-__ -_ SFD 10117!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put_ 10# in_comments)-(For_ No See ccmments,_pelow, - - - - - - - _ - - _ - - _ - 15 All wells within 114-mile area of review identified(Fo[servicewellonly)------ ---------Yes,_-_ _--Nanuq-3-_-___--__-__--_.--_---_---_---_--___------_- 16 Pre-produced injector; duration of pre production Less than 3 months_(For_service well only) No_ _ - - - - -Well will be flowed back for clean up. -CPAI will produce about 400-500 bbl_s of mud & brine ±-2000 bbls_oil.- 17 AC_M_P_Finding of Consistency-has peen issued-for this project_ - NA- - Drilling permit approval not contingent upon ACMP review. Engineering 18 Condu_ctorsiring-provided - - Yes - - - - - - - - - 19 ______ Su _ ace casing-protects all- nown , SDWs _ _ - - - _ _ . - - - _ - . _ _________ NA--_-_ ___NoaquifersperA1O1$A,conclusion3._-_-- _ . - _ 20 CMT_v_ol_adequate_tocircul_ateoneQnductor_&surf-csg______________ _______ _Yes---- _________-__--------..---__-_____--.--_--_-____-----.- ---------------- 21 CMT_vol-adequate_totie-in long string tosu_rfcsg--________________ ___ ___- No--___ ___Annula[disposalmaybeproposed.____-_-----.--- ______-----_ __________-,- 22 CMT_will coverall known_productiye horizon_s_ - - - - - - Yes - - - - - - - TOC planned 500' and apove Nanuq-reservoir,_2500' and above Kuparuk. If other hydr-ocarpon zones are_ identifie_d_ 23 Casing designs adequate for C,_T,B&-pe-rmafrost------------------ ------- -Yes____ -----they will beisolated.___ --..__--______ ___ ______-_--__ __.___-_------.-_ 24 Adequate tankage_or reserve pit - , - - - - - Yes - - - - Rig is_e_quippe_d with steel-pits..No reserve_pitplanned, All waste to approvedannulus ordisposal wel_l._ 25 If_a-re-drill,has_a_1.0-403 forapandpnmentbeenapproved------------- --------- NA_-__- __-_----------__--_--__--__-------.__--___-_---------__-_----..----- 26 Adequate weilpore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ - - _ - -Proximity analysis perfo[med, Traveling cylinder path calculated, Gyros possible.. - - _ - - - _ - - _ - - - - - - - _ 27 If diverter required, does it meet regulations- - - - - - - Yes _ .. l)iyerter is plaanned._ Appr Date 28 Drilling fluid.program schematic & equip list adequate_ - - - - . _ Yes Maximum expected formation pressure 8,7-EMW._ MW planned up 9.$ in-8-314" hole and 9.3 in-N-Kuparuk.- - TEM 10/17/2005 /] 29 BOPEs, do they meet_ regulation - - - - Yes - - - W ' 30 BOPE_press rating appropriate; test to-(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - _ - - - MASP calculated at 2514 psi._ 3500-psi-appCOpriate. CPAI normal tests_to 5000_psi, _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ 31 Choke-manifold complies wlAPl_RP-53(May84)________----_----- ---------Yes____ __-----------_-________--__------_--- 32 Work will occur without operation shutdown- - - - - - Yes - Planned war-kshould-pe_completed this_season,-then-well will_be 51 until facilities are ready._ - - . - - - - - 33 Ispresence_ofH2Sgas-propaple__------------------_-___ _____..-- No- __H2$was-not reportedin_theexplor_align_wells•__--_--_----__--_-_---_- 34 Mechanical condition of wells within AOR verified ~Forservice well on_ly~ - _ - - - Yes - - - _ _ .Nanuq #3 is only in_z_one penetration in AOR. Well is satisfactorily_cemented. - - - Geology 35 Permit_can be issued w/o hydrogen.sulfide measures- - - - Yes New untapped pofion_of reservoir. -No H2S, - - - - - - - - - 36 Data presented on potential overpressure zones - - - - Yes Normal-pressure gradient expected eased on nearby Nanuq 3 exploration well, - - Appr Date 37 Seismic analysis_ of shallow gas zones_ _ _ - - NA- - - - - - Hydrates_may_beencountered atease permafrost _Mitigation-measures discussed in-Drilling Hazards Summary. SFD 10112!2005 38 Seabed condition survey-(ifoff-shore) - - - - - - -- NA -- -- - -- - 39 -Contact namelphone.for_weekly progressreports [exploratory onlyj_ - - - - - - . NA_ - - -.. - - -- Geologic Engineering P i Date Date: Date 0 erator has made a lication for A1O for Nanu and Nanu Ku aruk Oil Pools, hearin Nov. 1, 2005. Pulse test involvin 9 p Commissioner: r Commissioner: mi ner !) ~ ~ ~/ injection of 10,000 bbls water will be conducted after a second well is drilled from the pad. The pulse test will occur after approval of the Nanuq AIO. Regular injection operations will not begin until appox. the 4th quarter of 2006. D I ~ O ~ • • • Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically . organize this category of information. s Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Mar 03 10:52:04 2006 Reel Header Service name .............LISTPE Date .....................06/03/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/03/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River Field MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS MWD RUN 1 MW0004025926 R. KRELL L. HILL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 12.250 2ND STRING 8.750 3RD STRING PRODUCTION STRING Scientific Technical Services i~7e~ Scientific Technical Services CD4-319 501032051600 ConocoPhillips Alaska, Inc. Sperry Drilling Services 03-MAR-06 MWD RUN 2 MWD RUN 3 MW0004025926 MW0004025926 M. HANIK M. HANIK L. HILL L. HILL 24 11N 4E 2973 419 55.50 19.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 16.000 114.0 9.625 3196.0 • • REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL). 4. MWD RUN 2 COMPRISED DIRECTIONAL, DGR, EWR4, CTN, ALD, ACAL, PRESSURE WHILE DRILLING (PWD), AND GEOPILOT ROTARY-STEERABLE BHA (GP) . 5. MWD RUN 3 COMPRISED DIRECTIONAL, DGR, EWR4, PWD, CTN, ACAL, AND STABILIZED LITHO-DENSITY (SLD). 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 1-3 REPRESENT WELL CD4-319 WITH API#: 50-103-20516-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12005'MD/7154'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING BIT-TO-SENSOR DISTANCES. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (12.25" & 8.75" BITS) MUD WEIGHT: 8.7 - 10.00 PPG • • MUD SALINITY: 200 - 950 PPM CHLORIDES FORMATION WATER SALINITY: 10000-25000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RHOB 114.0 11928.5 DRHO 114.0 11928.5 PEF 114.0 11928.5 NCNT 117.0 11915.5 NPHI 117.0 11915.5 FCNT 117.0 11915.5 RPS 119.0 11958.5 RPM 119.0 11958.5 RPX 119.0 11958.5 RPD 119.0 11958.5 GR 127.5 11966.0 ROP 168.0 12005.0 FET 169.0 11958.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 114.0 3206.0 MWD 2 3206.0 10652.0 MWD 3 10652.0 12005.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FONT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 114 12005 6059.5 23783 114 12005 FCNT MWD CNTS 565.4 3044 1048 23591 117 11915.5 NCNT MWD CNTS 111143 2 17198 148413 23591 117 11915.5 RHOB MWD G/CM 0.522 3.045 2.29686 23630 114 11928.5 DRHO MWD G/CM -3.59 0.69 0.0603922 23630 114 11928.5 RPD MWD OHMM 0.43 2000 34.2557 23680 119 11958.5 RPM MWD OHMM 0.37 2000 17.7566 23680 119 11958.5 RPS MWD OHMM 0.51 9 73.64 10.8513 23680 119 11958.5 RPX MWD OHMM 0.81 18 69.86 8.40745 23680 119 11958.5 FET MWD HOUR 0.15 72.78 0.883601 23580 169 11958.5 GR MWD API 19.63 417 114.027 23678 127.5 11966 PEF MWD BARN 0.33 15.25 2.67095 23630 114 11928.5 ROP MWD FT/H 1.65 4 42.28 184.682 23641 168 12005 NPHI MWD PU-S 10.51 1 02.88 38.0728 23598 117 11915.5 First Reading For Entire File..........114 Last Reading For Entire File...........12005 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEF 114.0 3122.5 DRHO 114.0 3122.5 RHOB 114.0 3122.5 NPHI 117.0 3104.5 FCNT 117.0 3104.5 NCNT 117.0 3104.5 RPS 119.0 3156.5 RPM 119.0 3156.5 RPD 119.0 3156.5 RPX 119.0 3156.5 GR 127.5 3164.0 ROP 168.0 3206.0 FET 169.0 3156.5 LOG HEADER DATA DATE LOGGED: O1-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 3206.0 TOP LOG INTERVAL (FT) 168.0 BOTTOM LOG INTERVAL (FT) 3206.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: •0 MAXIMUM ANGLE: 59.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 78633 CTN COMP THERMAL NEUTRON 158416 ALD Azimuth. Litho-Den 10718128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 114.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S) 300.0 MUD PH: 8.3 MUD CHLORIDES (PPM): 950 FLUID LOSS (C3) 1.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.900 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.730 100.0 MUD FILTRATE AT MT: 2.100 68.0 MUD CAKE AT MT: 4.000 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • • Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FONT MWDO10 CNTS 4 1 68 4 2 NCNT MWDO10 CNTS 4 1 68 8 3 RHOB MWDO10 G/CM 4 1 68 12 4 DRHO MWDO10 G/CM 4 1 68 16 5 RPD MWDO10 OHMM 4 1 68 20 6 RPM MWDO10 OHMM 4 1 68 24 7 RPS MWDO10 OHMM 4 1 68 28 8 RPX MWDO10 OHMM 4 1 68 32 9 FET MWDO10 HOUR 4 1 68 36 10 GR MWDO10 API 4 1 68 40 11 PEF MWDO10 BARN 4 1 68 44 12 ROP MWD010 FT/H 4 1 68 48 13 NPHI MWDO10 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 114 3206 1660 6185 114 3206 FCNT MWDO10 CNTS 565.4 3044 879.45 5976 117 3104.5 NCNT MWDO10 CNTS 141547 217198 159505 5976 117 3104.5 RHOB MWDO10 G/CM 0.528 2.972 2.00271 6018 114 3122.5 DRHO MWDO10 G/CM -0.741 0.69 0.0824247 6018 114 3122.5 RPD MWDO10 OHMM 0.91 2000 78.5716 6076 119 3156.5 RPM MWDO10 OHMM 0.92 2000 41.2099 6076 119 3156.5 RPS MWDO10 OHMM 0.95 506.7 21.5352 6076 119 3156.5 RPX MWDO10 OHMM 0.88 192.71 12.1321 6076 119 3156.5 FET MWDO10 HOUR 0.19 4.3 0.67999 5976 169 3156.5 GR MWDO10 API 19.63 208.06 97.5667 6074 127.5 3164 PEF MWDO10 BARN 0.33 5.29 2.0597 6018 114 3122.5 ROP MWDO10 FT/H 1.65 389.74 139.47 6043 168 3206 NPHI MWDO10 PU-S 10.51 102.88 55.9131 5976 117 3104.5 First Reading For Entire File..........114 Last Reading For Entire File...........3206 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... • • Version Number...........1.0.0 Date of Generation.......06/03/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 3105.0 FONT 3105.0 NPHI 3105.0 DRHO 3123.0 PEF 3123.0 RHOB 3123.0 FET 3157.0 RPM 3157.0 RPD 3157.0 RPX 3157.0 RPS 3157.0 GR 3164.5 ROP 3206.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10560.5 10560.5 10560.5 10574.0 10574.0 10574.0 10607.0 10607.0 10607.0 10607.0 10607.0 10615.0 10652.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ALD Azimuth. Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 06-NOV-05 Insite 66.37 Memory 10652.0 3206.0 10652.0 37.4 64.3 TOOL NUMBER 103770 134760 179954 1064059 8.750 3196.0 Fresh Water Gel 9.70 35.0 9.3 300 6.8 5.500 72.0 3.320 123.8 9.000 72.0 MUD CAKE AT MT: 3.800 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD020 CNTS 4 1 68 4 2 NCNT MWD020 CNTS 4 1 68 8 3 RHOB MWD020 G/CM 4 1 68 12 4 DRHO MWD020 G/CM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HOUR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 BARN 4 1 68 44 12 ROP MWD020 FT/H 4 1 68 48 13 NPHI MWD020 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3105 10652 6878.5 15095 3105 10652 FONT MWD020 CNTS 583 2767 1123.24 14912 3105 10560.5 NCNT MWD020 CNTS 111143 184630 145541 14912 3105 10560.5 RHOB MWD020 G/CM 0.522 3.045 2.39102 14903 3123 10574 DRHO MWD020 G/CM -3.59 0.263 0.0310401 14903 3123 10574 RPD MWD020 OHMM 0.43 2000 14.8003 14901 3157 10607 RPM MWD020 OHMM 0.37 2000 7.15891 14901 3157 10607 RPS MWD020 OHMM 0.51 973.64 6.24901 14901 3157 10607 RPX MWD020 OHMM 0.81 952.01 6.07854 14901 3157 10607 FET MWD020 HOUR 0.15 72.78 0.807491 14901 3157 10607 GR MWD020 API 54.77 199.79 112.828 14902 3164.5 10615 PEF MWD020 BARN 1.02 15.25 2.88181 14903 3123 10574 ROP MWD020 FT/H 11.06 442.28 219.989 14892 3206.5 10652 NPHI MWD020 PU-S 12.56 54.86 31.6705 14912 3105 10560.5 First Reading For Entire File..........3105 Last Reading For Entire File...........10652 File Trailer Service name .............STSLIB.003 Service Sub Level Name... • • Version Number...........1.0.0 Date of Generation.......06/03/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 10561.0 NPHI 10561.0 FONT 10561.0 PEF 10574.5 RHOB 10574.5 DRHO 10574.5 RPD 10607.5 FET 10607.5 RPS 10607.5 RPX 10607.5 RPM 10607.5 GR 10615.5 ROP 10652.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) STOP DEPTH 11915.5 11915.5 11915.5 11928.5 11928.5 11928.5 11958.5 11958.5 11958.5 11958.5 11958.5 11966.0 12005.0 08-NOV-05 Insite 66.37 Memory 12005.0 10652.0 12005.0 48.0 90.0 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 E[TIR4 ELECTROMAG. RESIS. 4 134760 SLD STABILIZED LITHO DEN 59952 CTN COMP THERMAL NEUTRON 201229 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 3196.0 ~J Fresh Water Gel 9.70 38.0 8.8 300 7.6 1.050 74.0 .570 141.8 1.900 74.0 1.800 74.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10561 12005 11283 2889 10561 12005 FCNT MWD030 CNTS 764.9 2 500.8 1006.64 2710 10561 11915.5 NCNT MWD030 CNTS 127542 1 86840 139784 2710 10561 11915.5 RHOB MWD030 G/CM 2.091 3.014 2.43226 2709 10574.5 11928.5 DRHO MWD030 G/CM -0.049 0.616 0.172921 2709 10574.5 11928.5 RPD MWD030 OHMM 2.3 2000 41.892 2703 10607.5 11958.5 RPM MWD030 OHMM 2.29 2000 23.4589 2703 10607.5 11958.5 RPS MWD030 OHMM 2.42 2 16.65 12.2068 2703 10607.5 11958.5 RPX MWD030 OHMM 2.38 18 69.86 12.8735 2703 10607.5 11958.5 FET MWD030 HOUR 0.32 24.23 1.75334 2703 10607.5 11958.5 GR MWD030 API 40.3 417 157.642 2702 10615.5 PEF MWD030 BARN 1.8 7.21 2.8688 2709 10574.5 ROP MWD030 FT/H 5.09 264.73 91.3468 2706 10652.5 NPHI MWD030 PU-S 14.15 46.5 33.9607 2710 10561 First Reading For Entire File..........10561 Last Reading For Entire File...........12005 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/03/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/03/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF 11966 11928.5 12005 11915.5 Scientific Technical Services Scientific Technical Services End Of LIS File