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Home My WebLink About206-054 T R A N S M I T T A LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – CRU DATE: 12/19/2023 Transmitted: North Slope, Colville River Unit Colville CD1-01A 50-103-20299-01 212099_CD1-01A_PERF_23Jul22 212099_CD1-01A_WFL_23May2022 CD1-04 50-103-20346-00 200117_CD1-04_PLUG_27Aug2022 CD1-33 50-103-20357-00 222105_CD1-33_Puncher_21Sep2022 CD1-48A 50-103-20592-01 212004_CD1-48A_LDL_28Jul2022 CD2-02 50-103-20513-00 205109_CD2-02_LDL_11Oct2022 205109_CD2-02_LDL_12Jul2022 205109_CD2-02_Patch_07Nov2022 205109_CD2-02_PLUG_23Aug2022 CD2-15 50-103-20386-00 201159_CD2-15_LDL_06Oct23 CD2-310 50-103-20826-00 220028_CD2-310_DHSIT_10Aug2022 220028_CD2-310_USIT_25Apr2022 CD2-404 50-103-20530-00 206054_CD2-404_Patch_30Dec2021 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38291 T38292 T38293 T38294 T38295 T39296 T38297 T38734 200-212 CD2-404 50-103-20530-00 206054_CD2-404_Patch_30Dec2021 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:54:09 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, September 1, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Lou Laubenstein P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-404 COLVILLE RIV QANN CD2-404 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2022 CD2-404 50-103-20530-00-00 206-054-0 W SPT 4054 2060540 1500 1531 1531 1531 1531 473 611 600 587 4YRTST P Lou Laubenstein 7/17/2022 4-year test 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 QANN CD2-404 Inspection Date: Tubing OA Packer Depth 830 2290 2220 2200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitLOL220718144549 BBL Pumped:1.6 BBL Returned:1.3 Thursday, September 1, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 James B. Regg Digitally signed by James B. Regg Date: 2022.09.01 14:05:20 -08'00' 1 Regg, James B (OGC) From:Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent:Monday, July 11, 2022 12:59 PM To:Brooks, Phoebe L (OGC); Regg, James B (OGC); Wallace, Chris D (OGC); DOA AOGCC Prudhoe Bay Subject:CRU MITs 06/27 - 06/28/22 Attachments:MIT CRU CD2 PAD 06-27-22.xlsx; MIT CRU CD2 PAD 06-28-22.xlsx; MIT CRU CD2-404 SI TEST 06-27-22.xlsx Apologies‐‐ I just returned to the office after being out last week. I thought I had sent these prior to leaving. Sorry again for the delay. Travis From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Thursday, July 7, 2022 2:13 PM To: Smith, Travis T <Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]CRU MITs 06/27 ‐ 06/28/22 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Travis, I was reviewing June MITs (due 7/5) and didn’t see the MITs for CD2 that were witnessed by Matt Herrera on 6/27 & 6/28? Please advise. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CRU CD2-404 PTD 2060540 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2060540 Type Inj N Tubing 950 960 960 960 Type Test P Packer TVD 4056 BBL Pump 1.5 IA 1 1760 1730 1720 Interval 4 Test psi 1500 BBL Return 1.5 OA 200 210 210 210 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD 5448 BBL Pump IA Interval Test psi 1500 BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: CD2-404 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD2 PAD N/A Hembree / Caudle 06/27/22 Form 10-426 (Revised 01/2017)2022-0627_MIT_CRU_CD2-404       J. Regg; 7/14/2022 MEMORANDUM TO: Jim Regg�w P.I. Supervisor 1-��e FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, January 21, 2022 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD2 -404 COLVILLE RIV QANN C132-404 Src: Inspector Reviewed By: P.I. Supry ::j9r— Comm Well Name COLVILLE RIV QANN CD2 -404 API Well Number 50-103-20530-00-00 Inspector Name: Brian Bixby Permit Number: 206-054-0 Inspection Date: 1/16/2022 Insp Num: mitBDB220117054406 Rel Insp Num: Packer Well CD2404 Type Inj W -TVD PTD 2060540 Type Test, SPT iTest psi BBL Pumped: 1 BBL Returned: Intervals OTHER —TP/F Notes: MITIA as per SUNDRY # 321-596 --' Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - 4054 Tubing 1300 13 - 1300 - 1300 130 _ I 1500 IA 1800 3000 2950 2940. 1.1 . OA 920 990 990 990 ' P ,�/ Friday, January 21, 2022 Page 1 of l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y Meredith Guhl at 7:30 am, Jan 21, 2022 Travis T. Smith Digitally signed by Travis T. Smith Date: 2022.01.20 16:47:03 -09'00' VTL 01/24/2022 RBDMS HEW 1/28/2022 DSR-1/24/22 !"#$$$ $$$ ! $$$ $$$ % &'""'()&*!() &'"+'*( $$$ $$$ ' !+,%-'"!+() -'"( .'").!$#) )!+, /' .". #. ,-!*( ) " #/ # ! # ''012345678 0995:;<=>?:562<3@ Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:CD2-404 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: Set Patch, MIT IA, Set Inj Valve, DDT on safety valve 1/4/2022 CD2-404 oberr Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.50 Top (ftKB) 36.0 Set Depth (ftKB) 114.0 Set Depth (TVD)… 114.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 36.7 Set Depth (ftKB) 2,693.0 Set Depth (TVD)… 2,382.9 Wt/Len (l… 45.50 Grade J-55 Top Thread BTCM Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 34.8 Set Depth (ftKB) 5,560.5 Set Depth (TVD)… 4,071.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 5,331.1 Set Depth (ftKB) 11,083.0 Set Depth (TVD)… 4,076.8 Wt/Len (l… 9.20 Grade L-80 Top Thread SL-HT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 5,331.1 4,053.983.47 SLEEVE TIEBACK SLEEVE 5.750 5,342.1 4,055.183.84PACKER LINER TOP PACKER 4.940 5,350.0 4,055.9 84.04 NIPPLE RS PACKOFF SEAL NIPPLE 4.880 5,352.8 4,056.2 84.11 HANGER LINER HANGER 4.830 5,363.4 4,057.3 84.38 SBE 80-40 SEAL BORE EXTENSION 4.010 11,047.9 4,075.1 87.40 BUSHING PACKOFF BUSHING 2.900 Tubing Strings Tubing Description TUBING 4.5"x3.5"@136' String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 32.8 Set Depth (ft… 5,369.1 Set Depth (TVD) (… 4,057.8 Wt (lb/ft) 9.30 Grade L-80 Top Connection 8RD EUE Mod Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Nominal ID (in) OD Nominal (in)Make Model Com 32.832.80.00 HANGER 3.958 10.850 T&C Non -Upset TUBING Hanger-FMC w/ 2.23 pup 136.4 136.4 1.18 XO Reducing 3.000 5.188 T&C Non -Upset CROSSOVER 5.188"x3" 2,237.2 2,011.0 34.18 SAFETY VLV 2.812 5.300 T&C Upset Camco TRMAXX-5E ***NOT LOCKED OUT*** 4,506.8 3,769.1 56.91 GAS LIFT 2.920 5.390 CAMCO KBMG GLM - Camco KBMG 3 1/2" 4,626.8 3,830.4 61.42 GAS LIFT 2.920 5.390 CAMCO KBMG GLM - Camco KBMG 3 1/2" 4,705.5 3,866.5 63.89 NIPPLE 2.750 4.500 T&C Upset HES 'XN' NIPPLE w/2.75" NO GO 5,364.9 4,057.4 84.42 LOCATOR 2.992 4.500 Baker T&C Upset BAKER LOCATOR w/SPACE OUT PUP Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 2,237.22,011.134.18 INJ VALVE 3.5" MCX ON 2.81" X LOCK (1.09" BEAN)1/4/2022 1.090 4182968-1 4,638.4 3,836.061.82 PACKER - PATCH - UPR 3.5" Paragon II Packer ME @ 4640.81' Top of patch ~5' below bottom of GLM 2 at 4,633.8' 1/4/2022 1.625ALPP35014 4,642.03,837.7 61.95 SPACER PIPE Spacer Pipe- 1.90 EU 10RD 1/4/2022 1.590 4,656.0 3,844.2 62.43 LEAK - TUBING Tubing leak @ 4,656' 11/17/2021 2.060 4,661.63,846.862.62 PACKER - PATCH - LWR 3.5" Paragon II Packer ME @ 4,664' 12/30/2021 1.625LATCH- ALPAL35003 ALPP35003 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 4,506.83,769.1 56.91 1 GAS LIFT DMY BK 0.000 0.08/31/2008 2 4,626.83,830.4 61.42 1 GAS LIFT DMY BK 0.000 0.012/22/2021 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 5,451.0 5,732.0 4,064.2 4,079.4 5/21/2006 32.0SLOTSSlotted Liner 6,045.0 6,140.0 4,089.5 4,089.3 5/21/2006 32.0 SLOTS Slotted Liner 6,171.0 6,233.0 4,088.4 4,086.1 5/21/2006 32.0 SLOTS Slotted Liner 6,265.0 6,359.0 4,085.3 4,083.8 5/21/2006 32.0 SLOTS Slotted Liner 6,547.0 7,082.0 4,081.5 4,082.7 5/21/2006 32.0SLOTSSlotted Liner 7,330.0 7,707.0 4,080.6 4,078.1 5/21/2006 32.0SLOTSSlotted Liner 8,974.010,196.0 4,070.7 4,068.3 5/21/2006 32.0SLOTSSlotted Liner 10,355.0 10,827.0 4,069.8 4,066.5 5/21/2006 32.0 SLOTS Slotted Liner 10,953.0 11,048.0 4,071.2 4,075.1 5/21/2006 32.0 SLOTS Slotted Liner Horizontal, CD2-404, 1/19/2022 2:42:06 PM Vertical schematic (actual) LINER; 5,331.1-11,083.0 SLOTS; 10,953.0-11,048.0 SLOTS; 10,355.0-10,827.0 SLOTS; 8,974.0-10,196.0 SLOTS; 7,330.0-7,707.0 SLOTS; 6,547.0-7,082.0 SLOTS; 6,265.0-6,359.0 SLOTS; 6,171.0-6,233.0 SLOTS; 6,045.0-6,140.0 SLOTS; 5,451.0-5,732.0 INTERMEDIATE; 34.8-5,560.5 PACKER - PATCH - LWR; 4,661.5 LEAK - TUBING; 4,656.0 SPACER PIPE; 4,642.0 PACKER - PATCH - UPR; 4,638.4 GAS LIFT; 4,626.8 GAS LIFT; 4,506.8 SURFACE; 36.7-2,693.0 SAFETY VLV; 2,237.2 INJ VALVE; 2,237.2 CONDUCTOR; 36.0-114.0 WNS INJ KB-Grd (ft) 37.03 Rig Release Date 5/24/2006 CD2-404 ... TD Act Btm (ftKB) 11,540.0 Well Attributes Field Name QANNIK Wellbore API/UWI 501032053000 Wellbore Status INJ Max Angle & MD Incl (°) 95.21 MD (ftKB) 11,502.66 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment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y Samantha Carlisle at 4:13 pm, Nov 18, 2021 Travis T. 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The well has been shut‐in and freeze protected. DHD will perform diagnostic testing including an MIT‐IA and wellhead testing. Following this we will submit paperwork for continued injection or repairs. A well schematic and 90‐day TIO are attached. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Smith WNS Intervention & Integrity Engineer 907‐670‐4014 Travis.T.Smith@conocophillips.com Annular Communication Surveillance 11-Jun-2021Well Name:CD2-404 Start Date:11-Jun-2021 9-Sep-2021Days:90 End Date:9-Sep-2021 50 60 70 80 90 100 110 120 130 140 150 0 500 1000 1500 2000 2500 11-Jun-2114-Jun-2117-Jun-2120-Jun-2123-Jun-2126-Jun-2129-Jun-212-Jul-215-Jul-218-Jul-2111-Jul-2114-Jul-2117-Jul-2120-Jul-2123-Jul-2126-Jul-2129-Jul-211-Aug-214-Aug-217-Aug-2110-Aug-2113-Aug-2116-Aug-2119-Aug-2122-Aug-2125-Aug-2128-Aug-2131-Aug-213-Sep-216-Sep-219-Sep-21Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 500 1000 1500 2000 2500 3000 3500 11-Jun-2114-Jun-2117-Jun-2120-Jun-2123-Jun-2126-Jun-2129-Jun-212-Jul-215-Jul-218-Jul-2111-Jul-2114-Jul-2117-Jul-2120-Jul-2123-Jul-2126-Jul-2129-Jul-211-Aug-214-Aug-217-Aug-2110-Aug-2113-Aug-2116-Aug-2119-Aug-2122-Aug-2125-Aug-2128-Aug-2131-Aug-213-Sep-216-Sep-21Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CD2-404 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SBHP for Surveillance 3/17/2020 CD2-404 claytg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.50 Top (ftKB) 36.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 36.7 Set Depth (ftKB) 2,693.0 Set Depth (TVD) … 2,382.9 Wt/Len (l… 45.50 Grade J-55 Top Thread BTCM Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 34.8 Set Depth (ftKB) 5,560.5 Set Depth (TVD) … 4,071.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 5,331.1 Set Depth (ftKB) 11,083.0 Set Depth (TVD) … 4,076.8 Wt/Len (l… 9.20 Grade L-80 Top Thread SL-HT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,331.1 4,053.9 83.47 SLEEVE TIEBACK SLEEVE 5.750 5,342.1 4,055.1 83.84 PACKER LINER TOP PACKER 4.940 5,350.0 4,055.9 84.04 NIPPLE RS PACKOFF SEAL NIPPLE 4.880 5,352.8 4,056.2 84.11 HANGER LINER HANGER 4.830 5,363.4 4,057.3 84.38 SBE 80-40 SEAL BORE EXTENSION 4.010 11,047.9 4,075.1 87.40 BUSHING PACKOFF BUSHING 2.900 Tubing Strings Tubing Description TUBING 4.5"x3.5"@136' String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 32.8 Set Depth (ft… 5,369.1 Set Depth (TVD) (… 4,057.8 Wt (lb/ft) 9.30 Grade L-80 Top Connection 8RD EUE Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.8 32.8 0.00 HANGER TUBING Hanger-FMC w/ 2.23 pup 3.958 136.4 136.4 1.18 XO Reducing CROSSOVER 5.188"x3" 3.000 2,237.2 2,011.0 34.18 SAFETY VLV Camco TRMAXX-5E ***NOT LOCKED OUT*** 2.812 4,705.5 3,866.5 63.89 NIPPLE HES 'XN' NIPPLE w/2.75" NO GO 2.750 5,364.9 4,057.4 84.42 LOCATOR BAKER LOCATOR w/SPACE OUT PUP 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,237.2 2,011.1 34.18 INJ VALVE 3.5" MCX ON 2.81" X LOCK (1.09" BEAN) 3/17/2020 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 5,451.0 5,732.0 4,064.2 4,079.4 5/21/2006 32.0 SLOTS Slotted Liner 6,045.0 6,140.0 4,089.5 4,089.3 5/21/2006 32.0 SLOTS Slotted Liner 6,171.0 6,233.0 4,088.4 4,086.1 5/21/2006 32.0 SLOTS Slotted Liner 6,265.0 6,359.0 4,085.3 4,083.8 5/21/2006 32.0 SLOTS Slotted Liner 6,547.0 7,082.0 4,081.5 4,082.7 5/21/2006 32.0 SLOTS Slotted Liner 7,330.0 7,707.0 4,080.6 4,078.1 5/21/2006 32.0 SLOTS Slotted Liner 8,974.0 10,196.0 4,070.7 4,068.3 5/21/2006 32.0 SLOTS Slotted Liner 10,355.0 10,827.0 4,069.8 4,066.5 5/21/2006 32.0 SLOTS Slotted Liner 10,953.0 11,048.0 4,071.2 4,075.1 5/21/2006 32.0 SLOTS Slotted Liner Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 4,506.8 3,769.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 8/31/2008 2 4,626.8 3,830.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/1/2008 Notes: General & Safety End Date Annotation 9/5/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Horizontal, CD2-404, 5/25/2020 10:51:43 AM Vertical schematic (actual) LINER; 5,331.1-11,083.0 SLOTS; 10,953.0-11,048.0 SLOTS; 10,355.0-10,827.0 SLOTS; 8,974.0-10,196.0 SLOTS; 7,330.0-7,707.0 SLOTS; 6,547.0-7,082.0 SLOTS; 6,265.0-6,359.0 SLOTS; 6,171.0-6,233.0 SLOTS; 6,045.0-6,140.0 SLOTS; 5,451.0-5,732.0 INTERMEDIATE; 34.8-5,560.5 LOCATOR; 5,364.9 NIPPLE; 4,705.5 GAS LIFT; 4,626.8 GAS LIFT; 4,506.8 SURFACE; 36.7-2,693.0 SAFETY VLV; 2,237.2 INJ VALVE; 2,237.2 CONDUCTOR; 36.0-114.0 HANGER; 32.8 WNS INJ KB-Grd (ft) 37.03 Rig Release Date 5/24/2006 CD2-404 ... TD Act Btm (ftKB) 11,540.0 Well Attributes Field Name QANNIK Wellbore API/UWI 501032053000 Wellbore Status INJ Max Angle & MD Incl (°) 95.21 MD (ftKB) 11,502.66 WELLNAME WELLBORECD2-404 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, December 8, 2020 1:23 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: RE: CRU CD2 -404 (PTD 206-054) Injection Monitoring Period Chris— Water injector CRU CD2 -404 (PTD 206-054) ended its monitoring period yesterday, December, 7, 2020. The pressure trends during this time did not exhibit problematic behavior. The reservoir management team has decided to shut the injector in for the time -being. During this shut-in, and when the well is brought back online, we intend to operate it as a normal injection well. Please let me know if you have any questions or disagree with the plan forward. Thanks, Travis From: Smith, Travis T Sent: Thursday, November 5, 2020 5:12 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: CRU CD2 -404 (PTD 206-054) Injection Monitoring Period Chris— CRU CD2 -404 was brought back online on October 8, 2020. Per the communication below, it was placed on a 30 -day monitoring period to watch for signs of IA depressurization. The lockdown screws were re -torqued to attempt to address the issue described below. Thus far, the IA has not exhibited problematic behavior. Swings in the injection rates, however, have prevented a conclusive determination on the IA. Our intent is to extend the monitoring period by another 30 -days. If communication is evident the well will be shut in. Please let me know if you have any questions or disagree with the plan forward. Thanks, Travis From: Well IntegrityCOMPI liance Specialist WNS & CPF3 Sent: Tuesday, March 3, 202 : 8 AM To:'Wallace, Chris D (CED)' <chris.wa alaska. ov> Cc: CPA Wells Supt <n1030@conocophillips.co Subject: CRU CD2 -404 (PTD 206-054) Report of Suspect I -D-epressurization Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Thursday, November 5, 2020 5:12 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: CRU CD2 -404 (PTD 206-054) Injection Monitoring Period Chris— CRU C132-404 was brought back online on October 8, 2020. Per the communication below, it was placed on a 30 -day monitoring period to watch for signs of IA depressurization. The lockdown screws were re -torqued to attempt to address the issue described below. Thus far, the IA has not exhibited problematic behavior. Swings in the injection rates, however, have prevented a conclusive determination on the IA. Our intent is to extend the monitoring period by another 30 -days. If communication is evident the well will be shut in. Please let me know if you have any questions or disagree with the plan forward. Thanks, Travis From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Tuesday, March 3, 2020 9:38 AM To:'Wallace, Chris D (CED)' <chris.waIlace @alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: CRU CD2 -404 (PTD 206-054) Report of Suspect IA Depressurization Good Morning Chris, Water injector CRU CD2 -404 (PTD 206-054) has been shut in for reservoir pressure management since 7/30/2019. The well has recently exhibited suspect inner annulus depressurization. The tubing and inner casing packoff were tested 2/29/20 with passing criteria; However, the lower metal to metal seal is compromised, which may be the source of the suspect IA depressurization. The well will continue to remain SI for reservoir pressure management. When the well is able to return to service, CPAI intends to conduct a 30 -day monitor period on water injection to verify if the suspect behavior persists while online. If communication is evident, the well will be shut in. Please let me know if you have any questions or disagree with the plan forward. Please see the attached schematic and 90 -day TIO plot. Sincerely, Sara. Ca* -W& (HeAC4v) � Ste kava& 1Pacl L Well Integrity & Compliance Specialist, WNS & C1PF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop.com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, March 3, 2020 9:38 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CRU CD2 -404 (PTD 206-054) Report of Suspect IA Depressurization Attachments: CD2 -404 90 -Day TIO 3.3.20.pdf; CD2-404.pdf Good Morning Chris, Water injector CRU CD2 -404 (PTD 206-054) has been shut in for reservoir pressure management since 7/30/2019. The well has recently exhibited suspect inner annulus depressurization. The tubing and inner casing packoff were tested 2/29/20 with passing criteria; However, the lower metal to metal seal is compromised, which may be the source of the suspect IA depressurization. The well will continue to remain SI for reservoir pressure management. When the well is able to return to service, CPAI intends to conduct a 30 -day monitor period on water injection to verify if the suspect behavior persists while online. If communication is evident, the well will be shut in. Please let me know if you have any questions or disagree with the plan forward. Please see the attached schematic and 90 -day TIO plot. Sincerely, SGL-rw C aX'lbA& (Ue.AW / St-P.phtN� PaJv Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549Pcop.com Cell: 907-331-7514 1 sara a carlisle@cop.com • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 11,2018 TO: Jim Regg P.I.Supervisor l '`-11 � �3 o� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD2-404 FROM: Brian Bixby COLVILLE RIV QANN CD2-404 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 41%2— NON-CONFIDENTIAL 1%2NON-CONFIDENTIAL Comm Well Name COLVILLE RIV QANN CD2-404 API Well Number 50-103-20530-00-00 Inspector Name: Brian Bixby Permit Number: 206-054-0 Inspection Date: 6/5/2018 Insp Num: mitBDB180610162503 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD2-404 - Type Inj ( W TVD 4054 ' Tubing 1360 1360 1360 - 1360 ------------- PTD 2060540 - Type Testi SPT Test psi 1500 ' IA 685 2210 2135 - I 2120 BBL Pumped: 1.8 BBL Returned: OA 425 580 - 580 . 580 Interval 4YRTST P/F P ✓ Notes: SCANNE JUN 2 2 Lu iii Monday,June 11,2018 Page 1 of 1 MEMORANDUM ~ State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, August 02, 2010 TO: JimRegg ~ ~~~1~ P.I. Supervisor ~' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-404 FROM: Jeff Jones COLVILLE RIV QANN CD2-404 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: COLVILLE RIV QANN CD2-404 Insp Num: mitJJ100802074234 Rel Insp Num: API Well Number: 50-103-20530-00-00 permit Number: 206-OS4-0 Inspector Name: Jeff Jones Inspection Date: 6/12/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-404 -Type Inj. W TVD 40s4 jA 400 2200 2140 2090 P.T.D 2o6osao TypeTest SPT ~ Test psi ~ Isoo OA sso 7so 7so Aso Interval 4YRTST p~ P „Tubing 1390 1390 1390 1390 Notes: 1.3 BBLS diesel pumped; no exceptions noted. s~~~~~~h i+,, Monday, August 02, 2010 Page 1 of 1 =~. ~. ''~ ~~ ~~ ..z... ~ - ,~,n,,,- ~: ~ ~° . ~ ~r '~• a ~. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Mazker.doc MEMORANDUM ~ State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, October 09, 2008 TO: P1mRpggisor ~ ~~~/ ~ (~~~lY~I~J SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC CD2-404 FROM: John Crisp COLVILLE RIV QAN:V CD2-404 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv NON-CONFIDENTIAL Comm Well Name: COLVILLE RN QANN CD2-404 Insp Num: mitJCr081009093354 Rel Insp Num: API Well Number: 50-103-20530-00-00 Permit Number: 206-054-0 Inspector Name: John Crisp Inspection Date: 10/4/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well cDZ-aoa Type Inj. ' `~' TVD aoss IA 90o noo ~ 1660 16s0 P.T. 2060540 ~TypeTESt SPT I Test psi 1500 ~ OA 600 600 ~ 700 700 Interval ~TAL P/F P ~` Tubing I s6~ i s6~ ~ sal ~ sn ~ Notes' Injection rate 1500 BWPD with no change during MIT..3 bbl's pumped for test. Thursday, October 09, 2008 Page 1 of 1 CD2-404 Injection Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, September 02, 2008 9:43 AM To: 'Schneider, Tim S.' Subject: RE: CD2-404 (206-454) Injection Page 1 of 2 Tim, ERIO 4 was approved for the pilot injection project which was concluded in January 2007. AIO 35 is now the governing document for injection into the Qannik pool. The current status of CD2-404 is 1-WINJ. Regular injection into CD2-404 is authorized so long as the requirements of AIO 35 are met. Call or message with any questions. Tom Maunder, PE AOGCC From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophillips.com] Sent: Tuesday, September 02, 2008 9:02 AM To: Maunder, Thomas E (DOA) Subject: CD2-404 Injection ~~~ 5~t ~ ~ 200$ Tom, CPAI is preparing the Qannik well; CD2-404 (PTD: 206-054) for injection with the approval of AIO 035.000. (July 8, 2008) The permitting history is noted below. The 10-403 dated December 20th, 2006 stipulated injection in accordance with ER104 (attached). The injection period was limited to 12 months. With the recent AIO approval, is the 10-403 submitted sufficient for us to begin injection? Regards, Tim Schneider Prod. Engineer, WNS CPAI 907-265-6859 «Qannik test 4.pdf» 10-401-Permit to D&C as an Qannik Undefined exploration well approved 4/17/06. 10-403 to convert to injection and injection order needed if going in that direction (written on approved permit). 10-407-Revised Well Completion Report dated 7/24/06- exploratory temporary oil producer status with well tests included. 9/2!2008 CD2-404 Injection ~ Page 2 of 2 10-403 -convert to injection approved 12/20/06 10-404 -convert to injection reported 2/9/07 with MIT testing results included. Well currently shut in. 9/2/2008 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: 206-054 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD2-404 2. Address: 4b. Well Status: Oil ^Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20530-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g, Field: Initial Disposal ^ or Continuation ^ or Final ^Q 307-154 5/8/2007 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 ~~~ ) ,l f® ~UL ~ ~ 2DO drilling mud, completion occurred U fluids, formation fluids and any necessary water added Previous totals (bbls): 496* 496 2007 / 2nd 6168 100 0 6268 17 5/5/2007 5/31/2007 CD2-72 2007 / 3rd 0 0 0 0 0 2007 / 4th 0 0 0 0 0 2008 / 1st 0 0 0 0 0 Total Ending volume 6168 100 496 6764 17 Report is due on the 20th tbbls): 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): *In'ectlYl test and freeze rotect volumes onl I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ~ Date: 7 rt $ to Z 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 2 3 Jw,,.~. DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060540 Well Name/No. COLVILLE RIV QANN CD2-404 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20530-00-00 MD 11540 TVD 4066 Completion Date 5/23/2006 Completion Status 1-OIL Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / y meairrmt rvumper Name scale meaia No Start Stop CH Received Comments D D Asc Directional Survey 36 11540 Open 6/27/2006 tog Sonic 5 Col 1 3800 5050 Open 5/24/2006 USIT/GR/CCL 21-May- 2006 ED C Lis 1399 I nduction/Resistivity 0 0 Open 7/19/2006 LIS GR, ROP ~D C Asc ~~ 13990 Induction/Resistivity 0 0 Open 7/19/2006 Text GR, ROP Plpt 13990 LIS Verification 0 0 Open 7/19/2006 ~g Production 5 Blu 1 100 7490 Open 9/15/2006 PPL w/MaxTrac, DEFT, Ghost, Pres, Temp, Spin, Dens, GR, CCL 25-Aug- 2006 ED C Lis In duction/Resistivity 1 2693 5560 Open 10/19/2006 GR, FET, ROP w/Graphics ~ ~D C Las 14476//Injection Profile 5146 10174 Case 2/14/2007 Injection Profile LAS Format w/Graphics tD C Las 14480 asing collar locator 5146 10174 Case 2/14/2007 Jewlery, Pres, CCL, Temp, GR in LAS w/Graphics ED C Las 14481 ~ Injection Profile 5146 10174 Case 2/14/2007 Injection Profile, GR, Temp, CCL, Pres w/Graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060540 Well Name/No. COLVILLE RIV QANN CD2-404 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20530-00-00 MD 11540 TVD 4066 Completion Date 5/23/2006 Completion Status 1-OIL Current Status 1WINJ UIC Y ADDITIONAL INFORMATION Well Cored? Y /© Daily History Received? //~ N Chips Received? ~ Formation Tops V/ N Analysis ~7'N- Received? Comments: Compliance Reviewed By: ___, ____ Date: (~, ~_~%~- ~U b 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. 206-054 ConocoPhillips Alaska, Inc. Development ^ Exploratory ~ 7. Well Name: CD2-404 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20530-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 307-154 5/8/2007 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 496* 496 totals (bbls): 2007 / 2nd 6168 100 0 6268 17 5/5/2007 5/31/2007 CD2-72 2007 / 3rd 0 0 0 0 0 2007 / 4th 0 0 0 0 0 2008 / 1st 0 0 0 0 0 Total Ending Report is due on the 20th volume 6168 100 496 6764 17 (bbls): of the month following the final month of the quarter. Ex: July 20 for the second quarter Apri120 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): '`In'ectlVl test and freeze protect volumes onl I hereby certify that the foregoin isis trcorrect to the best of my knowledge. Signature: 1 ~'~-a-9------~ Date: ~°'f ~7~ `o ~ 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 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: 206-054 ConocoPhillips Alaska, Inc. Development ^ Exploratory ~ 7. Well Name: CD2-404 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20530-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 307-154 5/8/2007 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 496* 496 totals (bbls): 2007 / 2nd 6168 100 0 6268 17 5/5/2007 5/31/2007 CD2-72 2007 / 3rd 0 0 0 0 0 2007 / 4th 0 0 0 0 0 2008 / 1st Total Ending Report is due on the 20th volume 6168 100 496 6764 17 (bbls): of the month following the final month of the quarter. Ex: Apri120 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): *In~eCtlVlt test and freeze rotect volumes onl I hereby certify that the foregoi is true and correct to the best of my knowledge. Signature: ~ ~ Date: , ~R ~0'l3 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 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: 206-054 ConocoPhillips Alaska, Inc. Development ^ Exploratory ~ 7. Well Name: CD2-404 2. Address: 4b. Well Status: Oil Q Gas WAG 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20530-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 307-154 5/8/2007 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 496* 496 totals (bbls): 2007 / 2nd 6168 100 0 6268 17 5/5/2007 5/31/2007 CD2-72 2007 / 3rd 0 0 0 0 0 2007 / 4th 2008 / 1st Total Ending Report is due on the 20th volume 6168 100 496 6764 17 (bbls>: of the month following the final month of the quarter. Ex: Apri120 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): *In~ectlVlt test and freeze protect volumes onl I hereby certify that the foregoing is t ue a nd correct to t he e st ofm y knowledge. b r ~ ~ ~ '- e - d- ~ \ ~~ ~ ~`-'~'--=-- ~ S ~ ° ~"~ ~~ 7 ignature: ~-- -_~ Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 J Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 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. 2-054 ConocoPhillips Alaska, Inc. Development ^ Exploratory ~ 7. Well Name: CD2-404 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20530-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ~ or Continuation ^ or Final ^ 307-154 5/8/2007 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 496* 496 totals (bbls): 2007 / 2nd 6168 100 0 6268 17 5/5/2007 5/31 /2007 CD2-72 2007 / 3rd 2007 ! 4th 2008 / 1st Total Ending Report is due on the 20th volume 6168 100 496 6764 17 (bbls>: of the month following the final month of the quarter. Ex: Apri120 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): "In'ectlVl test and freeze rotect volumes onl I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ 7 ~S ~O 7 Si t \ \"-~ ~~ D gna ure: ate: 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 ~ ~ SARAH PAUN, GOVERNOR a~i/tav~~ O~ ~ ~S 333 W. 7th AVENUE, SUITE 100 COr1TSERQA'1'IOr1T COMI-IISSI011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Qannik Undefined Oil Pool, CD2-404 Sundry Number: 307-154 Dear Mr. Alvord: 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. 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. . V DATED this -day of May, 2007 Encl. incerely, Dan T. Seamount Cornmissicner ~0~ -OS~{ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May O1, 2007 MAY 0 3 2007 Alaska Oil and Gas Conservation Commission Alaska Oil & Gas Cons. Commission 333 West 7`~ Avenue, Suite 100 Anchorage Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD2-404 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2-404 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 CD2-404 approximately May 5, 2005 or as soon as a permit is available.. .s 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 10-3/4" x 7-5/8" 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 1/ mile radius, not already on file at AOGCC: CD2- 21, CD2-11. Further details regarding wells on CDZ pad within % mile radius should be on file at the AOGCC. The initial annular LOT (15.6 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.1 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. Si rely, Si( /~ (/li .,-- Vern Johnson Drilling Engineer cc: CD2-404 Well File Chip Alvord ATO-1700 Anadarko Sharon Allsup-Drake ATO-1530 ConocoPhilli~s RECEIV D EEIVED ~~,~ S~~ "~~ ~ ~rr // ~'~~ o ~ 2007 ~l~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION~~~a ~~il ~ Gas Cons. Commission ANNULAR DISPOSAL APPLICATION Anchorag6 _ _ ~.~s.,... 20 AAC 25.080 1. Operator 3. Permit to Drill Name: Number: 206-054 ConocoPhillips Alaska 4. API Number: 50-103-20530-00 ' 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD2-404 6. Field: Colville River Field " 7. Publicly recorded wells G~w~cc~`S ~'rcv~~w~.. 8. Stratigraphic description: a) All wells within one-quarter mile: Q~S a) Interval exposed to open annulus: CD2-42, CD2-24, CD2-15, CD2-26, CD2-49, CD2-17, CD2-32 Torok and Seabee formation, shale, siltstone and sandstone CD2-25, CD2-22, CD2-23, CD2-12, CD2-20, CD2-18 CD2-06, CD2-31,CD2-09, CD2-21, CD2-11 b) Waste receiving zone: b) water wells within one mile: (~~~~ ~p~S c:S c ~ Sand layers in the Colville group C-30 in the Seabee formation ' - ` ' ~ CxQQc~pVE~ ~ ~ R~ ~+^ ~ CTCS~ ,- w~~~~h ~~~ None W~~~~~\rcS c)Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1740' MD / 1600' 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 2139 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- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 5-May-07 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD)^ Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data ^~ Other ^ 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. /~ ~ l Signature: ~~~ Title: ,~~8fedtu~ IJ~~ ~~ ~C~ Printed Phone N N b ~ ~ r ~ um er: 265-6120 Date: L ame: Chip Alvord S Commission Use Onl Conditions of approval: C~M+`~~tCad~C~ ~~ ~~ t~C,oZ'S ,©~ LOT review and approval: S~ ~1 » ° L A ent form re uired V ~~ S b e o al n b u s qu q : ppr v um er: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Dates " , B'~i71U15 BFI SAY 4 g 2007 ,: ~ s • . ~ J * f °~ Form 10-403RD Rev. 6/2004 O ~ ~ ~ ~ „' ~~TRUCTIONS ON REVERSE. S it in Duplicat • i Note to Fide CRU CD2-404 (PTD 2060540) May 7, 2007 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD2-404 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus of CD2-404. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 10-3/4" surface casing shoe is set at a true vertical depth subsea ("'TVDSS") of about 2,330', near the base of a 430 to 460' thick shale and claystone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone and sandy siltstone open to the annulus of Colville River Unit ("CRU") CD2-404 to accept the proposed injected fluids. 3. The lower confining layer is sufficierrtly thick and laterally persistent to ensure injected materials remain within the target disposal intervals. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The propased disposal injection operations will not affect potential oil or gas reservoirs. ?. The area most strongly impacted by the proposed annular injection activities will be limited to a radius of less than 70' from the wellbore. Discussion CPAI's application was reviewed along with records from nearby wells Neve No. 1 ("Neve 1"), Alpine No. 1 ("Alpine 1"), and Alpine No. 3 ("Alpine 3"). The discussion that follows is based on well logs and mud logs from these wells. An index map is provided, below. The proposed injection interval in CRU CD2-404 lies in the Seabee formation in the northern half of Section 2, T11N, R4E, UM and about 3 miles from the current boundary of the CRU. The 10-3/4" surface casing shoe of CD2-404 lies at a depth of about 2,693' measured depth ("MD"), 2,383' true vertical feet ("TVD"), and 2,330' TVDSS, near the base of a 430' to 460' thick interval that is dominated by shale and claystone and is continuous throughout the area. This irnerval will provide upper confinement for fluids disposed in the annulus of the well. The annulus proposed for disposal of drilling wastes extends downward from the surface casing shoe to the top of cement for the 7-5/8" casing string, which is estimated to be at about 4,069' MD (3,4$7' TVD, 3,451' TVDSS). The most likely portion of the open annulus that will accept injected waste is a 150' thick interval of silty sandstone that lies between 2,400' and 2,550' TVDSS, which is just below the surface casing shoe. Two underlying siltstone zones may also accept some of the injected fluids. These zones lie between 2,605' and 2,684' TVDSS and 2,729' and 2,807' TVDSS. The aggregate thickness of all of these potential injection zones is about 310'. These three potenrtial injection zones are separated by two claystone intervals that are, in descending order, 55' and 45' thick. Beneath the injection zones is a CRU CD2-404 May 7, 2007 Note to File Page 2 of 3 15' thick interval of claystone that is continuous throughout the area. This claystone layer will provide lower confinement for any injected wastes. k ~ I _ _ .per D2-0e D2~DB PB, D2.11 ~'D) D231 DD2~L, \` D2,0 ~~ P Al lne 3 D2~,0 P IN 3 D2)2 PNOP D3-13 CRU CD2-404 D2-0' PB2 n-,3P n-01 PB, D2C) P D2~z D,-,D .` D2-02 PB, \. D136 Dt-02 ~ D2-23 ~~ D, al] D,~21L1 - D1-?20. ~ 15 D,-2, I •1DP ~ D D2~1 B, I ,)A ~,B 1 D1-01 ~, NRUN 1 D1~21P8 D2-31 -14 D1~BB D2L9 _2 D130PB 222 ~ ' ~' D3- R 31PB, RT02 P _ D2-SB PBt 31 P D234IB ~~, Proposed Alpine 1 D, 46P D Disposal ' .m -~ D2d4 -2 D1~2B Interval ~ , ~ DB B, ~~ 3DPN PB, 1'~ ~ D2 .q1 Y3DPB, ~43 P BD D244 p Dt-27 \ INE U2+10 D13BPB f ~ 2 D235A 0137 D,3B D23D Dt-3A _ _ p2.3p •22BPB Neve 1 '~ ' °~" - - - ~, ~ D D2-61 I D,AD ~ ~:~ir~~ D262 Index Map The operator's application reports the base of permafrost occurs at about 1,550' TVDSS in this area. Inspection of the well logs from Neve 1, Alpine 1 and Alpine 3 indicates that precise determination of the base of permafrost is difficult here. The geologic section appears frozen through about 1,100' TVDSS in these three wells. The base of permafrost lies about 1,200' above the top of the proposed injection intervals. The shallow geologic section in the area surrounding CD2-404 contains methane gas. Records from Neve 1, Alpine 1 and Alpine 3 indicate that traces of methane were first measured 70', 720' and 565' TVDSS, respectively. All three wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 10.0 pounds per gallon, with a range from 9.4 to 10.6 pounds per gallon). The shallowest occurrence of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mudlog) were 1,820', 1,040' and 2,320' TVDSS, respectively. So, the entire proposed disposal zone likely contains some methane gas. Supporting documentation to ConocoPhillips' annular disposal application states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Order 18B, which governs the CRU, states that there are no USDWs beneath the permafrost within the CRU area. The only oil shows observed in offset wells within strata that correlate to the proposed disposal interval occur in Neve 1 and Alpine 1 at 2,960' and 2,945' MD, respectively. The mudlogging geologists rated • • CRU CD2-404 May 7, 2007 Note to File Page 3 of 3 these shows as being trace to very poor shows in quality. 'They indicate the presence of only small amounts of residual oil. Better quality oil shows were encountered in Neve 1, Alpine 1 and Alpine 3 well below the proposed disposal interval. The following chart provides an estimate of the affected area surrounding the CD2-404 wellbore. A worst-case assumption will be made. A count of sand in the most likely disposal zone between 2,400' and 2,550' TVDSS indicates that about 45' of net sand can be counted using the gamma ray curve if a sand cut-off value of 95 API units is chosen. Inspection of the neutron and density porosity logs for correlative intervals in offset wells suggests a sand porosity of 34% at this depth. Based on these values, the area most strongly impacted by the proposed annular injection activities will be limited to a radius of less than 70' from the wellbore. Injected Fluid vs Affected Distance from CD2-404 Wellbore (assumes 45' aggregate injection zone thickness and 34°k porosity) 100 a a w m 3 E 0 50 d v c 0 Q The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 1,000' of permafrost, and is bounded above and below by continuous layers of claystone and / or shale. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. This injection zone lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. I recommend proval of this annular disposal project. Steve Davies Senior Petroleum Geologist D 5,000 10,000 15,000 20,000 25,0()0 30,000 35,000 Amount of Injected Fluid (barrels) Annulus Disposal Transmittal Form -Well CD2-404 AOGCC Reeulations, 20 AAC 25.080 (bl 1 Desi nation of the well or wells to receive drillin wastes: CD2-404 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 Lower Cretaceous Torok commission finding that the waste will be confined and will Formation provide a lower barrier. Calculated water salinities not come to the surface or contaminate freshwater. of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within lmile. 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 waste under h 3 of this section. 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 2243 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 N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary 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 CD2-72, CD2-468, other CD2 wells will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rodent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. Well CD2-404 Date 5/1/2007 Pressure Calculations for Annular Disposal (for submita] 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 0.4472 psi/ft Header Pressure (for wells on gas lift) 0 psi b'ersion LO - Jan'OS Pburst85% -PHydrostatic +PApplied - PFormation 3,876 = ( 2,383 * 0.052 * MWmax ) ~- 1500 - ( 0.4337 * 2,383 ) MWmax = 27.5 PPg 2,383 TVD Surface Casin>? Strin Size 10.75 in Weight 40.5 ppf Grade L 80 rbursaoo°r° 4,560 PsJ Pburst85% 3,876 psi Depth of Shoe 2,383 ft FIT/LOT @ Shoe 18.1 ppg or 2,243 psi FIT/LOT for Annulus 15.6 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 4,069' MD ~ 3,487' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% -PHydrostatic +PApplied - PGasGradient - PHeader 4,072 = ( 3,487 * 0.052 *MWmax )+ 1,500 - (0.4472 * 3,487) - 0 MWmax = 22.8 PPg 3.5 "Tubing 2nd Casing String Size 7.625 in 4,071 TVD Weight 29.7 ppf Grade L 80 rcollapse100% 4,790 PsJ Pcollapse85% 4,072 PsJ Top of Cement 3,487 ft Gas Gradient 0.4472 psi/ft Max Surf. Pressure 1,500 psi Header Press 0 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,383 * .052 * 18.1 ) Pmax allowable - 2,243 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". C~ ConocaPh~l~ ~ Casing Detail 10 3/4" Surface Casing n Well: CD2-404 Date: 5/10/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.70 FMC Gen V Hanger 2.59 36.70 Jts 3 to 65 63 Jts 10-3/4" 45.5# L-80 MBTC Csg 2565.80 39.29 Halliburton Float Collar 1.24 2605.09 Jts 1 to 2 2 Jts 10-3/4" 45.5# L-80 MBTC Csg 84.97 2606.33 Weatherford Float Shoe 1.74 2691.30 2693.04 TD 13 1/2" Surface Hole 2702.00 13-112" Hole @ 2,702' MD / 2,390' TVD 10-3/4" Shoe @ 2,693' MD / 2,383' TVD RUN TOTAL 37 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (stop ring on Jt #1 8 2 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 77 joints in the pipe shed. Run joints 1 - 65 Last 12 joints stay out Use Best-o-Life 2000 i e do e MU torgue ~ 9500 ft/Ibs Remarks: Up Wt - 170k Dn Wt- 135k Block Wt - 75k Supervisor. D. Burley / L. Hill Cement Detail Report CD2-404 Surface Casing Cement Primary Job Type DRILLING ORIGINAL & INITIAL COMPLETION Job Category AFE / RFE Start Date Spud Date End Date DRILLING 10136149 4/27/2006 5/8/2006 5/24/2006 ':Cement Details Description -- -- Cementing Start Date - - -_ Cementing End Date Wellbore Name Surface Casing Cement 5/10/2006 20:52 5/10/2006 23:14 CD2-404 Comment Cement 10 314" casing as follows: Pumped 40 bbls. biozan water w/ nut plug - 6 bpm @ 250 psi w/ rig pump -Switch to Dowell -Pumped 3 bbls water -test cement lines to 2500 psi -Dropped btm plug -Mixed & pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.7 bpm @ 320 psi - Mixed & pumped 449 bbls of lead slurry (ASL "G" w/ 30% D-53, 0.6% D046, 1.5% D079, 1.5% S001, 43.1 % D124, 9% BWOW D44, 0.5% D-65) @ 10.7 ppg - 7.5 bpm @ 220 psi -switched to tail slurry 58 Bbls ("G" w! 0.2% D46, 0.3% D65, 2% S001) @ 15.8 ppg - 5.6 bpm @ 205 psi Dropped top plug & pumped 20 bbls water w/ Dowell -Switch to rig pumps -Displaced w/ 9.7 ppg mud @ 6.7 bpm 340 to 860 psi for first 225 bbls -slowed to 4 bpm @ 700 psi for last 6 bbls. -Bumped plug U 1150 psi -CIP @ 2314 hrs, floats helds. Full returns during job w/ 250 bbls cement returns to surface -recripcated pipe until 449 Bbls of lead slurry away, landed hanger on landing ring. Cement Stages _ _ Sta e # <Sta a Number?> _ - --- - Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement 36.7 2,693.0 Yes 250.0 Yes Yes O (start) (bbl/min) O (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 4 6 700.0 1,200.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement 10 3/4" casing as follows: Pumped 40 bbls. biozan water w/ nut plug - 6 bpm @ 250 psi w/ rig pump -Switch to Dowell -Pumped 3 bbls water -test cement lines to 2500 psi -Dropped btm plug -Mixed & pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.7 bpm @ 320 psi - Mixed & pumped 449 bbls of lead slurry (ASL "G" w/ 30% D-53, 0.6% D046, 1.5% D079, 1.5% S001, 43.1% D124, 9% BWOW D44, 0.5% D-65) @ 10.7 ppg - 7.5 bpm @ 220 psi -switched to tail slurry 58 Bbls ("G" w/ 0.2% D46, 0.3% D65, 2% S001) @ 15.8 ppg - 5.6 bpm @ 205 psi Dropped top plug ~ pumped 20 bbls water w/ Dowell -Switch to rig pumps -Displaced w/ 9.7 ppg mud @ 6.7 bpm 340 to 860 psi for first 225 bbls -slowed to 4 bpm @ 700 psi for last 6 bbls. -Bumped plug U 1150 psi -CIP @ 2314 hrs, floats helds. Full returns during job w/ 250 bbls cement returns to surface -recripcated pipe until 449 Bbls of lead slurry away, landed hanger on landing ring. - _ _ __ _ -- Cement Fluids & Additives -- - -- --- Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm-(ftKB) Amount (sacks) 'Class Volume Pumped (bbl) Lead Cement 36.7 2,193.0 568 G 449.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.77 Additives Additive Type Concentration Conc Unit label -- __ _ __ _ _ - _ __ -- Fluid __ - _ __ _ _ _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,193.0 2,693.0 280 G 58.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 Additives Additive Type Concentration Conc Unit label Page 1/26 Report Printed: 5/1/2007 i r~ `- ~ - ~- Security Level: Development Daily Drilling Report CD2-404 Report Number: 6 . _. . Rig: DOYON 19 Report Date: 5/10/2006 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) CD2-404 Development QANNIK 5/8/2006 2.93 2,702.0 2,702.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE + Sup Amount 10136149 14,908.14 59,654.84 451,036.14 1,209,360.84 4,830,088.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Surface, 2,693.OftKB Ops and Depth @ Morning Report 24hr Forecast Set test plug and Test BOP. Test BOP. Pick up BHA and RIH. Drill shoe track and FIT. Change out mud and drill. Last 24hr Summary Cured lost circulation. Ran and cemented 10 3/4" casing @ 2693'. General Remarks Weather Head Count 48.0 Supervisor ~ Title _ <Contact Name?> - -- __ Don Mickey I Rig Supervisor - _ -- - - Time Log _ _ _ - _ -- - Start end Dur Time Depth Start Depth G c' ~ Time Lme ~ (hrs) phase Op Code OpSutrCo P-N-T Trbl Code Trbl Class (ft KB) (ftKB) ~ Comm/O eratlon 00:00 00:30 0.50 SURFAC WELCTL TRIP T Well Lost Circ - 0.0 952.0 RIH w/ open ended 5" drill pipe to 952' -filling hole with Control Other trip tank -estimated losses @ 80 bph 00:30 02:15 1.75 SURFAC WELCTL CIRC T Well Lost Circ - 952.0 952.0 Mix and pump 35 bbls LCM pill @ 25 ppb -monitor well Control Other on trip tank -losses @ 60-80 bpm Mixing larger volume pill 02:15 04:45 2.50 SURFAC WELCTL CIRC T Well Lost Circ - 952.0 952.0 Mix and pump 150 bbls of 9.7 ppg mud with 25 ppb LCM Control Other -pumped until/ LCM back across shakers 04:45 05:30 0.75 SURFAC WELCTL OTHR T Well Lost Circ - 952.0 952.0 Monitor well -losses @ 6-8 bph Control Other 05:30 06:00 0.50 SURFAC WELCTL TRIP T Well Lost Circ - 952.0 0.0 POOH with drill pipe Control Other 06:00 08:00 2.00 SURFAC CASING RURD P 0.0 0.0 RU to run 10 3/4" casing 08:00 08:15 0.25 SURFAC CASING SFTY P 0.0 0.0 Held PJSM with crew 08:15 09:15 1.00 SURFAC CASING RNCS P 0.0 164.0 PJSM -Ran 10 3/4" 45.5# L-80 MBTC as follows: Float shoe (Wetherford) 2 jts. -float collar(Halliburton) 2 jts.( first 4 connections made up w/ BakerLoc) filled pipe ~ checked floats 09:15 12:00 2.75 SURFAC CASING RNCS P 164.0 821.0 Run 10 3/4" 45.5# L-80 MBTC from 164' to 821' - washed down through tight spots on joints #'s 4, 11, 12 and 15 with 4.0 bpm with good returns. (20 joints total) 12:00 16:15 4.25 SURFAC CASING RNCS P 821.0 2,693.0 Run 10 3/4" 45.5# L-80 MBTC from 821' to 2,648' - washed down through tight spots on joints #'s 26, 29, 32, and 33 - 4.0 bpm with good returns. (65 joints total) MU FMC fluted hanger and LJ -Land casing with shoe @ 2,693', FC @ 2,605'. 16:15 17:00 0.75 SURFAC CEMENT RURD P 2,693.0 2,693.0 Lay down fill-up tool - MU Dowell cement head and lines - establish circulation with 2.5 bpm / 350 psi 17:00 20:45 3.75 SURFAC CEMENT CIRC P 2,693.0 2,693.0 Circulate and condition mud for cementing Latest BOP Test Data ~ uate ~ Comment _ ' Page 1/2 Report Printed: 5/1/2007 -~-.._ ~ Security Level: Development Daily Drilling Report CD2-404 Report Number: 6 Rig: DOYON 19 Report Date: 5/10!2006 - - - - - - - - - - 'Time Log _ __ __ _ _ ___ Start End Dur T ~ Time Depth Start ', Depth End Time Time ', (hrs) Phase Op Code '~ OpSub Co_ P-N-T Trlil Cade Trbl Class. (ftKB) { (ftKB) ComMOperation 20:45 23:30 2.75 SURFAC CEMENT DISP P 2,693.0 0.0 Cement 10 3/4" casing as follows: Pumped 40 bbls. biozan water w/ nut plug - 6.5 bpm @ 350 psi w/ rig pump -Switch to Dowell -Pumped 3 bbls water -test cement lines to 2500 psi -Dropped btm plug -Mixed & pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.4 bpm @ 120 psi - Mixed & pumped 449 bbls of lead slurry (ASL "G" w/ 30% D-53, 0.6% D046, 1.5% D079, 1.5% S001, 43.1 % D124, 9% BWOW D44, 0.5% D-65) @ 10.7 ppg - 7.5 bpm @ 420 psi -switched to tail slurry 58 Bbls ("G" w! 0.2% D46, 0.3% D65, 2% SOOT) @ 15.8 ppg - 5.6 bpm @ 365 psi Dropped top plug & pumped 20 bbls water w/ Dowell - Switch to rig pumps -Displaced w/ 9.7 ppg mud @ 6.7 bpm 340 to 860 psi for first 225 bbls -slowed to 4 bpm @ 700 psi for last 6 bbls. -Bumped plug t/ 1150 psi - CIP @ 2314 hrs, floats helds. Full returns during job w/ 250 bbls cement returns to surface - recripcated pipe until 449 Bbls of lead slurry away, landed hanger on landing ring. 23:30 00:00 0.50 SURFAC CASING DHEO P 0.0 0.0 Tested casing to 2500 psi for 30 Min. Mud Check Data j _ __ '; Solids. Corr Gel (10m) Gel (30m) HTHP Filt Density Temp., Type Depth (ftKB) Dens (Iblgal) f Vis (s 72 PV Cal 28p0 (Ib 11g 000 (Ibf/100ft~) ( (IbfllDOft') (Ibf1100ftP) MBT (Ib/bbq (mLJ30min) ' = 30.0 9.4 (/ ) 5.000 !i 18 000 22.000 Spud mud 2,702 0 9 70, I i - - . _ - i Injection Fluid _ Fluid Source From Lease (bbl) ! Destination _ ~ -Note Diesel CD2-404 15.0 CD2-56 Recycled mud CD2-404 407.0~CD2-56 Drill Strings: BHA No. 0 - Slick / Blt Run No. 0 - 42in, Veco 42, Veco, <SN?> __ _ )-_ ;--- ) (. _) ~ - ~ - -. De th In ftK6 De th Out ftKB TFA incl Noz m Nozzles l32" IADC Bit Dull Strin Wt 10001b WOB max 100... ~( ~ ( ) ( IVUOB (min) (1000... p ) T p 2,702.0 0-1-1-1-1-0-WT-TD 2,702.0 - -_ Drilling Parameters _ -- - -- -. _----..- - -- _ _ - i SI' Cum Drill ~ O flow _ idingHrs -- ~ -- --- -- - - RPM PU HL Rot HL J SO HL Time hrs (m) ..- '- ( ) ( ) hrs Cum De th ft ( ) (gP ) WOB Ibf (rPm) SPP (psi) (10001bf) (10001bf1- I, (10001b~ Off Btm Tq Drlll Tq ~ Start ftKB End ftKB ( ) I p O ( ) _ -_ __- _.. _._~ __._ _._. ~ . 2,702.0 2,702.0 i I I I I Wellbores - _ . _. _. - Wellbore Name Wellbore API/UWl CD2-404 501032053000 Section Size (in) Act Top (ftKB) - -- - '- --_ Act Btm (ftKB) _ - Start Date - - _ End Date - -- --- COND1 __ 42 _ 36.8 114.0 5/1/2006 5/3/2006 SURFAC 13 1/2 114.0 2,702.0 5/8/2006 5/11/2006 INTRMI 9 7/8 2,702.0 5,571.0 5/12/2006 5/13/2006 PROD1 6 3/4 5,571.0 - - 11,540.0 _ - 5/15/2006 -- _._- 5/18/2006 r- ----_ - ~Casmg Strings_ - __- --_ -- _ _ I - _ Casing Description Run Date ~ OD Qn) Wt (Ibslft) Grade Set Depth (ftKB) Comment Surface 5/10/2006 10 3/4 45.50 J-55 2,693.0 Ran 65 jts 10 3/4 45.5# L-80 MBTC casing to 2693'. FC @ 2606'. -- 1 -- - ---. .__ _ __ _ - _ _ _ Cement _ Surface Casin Cement -Started 5/10/2006 Type Wellbore String Cement Evaluation Results casing CD2-404 Surface, 2,693.OftK6 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) Surface Casing Cement 36.7 2,693.0 4 700.0 - - Fluid Class Amount (sacks) V (bbl) Den§ity (Ib/gaq_ _ Yield (ft'/sack) Est Top (ftKB). Est Btm ftKB) Lead Cement G 568 _ _ _ 449.0 4.45 36.7 2,193.0 Tail Cement G 280 58.0 1.17 2,193.0 2,693.0 Page 2/2 Report Printed: 5/1/2007 CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-404 Rig: Doyon 19 Date: I 5/10/2006 ~ Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Burley/Hill _ Pump used: #2 Mud Pump ~ Strokes ~ 0.1000 Bbls/strk ~ 8.0 5trk/min ~ T f T t ' ~ P i d ~ ype o es : , Casing Shoe Test LOT/FIT ump ng own .annulus and DP. Casing Test Pressure In te rit Test Hole Size: 9-7/8" ~ Casin Shoe Depth Hole De th Pumpin Shut-in Pumpin Shut-i n RKB-CHF: 36.7 Ft 2,693 Ft-MD 2,383 Ft-TVD 2,722 Ft-MD 2,406 Ft-TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 10-3/4" 45.5#/Ft L-80 BTC I ~ 0 0 0 2550 0 0 0 1050 Casin Test Pressure Int e rit Test 2 50 1 2550 2 50 0.25 1025 Mud Weight: 9.7 ppg Mud Weight: 9.6 ppg 4 100 2 2550 4 125 0.5 1010 Mud 10 min Gel: 18.0 Lb/100 Ft2 Mud 10 min Gel: 18.0 Lb/100 Ft2 6 200 3 2530 6 175 1 990 Test Pressure: 2,500 psi Rotating Weight: 150,000 Lbs 8 400 4 2525 8 300 1.5 9 Rotating Weight: 75,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 600 5 2520 10 450 2 94 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 12 700 6 2510 12 600 2.5 935 Estimates for Test: 2.4 bbls Estimates for Test: 1041 psi 0.9 bbls 14 800 7 2500 14 750 3 920 ~ ~~ 16 950 8 2500 16 875 3.5 910 EMW =Leak-off Pressure + Mud Weight = 1050 PIT 15 Second 18 1100 9 2500 18 1000 4 900 0.052 x TVD + 9.6 0.052 x 2383 Shut-in Pressure, psi 20 1300 10 2500 19 1050 4.5 890 EMW at 2693 Ft-MD (2383 Ft-ND) = 18.1 ppg 1025 22 1475 15 2500 5 885 soon Lost 50 psi during test, held 98% 24 1600 20 2500 5.5 880 of test pressure. 26 1750 25 2500 6 860 28 1850 30 2500 6.5 855 zsoo _ _ _ _ 30 2100 7 845 _ 32 2250 7.5 835 34 2450 8 825 zooo w 35 2550 8.5 815 9 800 ~ N tsoo 9.5 79 w - - 10 7. ~ a ,ooo ~ . ~ _~ soo 0 o , z s a o s ,o ,s so 2s so Barrels Shut-In time, Minutes Volume Volume Vol ume Vol ume ~~CASING TEST f LEAK-OFF TEST O PIT Point PUm ed Bled Back PUm ed Bled Back s s s s Comments: Tested casing after bumping plugs on cement opts. • • ~OnaCQ~t~~l 5 Casing Detail ~7%'Casing ~ ~4 Well: CD2-404 Date: 5/13/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Lower lock down 34.83 FMC Gen V Hanger 3.31 34.83 Jts 3 to 131 129 Jts 7 5/8" 29.7# L-80 BTCM Csg 5435.48 38.14 Halliburton Float Collar .96 5473.62 Jts 1 to 2 2 Jts 7 5/8" 29.7# L-80 BTCM Csg 84.44 5474.58 Weatherford Float Shoe 1.51 5559.02 5560.53 TD 9 7/8" Hole 5571.00 9 7/8" Hole TD @ 5,571' MD / 4,072' TVD 7 5/8" Shoe @ 5561' MD / 4,071' TVD Total Centralizers: 47 Straight blade centralizer one perjt on jts # 1-14 Straight blade centralizer one per jt jts. # 68, 69, 70 Straight blade centralizer one per jt on every other joint Starting @ # 72 to # 130 Top Kanik - 5,496 ' MD 4,067 'TVD 145 joints in shed - 131 total jts. to run Last 14 jts. out Use Run & Seal i e do e Average MU torque 6500 ft/Ibs Remarks: Up Wt - 220 k Dn Wt - 145k Block Wt - 75k Supervisor. D. Burley/L. Hill i ~---_ Cement Detail Report CD2-404 ,. Intermediate Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL & INITIAL COMPLETION DRILLING 10136149 4!27/2006 5/8/2006 5/24/2006 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate 5/14/200610:30 5/14/200612:03 CD2-404 Comment ,Cement Stages - - - -- _ --- -------- ------ _ _ ISta e # <Sta a Number?> _ Description Objective __ _ _ _ _ Top (ftKB) Bottom (ftKB) Full Return? _ Cmnt Rtm (... Top Plug? Btm Plug? Intermediate Isolation 34.8 5,560.5 Yes 0.0 Yes Yes O (start) (bbl/min) O (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 6 370.0 950.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment ~Cement Fluids & Additives --- -- Fluid ___- - _ _ ---- _ - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Primary Cement 4,500.0 5,560.0 310 G 62.9 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.11 15.80 Additives Additive Type Concentration Conc Unit label Page 1/26 Report Printed: 5/1/2007 --- Security Level: Development. Daily Drilling Report CD2-404 . .. Report Number: 10 R ig: DOYON 19 Report Date: 5/14/2006 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD2-404 Development QANNIK 5/8/2006 6.93 5,571.0 5,571.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE + Sup Amount 10136149 2,665.50 142,968.70 431,177.50 2,159,834.70 4,830,088.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 5,560.5ftKB Ops and Depth ~ Morning Report 24hr Forecast Making MADD Pass. RIH and make MADD pass. Cut drilling line. Drill shoe track and 20' of new hole. CBU. FIT to 12.5 PPG EMW. Change to MOBM and Drill. Last 24hr Summary Finished running casing to 5560'. Circulated and conditioned mud. Cemented casing. Tested casing to 3500 psi. Installed and tested packoff. RU and tested BOP. Picked up BHA. General Remarks Weather Head Count 26 Deg Wind NE @ 5 MPH 50.0 Supervisor ~ - Title <Contact Name?> Don Mickey _~Rig Supervisor _- - Time Lo - g _ - _ - -- ---_ Start End 7ur T ~ Time ' -. De th Start I Depth End I p Tlme Time ~:hrs) Phase Op Code OpSub Co.~P-N Ti ass. ,. (ftKB) ~ (ftK8) I CommlOperation '. Trbl Code Trbl G 00:00 00:30 0.50 INTRM1 CASING OTHR P _ 0.0 0.0 Pull test plug and install thin wall wear bushing 00:30 01:30 1.00 INTRMI CASING RURD P 0.0 0.0 RU to run 7 5/8" casing 01:30 01:45 0.25 INTRM1 CASING SFTY P 0.0 0.0 Held Prejob safety and Ots meeting with crew 01:45 05:00 3.25 INTRM1 CASING RNCS P 0.0 2,698.0 Make up & Thread lock 7-5/8" Silver bullet float shoe, 2- jts 7-5/8", 27.9#, L-80, BTC csg, 7-5/8" Float collar, Circ & check float equip., RIH to 2,698'. (64 jts total) 05:00 05:30 0.50 INTRMI CASING CIRC P 2,698.0 2,698.0 Circ csg vol., Stage rate up to 6 bpm @ 310 psi, PUW 148 K, SOW 125 K, Full returns. 05:30 08:15 2.75 INTRM1 CASING RNCS P 2,698.0 5,561.0 Continue running 7-5/8" csg. to 5,517', Make up FMC fluted hanger & Landing jt., Land csg w/ shoe @ 5561', FC @ 5,474'. 08:15 08:45 0.50 INTRMI CEMENT RURD P 5,561.0 5,561.0 Lay down Frank's fill up tool - Rig up Dowell cement head and lines 08:45 10:30 1.75 INTRMI CASING CIRC P 5,561.0 5,561.0 Circ & cond. mud for cementing, Stage rate up f/ 2 bpm / 300 psi to 7 bpm FCP @ 340 psi -Reciprocate casing 20', PUW 220K, SOW 148K. PJSM with Dowell and crew 10:30 11:30 1.00 INTRMI CEMENT DISP P 5,561.0 5,561.0 Cement 7" casing as follows: Pumped 5 bbl CW-100 - Test lines to 3700 psi -pump 15 bbls CW-100 @ 4.8 BPM @ 200 psi -Mix & pump 30 bbls MudPush XL @ 12.5 ppg - _PM @ 230 psi -Drop bottom plug -Mix & pum 2.9 ead slurry (Class G w/ .2% D046, .3% DO 07% 8155, .4% D167) @ 15.8 ppg - 5.7 BPM @ 150 psi 11:30 12:15 0.75 INTRM1 CEMENT DISP P 5,561.0 5,561.0 Drop top plug -Pumped 20 bbls water w/ Dowell - Switch to rig pumps & displaced w/ 230 bbls 9.8 ppg mud @ 6.8 BPM @ 140 to 540 psi -slowed rate to 4.0 BPM for last 5 bbls - 370 psi -bumped plug w/ 950 psi - floats held - OK - CIP @ 1203 hrs. Full returns throughout job 12:15 13:00 0.75 INTRM1 CASING DHEO P 0.0 0.0 RU and test casing to 3500 psi for 30 minutes 13:00 13:45 0.75 INTRM1 CEMENT RURD P 0.0 0.0 RD cement head -lay down landing joint -pull thin wall wear bushing 13:45 14:30 0.75 INTRM1 CASING DHEQ P 0.0 0.0 Install and test packoff to 5000 psi for 10 minutes 14:30 15:30 1.00 INTRM1 WELCTL OTHR P 0.0 0.0 Change out top pipe rams to 3 1/2" x 6" VBR's 15:30 15:45 0.25 INTRMI DRILL PULD P 0.0 0.0 PU and spot Geospan skid on rig floor Latest BOP Test Data Date Comment Page 1/3 Report Printed: 5/1/2007 Security Level: Development Daily Drilling Report CD2-404 Report Number: 10 Rig: DOYON 19 Report Date: 5/14/2006 _ --- - --- ____- _ _ Time Lo ____ _ Start j '~. Time = End Dur Time ~! (hrs) phase Op Code OpSutrCo_.I Time ', P-N-T{ Trbl Code Trbl Class. Depth Start (ftKB) Dep[h End (ftKB) Comm/Operation 15:45 21:00 5.25 INTRM1 WELCTL BOPE P 0.0 0.0 Set test plug. Tested BOPE, Choke manifold, and floor valves to 250/5000 psi. Annulur to 250/3500 psi. Tested closing unit. Witiness waived by Chuck Scheve AOGCC. Pulled test plug. 21:00 00:00 3.00 INTRM1 DRILL PULD P 0.0 403.0 Set wear bushing and rigged up bales and elevators. Picked up and made up BHA. Mud Check Data _ - - ! YP Calc Get (10s) Gel (10m) Gel (30m) Type ~ Depth (ftKB) Den. II ~:~I ~ V f° apt) PV Calc (cp) (Ibf/100ft') , (Ibfl100ft') ` (Ibf/100ft') (Ibf/~OOft~) _ _ HTHP F(It ~ Temp Solids, Corr MBT (Iblbbl) (mL/30min) ~ pH i, (°F) (%) LSND 5,571.0 10.00 44 11.0 18.000 8.000 12.000 15.000 17.5 ~ ,Injection Fluid ~ Fluid Source ~ From Lease (bbl Desfination Note Diesel 5.0' CD2-56 Same Recycled mud 1524.0 CD2-56 From CD2-404 Drill Strings: BHA No. 4 - Steerable / Bit Run No. 4 - 6 3/4in, Ha_Ilib_u_rton Security DBS , FMF3641Z, 10819800 _ _ Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in~)'Nozzles (l32") IADC Bit Dull String Wt (10001bf~ 1N06 (max) (100... WOB (min) (7000. 5,571.0 11,540.0 1-1-NO-A-X-O-NO-TD 10 0 0 Drill Strin g Components Jts Item Description OD (in)-- ~ Top Conn Sz (in) - Top Thread Cum Len (ft) _ I. 1 Geo Pilot 4 3/4 1.500 3 1/2 NC 38 17.48 1 Drill Collar -Flex Non Mag 4 3/4 1.500 3 1!2 NC 38 29.03 1 Stabilizer (Non Mag) 4.76 1.500 3 1/2 NC 38 32.62 1 MWD DM HOC 4 3/4 1.500 3 1/2 NC 38 41.18 1 MWD GR/RES 4.73 1.500 3 1/2 NC 38 65.36 1 MWD (Dir & Logging) 4.7 1.500 3 1!2 NC 38 76.22 1 MWD TM HOC 4.62 1.500 3 1/2 NC 38 87.40 1 Float Sub 4.66 2.313 3 1/2 NC 38 89.75 1 Stabilizer (Non Mag) 4 3/4 2.250 3 1/2 NC 38 94.30 1 MWD Batt Sonic 4.7 1.250 3 1/2 NC 38 122.71 1 NMDC 4.64 2.250 3 1/2 NC 38 153.71 1 NMDC 4.52 2.250 3 1/2 NC 38 184.64 1 NMDC 4.54 2.250 3 1!2 NC 38 215.52 1 XO Sub 4 3/4 2.563 4 XT 39 218.171 3 HWDP 4 2.563 4 XT 39 310.06' 1 Drilling Jars - DNT 4 3/4 2.000 4 XT 39 342.06 2 HWDP 4 2.563 4 XT 39 403.42 ~Driflmg P arameters Sliding Hrs ~ Cum Drill ~ O (flow) _ _ RPM T PU HL _ Rot HL 50 HL ~ _ ', Start (ftKB ) End (ftKB) (hrs) Cum De th ft Time (hrs) ! (gpm) p O WOB (Ibf) j (~Pm) SPP (psi) (10001bf) (t0001bf) (1060 fbf) _ O(#gtm T.; Drill Tq 5,571 .0 5,571.0 O 0 Oi 0 _ 0 0' 0 0~ 0~ 0.0 0.0 Wellbores ' Wellbore Name Wellbore API/UWI CD2-404 501032053000 -- -- Section Size jin) j Act Top (ftKB) Aot Btm (ftKB) Start Date End Dale - - COND1 42 3 6.8 114.0 _ 5/1/2006 _ 5/3/2006 SURFAC 131/2 114.0 2,702.0 5/8/2006 5/11/2006 INTRMI 9 7/8 2,702.0 5,571.0 5/12/2006 5/13/2006 PROD1 6 3/4 5,571.0 11,540.0 5/15/2006 5/18/2006 ' Casin Strin s ---- - Casing Description Run Date I OD {in) Wt (Ibs/ft) Grade Set Depth (ftKB) i Comment ' J ___. _ .'---- - - -_._._ -- - --- ----__ -_. _____ Intermediate 5/14/2006 7 5/8 29.70 L-80 5,560.51 Cement _ __ __ Intermediate -Started 5/14/2006 Type Wellbore String Cement Evaluation Results casing CD2-404 Intermediate, 5,560.5ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) Intermediate 34.8 5,560.5 4 370.0 Page 2/3 Report Printed: 5/1/2007 ---~ Daily Drilling Report CD2-404 Rig: DOYON 19 Fluid Class Amount (sacks) V (bbl) Density (3blgal) Yfeld (ft'/sack) ~ Security Level: Development Report Number: 10 Report Date: 5/14/2006 Est Top (ftKB) Est ~Bfm (ft KB) T Primary Cement G 310 62.9 15.80 1.17 4,500.0 5,560.0 Page 3/3 Report Printed: 5/1/2007 PRESSURE I GRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-404 Rig: Doyon 19 Date: 5/14/2006 Volume_Input Pump Rate: Drilling Supervisor: BurleylHill Pump used: Cement Unit ~ Barrels ~ Bbls/Strk ~ 0.80 Bbl/min ~ T f T P i d ~ ype o est: Annulus Leak Off Test for Disposal Adequacy ~ ump ng own annulus. Casin Test Pressure In te rit Test Hole Size: 9-~/$" ~ Casin Shoe Depth Hole Depth Pumpin Shut-in Pumpin Shut-in RKB-CHF: 36.7 Ft 2693.0 Ft-MD 2383.0 Ft-TVD 5571.0 Ft-MD 4072.0 Ft-TVD Bbls psi Min psi Bbls p si Min p si Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 85 0.00 469 Chan es for Annular Ade uac Test Pressure Int e rit Test 1 0.5 275 0.25 430 Enter outer casing shoe test results in comments Mud Weight: 10.0 ppg 2 1 400 0.50 410 Casing description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 525 1.00 405 Hole Size is that drilled below outer casing. 4 2 650 1.50 40 Use estimated TOC for Hole Depth. 5 2.25 698 2.00 39 Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg 6 2.5 450 2.50 393 Estimates for Test: 620 psi 0.5 bbls 7 3 420 3.00 390 ~ ~ 8 3.5 440 3.50 388 EMW =Leak-off Pressure + Mud Weight = 698 PIT 15 Second 9 4 440 4.00 387 0.052 x TVD 0.052 x + 10 2383 Shut-in Pressure, psi 10 4.5 450 4.50 383 EMW at 2693 Ft-MD (2383 Ft-ND) = 15.6 430 15 5 460 5.00 380 tooo 20 5.5 470 5.50 377 w N 500 W a 7 0 5 10 15 20 25 30 Shut-In time, Minutes O PIT Point Summary 0 1 2 3 4 5 6 Barrels ~~CASING TEST (LEAK-OFF TEST ~-- -- ConocoPhil I i s WELLPATH DETAILS p CD2-lOJ Alaska 501032053000 Rig: Down 19 Rcf Datum. CD2-004: 52.70ft V Sec[ion Origin Origin Starting MALLIBUiiTON Angle +N/-S +E/-W From ND ~I ~! Mrs 328 02° 0.U0 O.OU 36.80 w 7O C .C 7 O Quarter Mile (1320 feet) radius plot -3701 -3084 -2467 -1850 -1234 -617 0 617 1234 1851 West(-)/East(+) [ft] ~ ~ SURFACE CASING SHOE SEPARATION FROM CD2-404 CD2-404 x Y Surface Casina Shoe ASP 4 Coordinates: 370646.55 5975142.76 ells CD2-35** Details @ AOGCC ermit # ermit Date ource well Ann. Vol. ***" tart Date nd Date is ante from Object well* 2010 Surface csg. Shoe X Coord. 372312.31 Surface csg. Shoe Y Coord. 5974017.68 CD2-42 301-140 6/1/2001 CD2-24, CD2-33, CD2-33A, CD2-15 33992 6/1/2001 10/10/2001 1236 371098.46 5973992.48 CD2-24 CD2-33 B*** 301-186 7/13/2001 CD2-33 (+A&B), CD2-39, CD2-14, CD2-15 33999 7/16/2001 10/9/2001 ` 421 1349 370630.11 370155.64 5974721.81 5973886.23 CD2-39 301-281 10/9/2001 CD2-15, CD2-47, CD2-44 29945 10/10/2001 9/16/2002 2277 372350.61 5973633.17 CD2-14 301-288 10/9/2001 CD2-45, CD2-47, CD2-32 31073 11/13/2001 3/5/2002 1567 372202.47 5974960.87 CD2-15 301-308 11/6/2001 CD2-50, CD2-25, CD2-44 31652 3/6/2002 9/21/2002 244 370832.00 5974984.02 CD2-47 301-322 12/3/2001 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 1939 371231.72 5973294.19 CD2-45 301-345 12/13/2001 CD2-49, CD2-17 22991 1/20/2002 2/19/2002 2480 372765.13 5973853.74 CD2-34 302-069 3/4/2002 CD2-13, CD2-37 22842 10/17/2002 11/28/2002 1353 371803.06 5974439.79 CD2-26 302-068 3/4/2002 CD2-44, CD2-29, CD2-13 29626 9/7/2002 10/17/2002 1293 371798.52 5974554.55 CD2-49 302-070 3/4/2002 CD2-50, CD2-46, CD2-22 27960 4/22/2002 5/28/2002 1236 371252.38 5974065.93 CD2-17 302-122 4/10/2002 CD-48, CD2-08 18181 5/29/2002 2/7/2003 1232 371774.00 5974645.00 CD2-32 302-119 4/30/2002 CD2-19, CD2-41, CD2-23 31113 6/14/2002 7/23/2002 1062 371295.61 5974302.38 CD2-50 302-121 4/30/2002 CD2-41, CD2-19, CD2-16, CD2-38 32000 7!24/2002 9/7/2002 1369 371665.21 5974227.65 CD2-25 NA 1157 371594.00 5974479.00 CD2-46 302-273 9/20/2002 CD2-51, CD2-12 31864 4/15/2003 5/19/2003 1338 371694.80 5974310.85 CD2-22 302-274 9/20/2002 CD2-08, CD2-36, CD2-51 31253 2/7/2003 3/16/2003 1184 371678.61 5974562.30 CD2-48 302-275 9/20/2002 CD2-28, CD2-35a, CD2-45, CD2-08 32000 12/10/2002 2/4/2003 1717 371631.74 5973736.14 CD2-19 303-083 4/28/2003 CD2-58, CD2-52 31337 5/19/2003 6/27/2003 1702 372284.88 5974681.33 CD2-41 303-081 4/28/2003 CD2-20, CD2-55,CD2-43 32000 6/27/2003 7/28/2003 1898 371990.58 5973802.52 CD2-23 CD2-16 303-080 4/28/2003 CD2-18, CD2-55, CD2-06 32000 9/4/2003 1/1/2004 374 1848 371013.17 372460.34 5975070.46 5974790.01 CD2-38 CD2-44 303-082 4/28/2003 CD2-40, CD2-30 30011 7/28/2003 9/4/2003 2130 1609 372033.86 372034.57 5973527.13 5974328.53 CD2-29 CD2-13 CD2-37 CD2-28 CD2-08 303-249 8/25/2003 CD2-06, CD2-30, CD2-27 29036 10/8/2003 11/19/2003 2021 2112 2449 1550 2062 372652.44 372658.78 371569.79 372139.80 372655.88 5974896.02 5975785.31 5972874.47 5974728.95 5975603.76 CD2-36 303-365 12/12/2003 CD2-43, CD2-31, CD2-57 32000 12/31/2003 7/9/2004 2007 371848.22 5973535.38 CD2-51 303-312 10/28/2003 CD2-07, CD2-10 31769 11/19/2003 12/24/2003 3014 373114.02 5973411.81 CD2-12 303-365 12/12/2003 CD2-57, CD2-31 32000 5/15/2004 6/14/2004 522 371071.29 5975445.60 CD2-58 NA 2880 372102.03 5972657.80 CD2-52 NA 2482 372637.61 5973661.63 CD2-20 CD2-55 304-288 7/30/2004 452 80 2004 371366.14 371118.23 5975507.11 5973194.84 CD2-40 NA 0 1342 370691.67 5973801.44 CD2-30 CD2-18 NA 0 1542 925 370473.52 . 369825.76 5973610.96 5974716.05 CD2-06 NA 0 1303 371610.81 5976018.45 CD2-27 304-226 6/23/2004 CD2-53, CD2-05, CD2-09 32000 7/9/2004 8!27/2004 3170 373046.07 5973071.83 CD2-10 304-289 7/30/2004 CD2-09, CD2-56 30703 8/27/2004 10/15/2004 1441 371800.58 5976006.36 CD2-07 NA 0 1945 372218.06 5976287.95 CD2-43 1650 370344.04 5973520.68 CD2-57 305-238 8/17/2005 CD2-01 19181 8/22/2005 9/12/2005 3394 372537.05 5972324.37 CD2-31 NA 0 1074 369824.37 5974451.30 CD2-53 CD2-05 304-361 9/30/2004 CD2-56, CD2-54, CD2-02 26072 0 10/3/2004 8/5/2005 3464 1460 372896.67 370258.60 5972509.19 5973735.40 CD2-09 304-362 9/30/2004 418 1144 370318.00 5976239.00 CD2-56 305-307 10/11/2005 CD2-404 11167 5/7/2006 5/23/2006 2227 369875.93 5973053.08 CD2-54 NA 0 1896 369991.09 5973363.59 CD2-21 CD2-59 included 379 1478 370286.77 369650.94 5975261.48 5974049.86 CD2-60 2875 371269.33 5972336.05 CD2-03 1409 371040.60 5976495.42 CD2-02 1559 369431.33 5976119.22 CD2-01 2619 373114.47 5976019.06 CD2-11 included 336 370835.25 5975420.76 CD2-404 included 0 370646.55 5975142.76 * Lateral distance in feet, between surface casing shoes, in the X-Y plane ** CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7"annulus has not been permitted for annular disposal. ***CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. **** As of 5/1/7 Note that this sheet is not the definitive record ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ac, 6' os`r' Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, .~` %~ ~ ~~ M.. Loveland ConocoPhillips Well Integrity Project Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31.2007 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 CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-109 6" na 6" na 2.5 2/18/2007 CD2=404 2-054 6" na 6" na 1.8 3/22/2007 CD2-7 203-187 16" na 16" na 7.5 2/17!2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17!2007 CD2-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/96/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 CD2-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 CD2-24 201-095 6" na 6" na 1 3/8/2007 CD2-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 CD2-28 202-217 29" na 29" na 11 3/8/2007 CD2-30 203-135 8" na 8" na 3 3/8/2007 CD2-31 204-082 15" na 15" na 6 3/8/2007 CD2-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 CD2-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 CD2-37 202-211 29" na 29" na 13.8 2/18!2007 CD2-38 202-171 18" na 18" na 8.5 2!18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 CD2-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 CD2-47 201-205 25" na 25" na 11.9 2/18/2007 CD2-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CD2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-55 203-118 13" na 13" na 6 2/18/2007 CD2-57 204-072 8" na 8" na 1 3/8/2007 CD2-58 203-085 6" na 6" na 1 3/8/2007 CD2-59 204-248 6" na 6" na 1.5 3!8/2007. CD2-60 205-068 6" na 6" na 1 3/8/2007 Re: CD2-404 Form 404 • Subject: Re: CD2-404 Form 404 From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Wed, 14 Feb 2007 13:22:04 -0900 To: "Crui7n-ine,'Tim ~'~~~1Gam" <"I~in~.W.Crumrine~acoi~ocophilli[~s.com? ~j (Q ---C7S ~-'~ Tim, If you could send the ops summary that would be fine. I understand that you plan to send a more complete packet to .Dave in the coming weeks. With the relatively short injection time, it is not surprising that your weren't able to do the MIT IA. I don't believe there is any problem there since you had people out there all the time and if any IA pressure would have developed, I presume that the necessary response would have occurred. Look forward to the summary, don't worry about all the pressure stuff. Tom Crumrine, Tim William wrote, On 2/14/2007 1:16 PM: Tom, I certainly do have an operational summary to go along with the 404. I planned on sending a presentation to Dave Roby by early next week regarding the operations, along with all the data requested from our 11/29 meeting (CD1 and 2 OA pressures, etc., plus the gauge data collected on the CD2-23 and 2-11 OA during the injection). If you would like it sooner, please let me know. ', FYI, we did get a good step rate test, and injection profiles at two ', different rates. Total injection was-26,000 bbls. I should be getting the BH gauge data this week to verify frac pressure during and reservoir pressure after injection. As a side note, we did not conduct an MIT IA during injection, but only prior to initiating injection. The well never ,stabilized long. enough for our folks to go out and collect a recording. Sincerely, Tim Crumrine, P.E. Senior Engineer Western North Slope Growth ConocoPhillips Alaska (907) 265-6402 office (713) 515-9190 cell -----Original Message.----- From: Thomas Maunder [mailta:tcm maunder~~admir_.state.ak.us] Sent: Wednesday, February 14, 2007 1:03 PM To: Crumrine, Tim William Subject: CD2-404 Form 404 Tim, We have received the 404 with attached CPAI MIT form and the chart. Is there an operational summary to go with it? If it is just for the MIT, there isn't much to write about but do you have a summary of the actual injection operations? This may have already been submitted. I haven't yet checked the file. Thanks in advance for your reply. Email is acceptable. Tom Maunder, PE AOGCC 1 of 2 2/14/2007 2:20 PM Addendum to AOGCC Form 10-404 Summary of Well Operations for the CD2-404 Conversion to Injector and Summary for Pilot Injection Order CD2-404 Summary of Injection Operations Injection of Beaufort seawater into the CD2-404 began on January 3 and continued until January 27, 2007. A total of 25,962 barrels of water were injected into the Qannik interval of the CD2- 404. Water was diverted from the CD2-06 Alpine injector via hardline piping. CD2 drillsite operators provided onsite monitoring of piping in accordance to CPAI HSE guidelines. During the injection period no water was injected into the CD2-06, so all metering and injection pressure readings recorded for the CD2-06 pertain only to the CD2-404. Please see Table 1 and Figure 1 for detailed pressure and injection volumes. The maximum pressure obtained during injection occurred on January 16 and was 1,214 psi at a rate of 2,980 bwpd. A maximum rate of 5,200 bwpd occurred on January 14. The corresponding pressure for the maximum rate was 990 psi. The pressure maximum during the full injection test period reached 1,336 psi with injection shut in. A mechanical integrity test during injection was not performed as pressures and rates did not stabilize during the injection period. Over the injection period, a step rate test was conducted to determine fracture pressure of the Qannik interval. Preliminary results indicate a surface pressure of 740 psi (2530 psi BH) with a corresponding rate of 1400 bwpd. BH gauge data should be available the week of February 18, 2007 to verify BH fracture pressure. Of course it is expected that as the reservoir gains pressure from injection the fracture pressure should increase. Also during the injection two 24-hour fall-off tests were performed in an attempt to determine skin values and skin variance as a function of injection rate and volume. Along with reservoir modeling these values may help in determining an optimized injection to withdrawal ratio for the Qannik project. I/W ratios will become of significant as CPAI moves forward with understanding potential cross-flow issues when discussing with the AOGCC conditions of an Area Injection Order. Two injection profiles were run via coiled tubing memory logging. The first profile was run at what CPAI believes is under fracture rate at 1,100 bwpd. The injection profile showed approximately 20-percent of water is injected at the heel of the well with injection occurring along the length of the well and at the toe. The second injection profile was run at what CPAI believes is above fracture rate at 3,200 bwpd. The injection profile showed approximately 60- percent of the water is injected at the heel with the remaining 40-percent injected along the length of the wellbore with a significant portion reaching the toe. • Table 1. Summary of Daily Injection Pressures and Rates Date Time on Inj./Day (hrs) Daily Total Water Inj. (bbls) Avg. Daily Pressure (psi) 1 /3/2007 12.5 422 308 1 /4/2007 24 1598 576 1/5/2007 24 1471 669 1 /6/2007 24 863 476 1 /7/2007 24 977 523 1 /8/2007 24 1030 558 1 /9/2007 24 1092 621 1 /10/2007 24 1100 658 1 /11 /2007 24 1124 696 1/12/2007 24 1091 708 1/13/2007 24 1056 705 1/14/2007 24 1433 666 1 /15/2007 24 2803 878 1 /16/2007 12.1 1589 1102 1/17/2007 0 0 596 1/18/2007 0 0 410 1/19/2007 20.6 702 521 1 /20/2007 24 235 590 1 /21 /2007 24 713 718 1 /22/2007 24 866 791 1 /23/2007 24 1045 849 1 /24/2007 24 1341 906 1 /25/2007 24 1478 899 1 /26/2007 24 1496 936 1 /27/2007 8.8 436 663 ~aeq~ aanssaad/a~eg •i aan~i~ Pressu re ~psi~ N O .A O O7 C O O O O O N O A O 6J O O O O O O O O O O 007 1 2 00 !312 1 : 1!4!2007 12:00 ~ 1!512007 12:OD 1f6120D7 12:00 1/7120D7 12:00 118!2007 12:00 ~ v 11912007 12:00 N a 1/1012007 12:DD ~ 1/11/2007 12:00 ro• A 1 f 12120D7 12:00 Q ~ 11131200712:00 ~ N 1/141200712:00 3 1!151200712:00 ~ ~ `'~ `~ 1/1612DD712:00 ~ 11171200712:00 ~ ~ ~ 1!1 812007 1 2:00 ~ ~ 1119!2007 12:00 H H 1!2012007 12:00 1/21/2007 12:00 t7 3 1122!2007 12:00 ~ 1 f23/20D7 12:00 1f24/2D07 12:00 1125!2007 12:00 112612D07 12:00 1f27f2D07 12 OD O O N C O J O A O CTi O 6J O O O O O O O O O O O O O Rate ~ bwpd) ConocoPhillips February 09, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 t Tim Crumrine Senior Engineer WNS Development P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6402 Subject: Submission of Form 10-404 Report of Sundry Well Operations for CD2-404 (Sundry # 306-282) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Form 10-404 Report of Sundry Well Operations for the conversion from pre-producer to water injector for the Alpine well ~ CD2-404 in accordance with Sundry Number 306-282. State witnessing of MIT was waived. The chart recording from the MIT IA is included with this submission along with a data sheet describing the conditions for the pressure testing. If you have any questions regarding this matter, please contact me at 265-6402. Sincerely, r,.. . r- . ~. ..... ~ ,^, _ Tim Crumrine, P.E. Senior Engineer CPAI WNS Development ~~~ ~'~~ Q ~ ~(~~7 ~~~ iii ~~ (4ff~~= ~rrris~i~ion . ,. _ An~~@r~p~i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Conyers. to WINJ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory^ 206-054 3. Address: P.O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ^ Service ^~ 6. API Number: ( 50-103-20530-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' CD2-404 8. Property Designation: 10. Field/Pool(s): ADL 380075, 25530 ~ Colville River Unit / Qannik Undefined Pool 11. Present Well Condition Summary: Total Depth measured 11540' feet Plugs (measured) true vertical 4066' ~ feet Junk (measured) Effective Depth measured feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 16" 114' Surface 2640' 10-3/4" 2693' ~~ ~ ~~ Intermediate Production 5508' 7-5/8" 5561' ffir Liner 5752' 3-1/2" 11083' ~~~ t3 ~ ~°)(~7 Perforation depth: Measured depth: ~Akll ~IA~ ~ ~~~ ~~1C)~`: ~(.}(•tit>h1~AiGt1 ~1fl$h9~'~~f ::. . ,._. True Vertical depth: Tubing: (size, grade, and measured depth) 3-112" L-80 5385' Packers and SSSV (type and measured depth) Liner Top Packer, No production packer, SSSV = 2237' i 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q ' Daily Report of Well Operations Summary and MIT IA 16. Well Status after work: Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ~ - WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-282 Contact Tim Crumrine Printed Name Tim Crumrine Title Senior Engineer Signature ~~~- _..` . y Phone 265-6402 Date 9-Feb-07 -- d~ ?. i3,o7 Form 10-404 Revised 04/2006 ~~ ~ ~~~ ~ ~ ~~~~ ~a`t 1 Submit riginal Only • MECr~ANICAL INTEGRITY TEST (Mr I') FORM ' WELL NO.: C' D~ - ~©~ DATE: ~Q -- j$ WELL TYPE: Pf~~..f~r ~ i,e,: Prod, Prod A/L, MI, SWI, PWI MIT TEST TYPE: ,~~~. i.e., Tbg, IA / 9-5/8", OA / 13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: a~(~n~:; psi. Note: Please consult the PWS if there's any questioh @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: ~J1E5i; ~ Record all Wellhead Pressures before and during Test ~~ T E START TIME: ~' ; ~ O PRE MIT PRESSURES (PSI) INITIAL MIT PRESSURES (PSI) 15 MINUTE PRESSURES (PSI)* 30 MINUTE PRESSURES (PSI}** PASS OR FAIL S TUBING `j O 2500 `-00 ~ T IA 'j O ~D v A-~ S OA 1 COMMENTS: T E START TIME: ~ 3',~ ~ PRE MIT PRESSURES (PSI) INITIAL MIT PRESSURES (PSI) 15 MINUTE PRESSURES (PSI)* 30 MINUTE PRESSURES (PSt)** PASS OR FAIL S TUBING ~ t~ ~ T IA / 9-5/8" '~ 5 a Oa ~ ' t~fi-gS OA/ 13-318" x.15 8a 0a ba 2 COMMENTS: T E START TIME: PRE MIT PRESSURES (PSI) INITIAL MIT PRESSURES (PSI) 15 MINUTE PRESSURES (PSI) 30 MINUTE PRESSURES (PSI) PASS OR FAIL S TUBING T IA J 9-5/8" OA ! 13-318" 3 COMMENTS: !,MISC COMMENTS: ~ . . Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization -press loss second 15 min < 50% press loss first 15 min FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. ® -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: ~~~s~t~L~ cc: PWS 6/3/00 N~~~ - - ---__- ~~ ~,~ - , j aspp : _-:-- -'-- ice- 1 \,. ~L ~_ /' J~ ~ / / ~ \ / i/// ' ~ / ~/i i ..: i ~~ ,'/i /,' % i~ ~/'~~ // ~ ~ / D //~~ ~j // /~,i , i/. ;/ / ~~ _ ~,_ i ~ /, ~ , / / ; ~ ;/r ~,, / '~;/ i // ~ ' / / /~~~ % ~~ ~ i/ ' ~ !i /r r / / i/ / r / / ~~i -y ,~~ ~ t __ ~i% ~~<,r /.//!r i/r ~i/ !/~i/ % '///~i% a p ~ ~ 000 ~/ r,, ~ ~ ///~~~/, , '~/ / ~%/j i ~, j/ / ~i~ c,~0 _ ~, ' t ~ ~~~ '~ r/~~~ ~~. 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X110 ~~' IWi 1 !, ~ , I;~ ~ , I j. III I;~'l I + 1 ~ ~ ~ 1~1~. I _ ` ~~Jy 'I'~'~';`, ' O I lI 1« `t ' I ~, I' II~, I I~I~V~, II~Itn 11,,.1 ~,~, ~ I I, .`~-. ~ wy( r I r. f; O ,r`A1 ,1 .II~ 1 l~ I ' t I t. , A~A I I t ~~ - ~ r G- 1t\~ 7r,~ ~r~ ~ l 1 , i -I O ~ ~j II . \ \ ~~ ~. .' '~ \ `, \ V ~ ~ !1` / :~ r~ , ~ p ~ ~ ~ ~~, ~ ~ _ _ ~-----r,- _ pp~ ~- ,. Ob r _ ~_ ~~ ~ i.'i S,~ ~ -~ - , '~` ` ~ - - - 0~~' ~~ _ \~ / ". - - i G7 __ _._._ - ,~~ r ~~L !_~.-_-~: yy T1~~41 /V~f~/CAL ProActive Diagnostic Services, Inc. To: State of Alaska - AOGCC Howard Okland 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fay (907) 245-8952 1) 1 EDE CD2 - 404 Injection Profile 2) 3) 4) 6) ~) Signed Print Name: (:~~~~t-~, OYla~a,~~ 14„1an-07 ~~ ~ % . _ ~;~; Date : ~:S~f~~ ; . _ p ., _ . ~:~; PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAx: (9071245-8952 E-MAIL : 'CSIa;dGN®P,:O,GE(l~NiESN©;?Y' OG.~O~JI WEBSITE : ll1MPt~1,ME4410f2`fLt7G.~,~Jt~7 D:\Master_Copy_00_pDSANC-20xx~Z_ Word\Dishibution\Transmittal_Sheets\Transmit_Original. doc • • VV~L~ ~4~ ~~,-.°'' Ti4,4/1/Sfl/1/•4L ProActive Diagnostic Services, Inc. To: State of Alaska - AOGCC Howard Okland 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907j 245-8952 1 ] 1 EDE CD2 - 404 2) 3) 4) 5) Injection Profile 16-Jan-07 61 c~b(~-o~~l ~' ~y~~$0 7] ,~ ~ ~,. _ ~ -~' ~~ ~ 4 2~~~ Signed : - Date a Print Name: ~fn r'~!,~-~ Wt0 ~1,aln~~ ~/~ pr., use PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAx: (9071245-8952 E-MAIL : ~OSfaHCI~lOR.~tiE(~MEIdlO€2b. E.fJG.iL1M WEBSITE :'J~MNU.i~Es'1101?Y~.OG.f.OM D~1Master_Copy_00_PDSANC-20pc~Z Word\Distribution\Transmithnl_SheetslTrazismit_Otiginal.doc • VV~L.L~ _ Y _~ ProActive Diagnostic Services, Inc. To: State of Alaska - AOGCC Howard Okland 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax. (907) 245-8952 1) 1 EDE Cd2 - 404 Injection Profile 14&1 S-Jan-07 (run 1 &2) 2) 3) 5) s) 7) l1 V Signed Print Name: In ~;~.~}~~ g-~l~~a l~er~ ~~ ~~, '` " ~ -~ ~:. Date °"` _ k ~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907245-8951 FAX: (907245-8952 E-MAIL : 'OSial~9C;$OR,d' CECC~MEh9oi2','~ oG.CvM WESSITE : ?I~,fWVt/.i~ElVi0E2'fLOCs.COPdI D:~1Kaster_Copy_00_PDSANC-20~oc~Z_Word\Distd6utionlTransmittal_Sheets\Transmit_Original.doc RE: CD2-404 Qannik Well • • Subject: RE: CD2-404 Qannik Well From: NSK Well Integrity Proj <N1878@conocophillips.com> Date: Thu, 08 Feb 2007 12:17:58 -0900 To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: NSK Well Integrity Proj <N1878@conocophillips.com> ~ ~~ Tom, According to my notes we have a erio4 (what ever that is) allowing temp injection. If it changed the status of the well it hasn't hit our database yet (which doesn't surprise me). I'll check with town to see what they filed. Thanks MJ From: Thomas Maunder [mailto:tom_maunder@admin,state.ak.us] Sent: Thursday, February 08, 2007 11:07 AM To: NSK Well Integrity Proj Subject: Re: CD2-404 Qannik Well MJ, You might want to check on the well category. order to all that part of the operation to proceed 404 changing the status. Tom Maunder, PE AOGCC There was quite a "hoop and loop" including an injection I haven't checked the file, but there should have been a NSK Well Integrity Proj wrote, On 2/8/2007 10:50 AM: Tom, You are right, it was an injection test. Sorry for the miss information. First morning back... I didn't do any research and the well supervisor said the test was finish and I saw the well is categorized as a producer.... teach me for cutting corners. But we will have the well SI and Freeze protected. Thanks MJ From: Thomas Maunder [mailto:tom maunder@admin.state.ak.usl Sent: Thursday, February 08, 2007 8:57 AM To: NSK Well Integrity Proj Cc: NSK Problem Well Supv Subject: Re: CD2-404 Qannik Well Hi MJ, I remember a production test shortly after drilling. Wasn't the latest work an injection test? The method to secure the well is CPAI's choice. As you note, the well will be SI. Whatever method you all choose, the important point is that the well is freeze protected. Call or message with any questions. '~ 1 of 2 6/20/2007 7:57 AM RE: CD2-404 Qannik Well • Tom Maunder, PE AOGCC NSK Well Integrity Proj wrote, On 2/8/2007 8:48 AM: Tom, The Qannik well CD2-404 (PTD 206-054) has completed its production test and is slated to go into "stand by" mode for a temporary but unknown amount of time while waiting for logistics to come together for the development. It currently has tubing and casing integrity and is just waiting on the development to catch up. Is there an AOGCC preferred method to secure the well or will SI with a BPV be sufficient? Please Advise. Thanks MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 448-3114 2 of 2 6/20/2007 7:57 AM SARAH PALIN, GOVERNOR 333 W. 7`e AVENtiE, SU[TE 100 ANCHORAGE, ALASK4 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 Tim Crumrine Alpine Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Qannik Undefined Oil Pool, CD2-404 Sundry Number: 306-282 Dear Mr. Crumrine: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after .written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this, day of December, 2006 Encl. ~~(~~: tom( Sincerely, WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-404, r October 16, 2006 AK-MW-4348860 CD2-404: Digital Log Images: 50-103-20530-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A1~1D RETURl~'IIVG THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~: ~, ,,~ ~~, ', ; r~ , ~,, ,~ -r_ Dat,~~ ~` ; i' ~~, Sgt.;,.. _~Cj(.r~ ~S '~ Signed: r ~- ~~'-! I '~~ • • ~~ ~~~' Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth RECEIVED SEP 1 5 2006 F118Ska Oil & Gas COas. COIr-tiU8810f1 Well Job # Log Description NO. 3988 Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Date BL Prints CD ~CD2-404 ~ 11216316 PROD PROFILE W/MAXTRAC ~ 08/25/06 ~ 1 ~ ~ ~ ~ SIGNED: DATE: 09/15/06 ,. • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. Tim Crumrine Alpine Engineer Alpine Development ` „ P. O. Box 100360 ~rr% Anchorage, AK 99510-0360 ~~~~~~~~ ~ ~ ~ ~~ Phone: 907-265-6402 August 16, 2006 14~~E~~ED Commissioner State of Alaska AEG 17 X006 Alaska Oil & Gas Conservation Commission Alaska 011 & Ga 333 West 7th Avenue Suite 100 s Cons. ~ Anchorage, Alaska 99501 Anchor~D~ °~~ss~on Subject: Application for Sundry Approval for CD2-404 (APD # 206-054) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the upcoming conversion from pre-producer to an injector on the Alpine well CD2- 404. ' If you have any questions regarding this matter, please contact me at 265-6402. Sincerely, T. Crumrine Alpine Engineer CPAI Alpine Development TC/skad _, . ~~. °~ '~~i~ ~~~EIVEp STATE OF ALASKA ~ ~U '- (`~ A(f ~j `~ ~ 7 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska pi! & APPLICATION FOR SUNDRY APPROVAL gas Cons. COmmiss~on 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^/ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ NVIIVCI JIVII W Time Extension ^ Injector Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 206-054 `~ 3. Address: Stratigraphic ^ Service ^/ 6. API Number: ~. P. O. Box 100360, Anchora e, Alaska 99510 50-103-20530-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO Q CD2-404 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380075, 25530 - RKB 36' Colville River Field / Kanik Undefined Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11540' ~ 4066` Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2640' 10-3/4" 2693' PRODUCTION 5508' 7-5/8" 5561' SLOTTED LINER 5752' 3-1/2" 11083' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1 /2" L-80 5385' Packers and SSSV Type: Packers and SSSV MD (ft) Liner top packer, no production packer SSSV= Tubing Retrievable SSSV= 2237' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: August 29, 2006 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ - WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Crumrine @ 265-6402 Printed Name Tim Crumrine Title: Alpine Engineer Signature Phone 265-4021 Date Commission Use Onl Sundry~~ tuber: Conditions of approval: Notify Commission so that a representative may witness "~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~'Qx'c'U~~~O~~; ~ r~ 0.000 ~ ~ l C ~~. 'tea ~ ~I`~,. ~~.` ~ ~' 1~~U Subsequent Form Required: (.,.~~ t--~ APPROVED BY (p •• Qs 0 ~ Approved by: COMMISSIONER THE COMMISSION Date: ~ Form i 0-403 Revised 06/2006 ~~ ~ ~ ~ ~f N~ Submit in Duplicate 1~1~~ Iz. • /g ~~ t • • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 10-403 ATTACHMENT -DESCRIPTION SUMMARY OF PROPOSAL The CD2-404 well (Colville River Unit / Qannik (Kanik) Undefined Pool) was drilled as an injector, but is currently set up as a temporary producer in order to test the well, run production logs, and establish a decline to further define the commerciality of developing the Qannik field. The well has produced at average rates of 1100 -1200 STBOPD with a GOR of 900 Mscf/bbl. In order to further outline the commerciality of the Qannik field, a water inj ectivity and water flowback needs to be performed. A surface jumper line will be run from an adjacent water injector not currently taking water to the CD2-404 well. In order to covert from temporary producer status to injector the following procedure is proposed. 1. Set plug in XN nipple to isolate formation pressure and prevent an influx of hydrocarbon. 2. Pressure test plug 3. Reverse circ. 116 bbls inhibited brine (kill fluid) down the IA followed by 85 bbls of diesel for annular freeze protection. 4. Set Dummy Valve in GLM 5. MIT Inner Annulus -Pressure test backside to 2500 psi (casing tested to 3500 psi 5/23/06) 6. MIT Tubing -Pressure test tubing to 2500 psi (tubing tested to 3500 psi 5/23/06) 7. Pull XN plug 8. Pump 22 bbls (at 1 bpm max) diesel down tubing for freeze protection 9. Function test SSSV ~~~~~~ ~C:iANICAL INTEGRITY REPORT n ~ LL D:.T=- TD : ?~_ ID 'I'~VD ; ?BTD SID a s i ~ : ~1'j4S" Shoe : J _~ t-ID ~6~ ~ TV"D ; D ~I : l~l ~ ?~ ~~~ TGD -=:,e.: Shoe : ~-' ; .C ~~~~ Pacxer 5~, - tea' - ~ --o- - ~:~~ ana ~ 'S~`~~ ~~Cra?~=C~.y INTEGRITV - ~n.RT #I ~nrulus ?ress Test: -? ! ~ mrn Ca~ents . ~0 min i '~'CR.~N1C~ ~. 1NTEGRIT~ - PART # Z ~-~-'r~ 1\b = ~`-~~hLS Cement Volumes :~ Amt. Liner ~ CsQ 3~~ ~ DV ~-~. Crt -.rol to cover- oer=s \3~-l.S~ Sai~ZC``C~~ ~o CO~;C~C- ~n ~'''C ~t'~~c ~' ~ ~`~~a~~ _::eoretical TOC ~ ~~~~~c, ~ ~'dC =% ~~~ ~ - ?roductian Log: Type A ~/`}t ~~ AOGCC File ~~ Cem_nt Bond Log (Yes ar No) ~~5 t CBL Evaluation, tone aoove perfs ~~< <~ 5~'U `oc o~E~~\~ ~~ e~:~,A ~,~.~.=.~ m ~ ~- ~- ~~~ tic. ts~~~~ro ~ y CONC-LJS~ONS: ?art r 1 ?art f2: ~~`~~ \~5\`C< t~~~~ ~ - Evaluation • ConocoPhillips July 24, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-404 (APD 206-054) Dear Commissioner: P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ConocoPhillips Alaska, Inc. submits the amended Well Completion Report for the recent drilling operations on the Alpine wells CD2-404. We have modified the well summary to include the tests performed on this well. 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 ~ JUL 2 4 2006 ALASKA OIL AND GAS CONSERVATION COMMISSIONQ+a 0 WELL COMPLETION OR RECOMPLETION REPOI~~' ~-~„rL~~"~mission 1a. Well Status: Oil Q Gas Plugged Abandoned Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ^ Exploratory Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., .~'~j ~ ~~, orAband.: May , 2006 .. 12. Permit to Drill Number: 206-054 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 8, 2006 13. API Number: 50-103-20530-00 4a. Location of Well (Governmental Section): Surface: 1606' FNL, 1559' FEL, Sec. 2, T11 N, R4E, UM 7. Date TD Reached: May 18, 2006 14. Well Name and Number: CD2-404 - At Top Productive Horizon: 286' FSL, 1458' FWL, Sec. 35, T12N, R4E, UM 8. KB Elevation (ft): 36' RKB 15. Field/Pool(s): Colville River Field Total Depth: 956' FSL, 928' FWL, Sec. 26, T12N, R4E, UM 9. Plug Back Depth (MD + TVD): 11540' MD / 4066' TVD Undefined Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371686 y- 5974751 Zone- 4 10. Total Depth (MD + TVD): 11540' MD / 4066' TVD 16. Property Designation: ADL 380075, 25530 TPI: x- 369453 y- 5976682 Zone- 4 Total Depth: x-369019 ° - 5982640 Zone- 4 11. Depth where SSSV set: SSSV @ 2237' 17. land Use Permit: ALK 380075 18. Directional Survey: Yes ~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1798' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 36' 114' 36' 114' 42" pre-installed 10.75" 45.5# L-80 36' 2693' 36' 2383' 13.5" 568 sx AS Lite, 280 sx Class G 7-5/8" 29.7# L-80 36' 5561' 36' 4071' 9-718" 310 sx Class G 3.5" 9.3# L-80 5331' 11083' 4054' 4077' 6.75" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" / 3.5" 136' / 5385' 5331' slotted liner from 5331' - 11083' MD 4054' - 4077' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production June 7, 2006 Method of Operation (Flowing, gas lift, etc.) Gas Lift Date of Test June 6-27, 2006 Hours Tested 467 hours Production for Test Period --> OIL-BBL 23765 GAS-MCF 20394 WATER-BBL 50 CHOKE SIZE 88/64 GAS-OIL RATIO 861 Flow Tubing press. 330 psi Casing Pressure 610 psi Calculated 24-Hour Rate -> OIL-BBL 1219 GAS-MCF 1049 WATER-BBL 0 OIL GRAVITY -API (corr) 28.5 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". COMPLETION PATE ~tBDMS BFI JUI. 2 6 2006 - ~' ~ ~ `~ NONE ~[~tm Form 10-407 Revised 12/2003 R r ! ~` CONTINUED ON REVERSE /~~ r Ls~i ~j iI ~~~ 4 ~7 r-~ 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". CD2-404 K-3 4661' 3846' K-2 5502' 4067' SEE ATTACHED SUMMARY 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Summary of WeII Tests 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name /) ~ Chip~Alvord Title: Alpine Area Drilling Team Leader 712~~D~ ' ^ 'G '' Signature iN .~.. V - Phone u, 5 - (y l ~p Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 all test information. If none, state "None". Form 10-407 Revised 12/2003 Interval Data Testing of the K2 and K3 intervals Horizontal Section Length - 5979' Gross Sandstone Interval - 4094' Slotted Liner Footage - 3000' TVDss - 4015-4037' MD - 5561-11,540' Testing Data Bottom Hole Static Survey Timing: 5/28/2006 15:5 5 Purpose: Determine static BH pressure Method: Slickline using Halliburton Panex Gauge WHSIP - 450 psi (w/ 6.7 ppg Diesel to 4482' MD) BHSIP - 1947 psi BH Temp: 86 deg F • Pressure Drawdown Test Timing: Testing began June? (20:45) continued to June 27 (08:30) Purpose: Establish decline, determine if well can produce at commercial rates Method: The CD2-404 produced through Power Well Services portable test separator for metering purposes. Effluent from separator outlet routed from test separator through the CD2-09 wellhead (manned operation 24/7). Bottomhole pressure memory gauges were installed in the lower side pocket mandrel. Production Method: The well was gas lifted with 500 Mscf/day to a max 1 MM scf/day to establish various flowing BH pressures and determine critical drawdown pressure. Max Wellhead Pressure - 700 psi Max Casing Pressure - .1200 psi Average BHFP 700 psi. Average wellhead pressure 310 psi. Average Oil Rate 1,200 STBOPD Average GOR 850 scf/d 0% CO2 and 0% H2S Average BS&W 0%. Pressure Build Up Test Timing: Began June 27 (08:30) -July 4 (14:00) Purpose: Establish boundaries, gas cap distance, compare results to drawdown Method: Build Up occurred with BH memory gauges installed in lower side pocket mandrel (SPIDR gauges on wellhead) and lasted 7 days. Results: Pressure built up to 1500 psi BH pressure / 1300 psi surface before gauges were removed. C] ConocoPhillips July 20, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-404 (APD 206-054) Dear Commissioner: ~~~~~~E~ JUL 2 1 2006 Alaska Oil & Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine wells CD2-404. 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 GCA/skad G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION I~EGEIVED au~ 2 ~ 2006 WELL COMPLETION OR RECOMPLETION REPOR~IaI~Ic®Ons. ~i?f11ff11ssl0ii 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1 b. Well Class: Af1ChOk 8~6 Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., y~ ~ Z~. or,4band.: May , 2006 Permit to Drill Number: 206-054 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 8, 2006 13. API Number: 50-103-20530-00 4a. Location of Well (Governmental Section): Surface: 1606' FNL, 1559' FEL, Sec. 2, T11 N, R4E, UM ' 7. Date TD Reached: May 18, 2006 ~ 14. Well Name and Number: CD2-404 At Top Productive Horizon: 286' FSL, 1458' FWL, Sec. 35, T12N, R4E, UM 8. KB Elevation (ft): 36' RKB 15. Field/Pool(s): Colville River Field Total Depth: 956' FSL, 928' FWL, Sec. 26, T12N, R4E, UM 9. Plug Back Depth (MD + TVD): 11540' MD / 4066' TVD Kanik Undefined Pool ~'" 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371686 - y- 5974751 ' Zone- 4 10. Total Depth (MD + TVD): 11540' MD / 4066' TVD • 16 roperty Designation: ADL 380075, 25530 TPI: x- 369453 y- 5976682 Zone- 4 Total Depth: x-369019 - y- 5982640 • Zone- 4 11. Depth where SSSV set: .f''~ SSSV @ 2237' 17. Land Use Permit: ALK 380075 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: ,,r'' N/A feet MSL 20. Thickness of Permafrost: 1798' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SET1+tNG DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TQP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 36' 114' `' 36' 114' 42" pre-installed 10.75" 45.5# L-80 36' 2693' 36' 2383' 13.5" 568 sx AS Lite, 280 sx Class G 7-5/8" 29.7# L-80 36' 5561' 36' 4071' 9-7/8" 310 sx Class G 3.5" 9.3# L-80 5331' 1108 4054' 4077' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom, ~ r.~ 24. TUBING RECORD Interval, Size and Number; if none, state "none"): ~"~% SIZE DEPTH SET (MD) PACKER SET . f7 4.5" / 3.5" 136' / 5385' 5331' slotted liner from 5331' - 11083' MD 54' ;4077' TVD j ,rf ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. r'{ > ~ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~ R/ ~ h n/a ~ f 1;~~,~ ~ U 26. PRODUCTION TEST Date First Production June 7, 2006 Method of Operation (Flowing, gas lift, etc.) Gas Lift Date of Test June 6-27, 2006 Hours Tested 467 hours Production for Test Period --> OIL-BBL 23765 GAS-MCF 20394 WATER-BBL 50 CHOKE SIZE 88/64 GAS-OIL RATIO 861 Flow Tubing press. 330 psi Casing Pressure 610 psi Calculated 24-Hour Rate -> OIL-BBL 1219 GAS-MCF 1049 WATER-BBL 0 OIL GRAVITY -API (corr) 28.5 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". NONE Form 10-407 Revised 12/2003 { C TI EI~N~R~V~R~E { ~x ~/ r..a ' ; { 'dam ~~ ~ `"xb ~ ~// 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 cronducted, state "None". CD2-404 K-3 4661' 3846' K-2 5502' 4067' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name Chi Alvord Title: Alpine Area Drilling Team Leader / Signature ~~i ~~ Phone u~ ~ (~ ~ ~ Date 7l i~ ~~ INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 all test information. If none, state "None". Form 10-407 Revised 12/2003 S . . ~ . ~onocoPh~lip-s Time Log Summary kk2lh iew iNeU Reporting Time Logs Date From To Dur S, De th E. De th Phase Code Subcode T COM 04/27/2006 00:00 02:00 2.00 MIRU MOVE __ RURD P Prep rig for move -disconnect service lines -blow down steam & water s stem -move motor & it com lexes 02:00 14:00 12.00 MIRU MOVE MOB P Move camp -sewer treatment plant & shop to CD4 -Move Ball mill -pit & motor complexes & sub base f/ CD3-307 to CD2-404 -Ball mill -pit & motor complexes on location -sub still in route 04/28/2006 00:00 16:00 16.00 MIRU MOVE RURD P Finish moving sub base f/CD3 to CD2 -Set out BOPE stack -Move over CD2-404 -Spot motor & pit complexes - spot pipe shed -connect service lines -Accept rig @ 1600 hrs. - Suspend well ops and begin rig maintenance 05/07/2006 18:00 00:00 6.00 114 114 SURFA DRILL OTHR P Take on spud mud -Work on TD - MU BHA 05/08/2006 00:00 00:30 0.50 114 SURFA DRILL PULD P Continue to MU BHA #1 00:30 00:45 0.25 SURFA DRILL SFTY P Held PreSpud safety meeting with rig team 00:45 01:45 1.00 114 SURFA DRILL OTHR P Fill conductor with mud -check for leaks -pressure test mud lines to 3500 si -clean out conductor to 114' 01:45 09:30 7.75 114 673 SURFA DRILL DDRL P Drill from 114' to 673' MD 668' TVD PUW 105k SOW 105k RotWt 105 500 gpm / 900 psi / 40 rpm Torque on/off btm 7000/6000 ft/Ibs ADT- 3.94 hrs ART .73 hrs AST 3.21 hrs Surve with G ro 09:30 10:30 1.00 673 673 SURFA DRILL CIRC P Circ hole clean 620 gpm / 800 psi - Run G ro surve 10:30 11:30 1.00 673 40 SURFA DRILL TRIP P POOH on trip tamk from 673' to 40' 11:30 13:00 1.50 40 164 SURFA DRILL PULD P MU BHA #2 13:00 13:45 0.75 164 673 SURFA DRILL TRIP P RIH from 164' to 615' -precautionary wash down from 615' to 673'. 13:45 00:00 10.25 673 1,833 SURFA DRILL DDRL P Drill 13 1/2" hole w/ motor f/ 673' to 1833' MD - 1674' ND ADT - 5.58 hrs. =ART - 3.11 hrs AST 2.41 hrs WOB 25 k RPM 50 GPM 600 @ 1800 psi String wt. PU 123 SO 118 Rot 122 Tor ue on/off btm. - 7,500/6,000 ft/Ibs 05/09/2006 00:00 09:30 9.50 1,833 2,603 SURFA DRILL DDRL P Drill 13 1/2" hole w/ motor f/ 1,833' to 2603' M D ~.d ~ . ~~_ ~ ®e ~ ~_~_ .e.._ s.. ~ P~~ 7 ~sf'~#J a , ~ . ~~ ~ m A _... w ..... ~..~....~~~ .~..,~ Time Los ----- - _ Date From To Dur t~h _E. Depth Phase Code Subcode T .,OM 05/09/2006 09:30 10:30 1.00 2,603 2,603 SURFA RIGMN OTHR T Drag chain jumped sprocket -repair dra chain 10:30 11:30 1.00 2,603 2,702 SURFA DRILL DDRL P Drill 13 1/2" hole w/ motor f/ 2,603' to 2,702' MD Since Midnight - ADT - 6.83 hrs. _ ART - 6.13 hrs AST 0.7 hrs WOB 20/30 k RPM 50 GPM 700 @ 2850 psi String wt. PU 145 SO 120 Rot 135 Tor ue on/off btm. - 8,500/7,500 ft/Ibs 11:30 13:45 2.25 2,702 2,702 SURFA DRILL CIRC P Circ hole clean -increase mud wt. from 9.8 to 10.0 ppg - 700 gpm ! 2570 si/70r m 13:45 16:30 2.75 2,702 1,007 SURFA DRILL TRIP P Flow check well, static -Wipe hole from 2702' to 1,007' - 600 gpm / 2085 psi / 50 rpm -slowed pump to 500 gpm from 1,738'. Flow check well @ 1,007, static. 16:30 17:30 1.00 1,007 2,702 SURFA DRILL TRIP P RIH from 1,007' to 2,625' - no problems - Precautionary wash and ream from 2,625' to 2702'. 17:30 19:00 1.50 2,702 2,702 SURFA DRILL CIRC P Circulated hole clean @ 700 GPM 2950 si. 19:00 21:30 2.50 2,702 164 SURFA DRILL TRIP P POOH on trip tank. Hole fill normal. 21:30 23:30 2.00 164 0 SURFA DRILL PULD P Laid down BHA. Hole fill normal. 23:30 00:00 0.50 0 0 SURFA DRILL PULD P Cleared rig floor. Hole taking fluid at Est. 100 BPH. Mixin LCM. 05/10/2006 00:00 00:30 0.50 0 952 SURFA WELCT TRIP T RIH w/open ended 5" drill pipe to 952' - filling hole with trip tank -estimated losses 80 b h 00:30 02:15 1.75 952 952 SURFA WELCT CIRC T Mix and pump 35 bbls LCM pill @ 25 ppb -monitor well on trip tank -losses @ 60-80 bpm Mixin lar er volume ill 02:15 04:45 2.50 952 952 SURFA WELCT CIRC T Mix and pump 150 bbls of 9.7 ppg mud with 25 ppb LCM -pumped until) LCM back across shakers 04:45 05:30 0.75 952 952 SURFA WELCT OTHR T Monitor well -losses @ 6-8 bph 05:30 06:00 0.50 952 0 SURFA WELCT TRIP T POOH with drill pipe 06:00 08:00 2.00 0 0 SURFA CASIN( RURD P RU to run 10 3/4" casing 08:00 08:15 0.25 0 0 SURFA CASIN( SFTY P Held PJSM with crew 08:15 09:15 1.00 0 164 SURFA CASIN( RNCS P PJSM -Ran 10 3/4" 45.5# L-80 MBTC as follows: Float shoe (Wetherford) 2 jts. -float collar(Halliburton) 2 jts.(first 4 connections made up w/ BakerLoc) filled i e & checked floats 09:15 12:00 2.75 164 821 SURFA CASIN( RNCS P Run 10 3/4" 45.5# L-80 MBTC from 164' to 821' -washed down through tight spots on joints #'s 4, 11, 12 and 15 with 4.0 bpm with good returns. (20 'oints total ~~rlcaf~ I _._. ___~._ Time Lo~_ Date From To Dur th E. Depth Phase Code Subcode T ._ . OM _ 05/10/2006 12:00 16:15 4.25 821 2,693 SURFA CASIN( RNCS P Run 10 3/4" 45.5# L-80 MBTC from 821' to 2,648' -washed down through tight spots on joints #'s 26, 29, 32, and 33 - 4.0 bpm with good returns. (65 joints total) MU FMC fluted hanger and LJ -Land casing with shoe @ 2,693', FC 2,605': 16:15 17:00 0.75 2,693 2,693 SURFA CEMEf~ RURD P Lay down fill-up tool - MU Dowell cement head and lines -establish circulation with 2.5 b m / 350 si 17:00 20:45 3.75 2,693 2,693 SURFA CEME~ CIRC P Circulate and condition mud for cementin 20:45 23:30 2.75 2,693 0 SURFA CEME~ DISP P Cement 10 3/4" casing as follows: Pumped 40 bbls. biozan water w/ nut plug - 6.5 bpm @ 350 psi w/ rig pump - Switch to Dowell -Pumped 3 bbls water -test cement lines to 2500 psi - Dropped btm plug -Mixed & pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.4 bpm @ 120 psi - Mixed & pumped 449 bbls of lead slurry (ASL "G" w/ 30% D-53, 0.6% D046, 1.5% D079, 1.5% S001, 43.1% D124, 9% BWOW D44, 0.5% D-65) @ 10.7 ppg - 7.5 bpm @ 420 psi - switched to tail slurry 58 Bbls ("G" w/ 0.2% D46, 0.3% D65, 2% S001) @15.8 ppg-5.6bpm@365 psi Dropped top plug & pumped 20 bbls water w/ Dowell -Switch to rig pumps - Displaced w/ 9.7 ppg mud @ 6.7 bpm 340 to 860 psi for first 225 bbls - slowed to 4 bpm @ 700 psi for last 6 bbls. -Bumped plug t/ 1150 psi - CIP @ 2314 hrs, floats helds. Full returns during job w/ 250 bbls cement returns to surface - recripcated pipe until 449 Bbls of lead slurry away, landed han er on landin rin . 23:30 00:00 0.50 0 0 SURFA CASIN( DHEQ P Tested casing to 2500 psi for 30 Min. 05/11/2006 00:00 01:15 1.25 0 0 SURFA CASIN( RURD P RD cement lines and head - LD casing elevators and Landin 'oint 01:15 02:30 1.25 0 0 SURFA CASIN( NUND P PJSM - ND surface riser - LD mousehole 02:30 04:00 1.50 0 0 SURFA CASIN( NUND P Remove FMC speed head -install wel Ihead 04:00 07:15 3.25 0 0 SURFA WELCT NUND P NU BOP stack -set in mousehole 07:15 07:30 0.25 0 0 SURFA WELCT SFTY P PJSM with crew -Testing BOPE E € _.~~....~ _._. ._.... s .~ _ ~ m~ ~ Time Logs Date From To Dur th E De th Phase Code Subcode T _ OM 05/11/2006 07:30 09:00 1.50 0 0 _ SURFA WELCT BOPE P RU & test BOPE - Hydril to 250 & 3500 psi -.pipe rams, blind rams , choke & kill line valves, choke manifold TD IBOP's, dart & floor safety valve to 250 & 5000 pis -Performed accumulator closure test. witnessing of test waived b Jeff Jones, AOGCC 09:00 10:00 1.00 0 0 SURFA WELCT BOPE T Test pump hose failed -replace hose 10:00 14:00 4.00 0 0 SURFA WELCT BOPE P Continue testing BOPE 14:00 19:00 5.00 0 0 SURFA WELCT BOPE T Performed test #8, observed drip at lower mud cross flange -tightened flange and re-tested, no good. Seperate mud cross from lower pipe rams 19:00 21:00 2.00 0 0 SURFA WELCT BOPE P Finished testing BOPE 250/5000 psi. Pulled test lu and set wear bushin . 21:00 22:15 1.25 0 0 SURFA WELCT NUND P Nippled up riser and flowline. 22:15 00:00 1.75 0 80 SURFA DRILL PULD P Picked up BHA # 3. 05/12/2006 00:00 01:30 1.50 80 716 SURFA DRILL PULD P Finish initializing MWD - PU 3 6" nm flex collars and drilling jars -RIH to 716' -shallow test MWD 01:30 02:30 1.00 716 2,590 SURFA DRILL TRIP P RIH from 716' to 2,424' wash ddown from 2,424', to ed cement 2,590' 02:30 03:15 0.75 2,590 2,702 SURFA CEME~ DRLG P Drill out cement to fc, drill out FC, cement to shoe, FS, and clean out rathole to 2702' - 600 gpm / 1910 psi / 40 r m 03:15 03:45 0.50 2,702 2,722 SURFA DRILL DDRL P Drill 20' of new hole to 2722' 600 gpm/ 1970 psi / 40 rpm ADT= .13 hrs ART .13 hrs. 03:45 04:15 0.50 2,722 2,722 SURFA CEMEI~ CIRC P Circ hole clean for PIT 04:15 05:00 0.75 2,722 2,722 SURFA CEME~ FIT P RU and perform PIT to 18.1 ppg EMW - ri down lines, blow down a ui ment. 05:00 12:00 7.00 2,722 3,333 INTRM1 DRILL DDRL P Drill 9 7/8" hole w/ motor f/ 2,722' to 3,333' MD 2,907' TVD ADT - 4.72 hrs. =ART 4.64 hrs AST 0.08 hrs WOB 10/12 k RPM 80 GPM 650 @ 2360 psi String wt. PU 160 SO 120 Rot 135 Torque on/off btm. - 9,000/8,000 ft/Ibs ECD 10.2 - 10.4 12:00 00:00 12.00 3,333 4,637 INTRM1 DRILL DDRL P Drill 9 7/8" hole w/ motor f/ 3,333' to 4,637' MD 3,847' TVD ADT - 8.45 hrs. =ART 5.36 hrs AST 3.09 hrs WOB 10/15 k RPM 90 GPM 700 @ 2700 psi String wt. PU 180 SO 130 Rot 155 Torque on/off btm. - 11,000/10,000 fUlbs ECD 10.4 - 10.7 . ® ®~ ~ ~ ® s~® __. ~~s ~ ~ ~ Y .-_. ®-..a _ ~ _,~ ~ _.._ ,.-P,.P .. Time Loti~ ~ _ Date From To Dur th E. De th Phase Code Subcode T .,tJM 05/13/2006 00:00 08:30 8.50 4,637 5,571 INTRM1 DRILL DDRL P Drill 9 7/8" hole w/ motor f/ 4,637' to 5,571' MD 4,072' TVD ADT - 5.26 hrs. =ART 3.37 hrs AST 1.89 hrs WOB 10/15 k RPM 90 GPM 700 @ 2850 psi String wt. PU 185 SO 125 Rot 151 Torque on/off btm. - 12,000/11,500 ft/Ibs ECD 10.4 - 10.7 08:30 09:45 1.25 5,571 5,407 INTRM1 DRILL CIRC P Circ and cond mud -pumped 35 bbls high vis sweep - circ 2 X BU -700 gpm / 2450 psi / 90 rpm -stood back 2 stands to 5,407' -Flow check well, static 09:45 12:30 2.75 5,407 3,692 INTRM1 DRILL WPRT P Wipe hole from 5,407' to 3,691' - Backream from 5,407' to 4,644' - POOH on trip from 4,644' to 3,692' - hole appears in good condition -flow check well, static 12:30 13:30 1.00 3,692 5,571 INTRM1 DRILL WPRT P RIH to 5,500' - no problems - recautiona wash and ream to 5,571' 13:30 15:30 2.00 5,571 5,571 INTRM1 DRILL CIRC P Circ and condition mud -Pumped 35 bbls high vis sweep -increased mud wt. from 9.8 to 10.0 ppg 700 gpm / 2410 psi / 90 rpm -Pump Wellbore strenghening pill and casing runnin ills - dis lace to bit 15:30 16:45 1.25 5,571 3,661 INTRM1 DRILL TRIP P POOH with pump to 3,661' spotting casin runnin ill. 16:45 20:00 3.25 3,661 716 INTRM1 DRILL TRIP P POOH on TT to 716'. 20:00 22:00 2.00 716 0 INTRM1 DRILL PULD P Laid down BHA. 22:00 23:00 1.00 0 0 INTRM1 DRILL PULD P Pulled wear bushing and cleared rig floor. 23:00 00:00 1.00 0 0 INTRM1 WELCT EQRP P Changed rams to 7 5/8" for casing. 05/14/2006 00:00 00:30 0.50 0 0 INTRM1 CASIN( OTHR P Pull test plug and install thin wall wear bushin 00:30 01:30 1.00 0 0 INTRM1 CASIN( RURD P RU to run 7 5/8" casing 01:30 01:45 0.25 0 0 INTRM1 CASIN( SFTY P Held Prejob safety and Ots meeting with crew 01:45 05:00 3.25 0 2,698 INTRM1 CASIN( RNCS P Make up & Thread lock 7-5/8" Silver bullet float shoe, 2- jts 7-5/8", 27.9#, L-80, BTC csg, 7-5/8" Float collar, Circ & check float equip., RIH to 2,698'. (64 'ts total 05:00 05:30 0.50 2,698 2,698 INTRM1 CASIN( CIRC P Circ csg vol., Stage rate up to 6 bpm @ 310 psi, PUW 148 K, SOW 125 K, Full returns. 05:30 08:15 2.75 2,698 5,561 INTRM1 CASIN( RNCS P Continue running 7-5/8" csg. to 5,517', Make up FMC fluted hanger & Landing jt., Land csg w/ shoe @ 5561', FC @ 5,474'. ~a.~. s®~~ , _ _e.~ _._ ~.e..®® _"~ a~~ce ~:~ ~~ ~ _Time Logs + ~ Date __ From To Dur th E. De th Phase Code Subcod T .. e OM 05/14/2006 08:15 _ 08:45 0.50 5,561 5,561 INTRM1 CEMEI~ _ _ RURD P Lay down Frank's fill up tool - Rig up Dowell cement head and lines 08:45 10:30 1.75 5,561 5,561 INTRMI CASIN( CIRC P Circ & cond. mud for cementing, Stage rate up f/ 2 bpm / 300 psi to 7 bpm FCP @ 340 psi -Reciprocate casing 20', PUW 220K, SOW 148K. PJSM with Dowell and crew 10:30 11:30 1.00 5,561 5,561 INTRM1 CEME~ DISP P Cement 7" casing as follows: Pumped 5 bbl CW-100 -Test lines to 3700 psi - pump 15 bbls CW-100 @ 4.8 BPM @ 200 psi -Mix & pump 30 bbls MudPush XL @ 12.5 ppg - 5.2 BPM @ 230 psi -Drop bottom plug -Mix & pump 62.9 bbl Lead slurry (Class G w/ .2% DO46, .3% DO65, .07% 6155, .4%D167)@ 15.8 ppg-5.76PM@ 150 si 11:30 12:15 0.75 5,561 5,561 INTRMI CEMEt~ DISP P Drop top plug -Pumped 20 bbls water w/ Dowell -Switch to rig pumps & displaced w/ 230 bbls 9.8 ppg mud @ 6.8 BPM @ 140 to 540 psi -slowed rate to 4.0 BPM for last 5 bbls - 370 psi -bumped plug w/ 950 psi -floats held - OK - CIP @ 1203 hrs. Full returns throu hout 'ob 12:15 13:00 0.75 0 0 INTRM1 CASIN( DHEQ P RU and test casing to 3500 psi for 30 minutes 13:00 13:45 0.75 0 0 INTRM1 CEME~ RURD P RD cement head -lay down landing 'oint - ull thin wall wear bushin 13:45 14:30 0.75 0 0 INTRM1 CASIN( DHEQ P Install and test packoff to 5000 psi for 10 minutes 14:30 15:30 1.00 0 0 INTRMI WELC7 OTHR P Change out top pipe rams to 3 1/2" x 6" VBR's 15:30 15:45 0.25 0 0 INTRM1 DRILL PULD P PU and spot Geospan skid on rig floor 15:45 21:00 5.25 0 0 INTRM1 WELCT BOPE P Set test plug. Tested BOPE, Choke manifold, and floor valves to 250/5000 psi. Annulurto 250/3500 psi. Tested closing unit. Witiness waived by Chuck Scheve AOGCC. Pulled test lu . 21:00 00:00 3.00 0 403 INTRM1 DRILL PULD P Set wear bushing and rigged up bales and elevators. Picked up and made up BHA. 05/15/2006 00:00 01:15 1.25 403 403 INTRM1 DRILL PULD P Finish picking up BHA and pulse tested MWD and downlink to Geopilot. Tested Geo S an to 3,000 si. 01:15 05:30 4.25 403 4,909 INTRM1 DRILL PULD P RIH picking up 129 jts DP from pipe shed to 4,909'. 05:30 07:00 1.50 4,909 .5,291 INTRM1 EVAL1l~ DLOG P Made MADD pass from 4,909' to 5,291' with BAT sonic to C ~_r 07:00 07:45 0.75 5,291 5,357 INTRM1 CEMEI~ COCF P , Cleaned out cement from 5,291' to 5,357'. 07:45 08:15 0.50 5,357 5,357 INTRM1 EVALVI, DLOG P Finished MADD pass from 5,291' to 5,357'. Time Logs i Date From To Dur th E. De th Phase Code Subcode T OM 05/15/2006 08:15 09:30 1.25 5,357 5,357 INTRM1 RIGMN SVRG P PJSM. Slipped and cut Drilling Line. 09:30 10:30 1.00 5,357 5,474 INTRM1 CEMEI~ DRLG P Drilled out cement to 5,474'. MADD ass to 5,446'. 10:30 12:45 2.25 5,474 5,571 INTRM1 CEMEf~ DRLG P Drilled Float collar and shoe track to 5,560'. Cleaned out rat hole to 5,571'. 12:45 13:00 0.25 5,571 5,591 INTRM1 DRILL DDRL P Drilled from 5571' to 5591'. ADT .18 Hr. 13:00 13:30 0.50 5,591 5,591 INTRM1 DRILL CIRC P CBU. 13:30 14:30 1.00 5,591 5,591 INTRM1 DRILL FIT P RU and did FIT to 12.5 PPG EMW. 14:30 15:30 1.00 5,591 5,591 PROD1 DRILL CIRC P Changed mud system to 9.9 PPG MOBM. 15:30 00:00 8.50 5,591 6,560 PROD1 DRILL DDRL P Drilled from 5,591' to 6,560' MD 4,079' TVD. ADT 6.2 hrs. WOB 5/10 K RPM 120 GPM 310 PP 3100 psi.. UP Wt. 150 Dn Wt. 108 Rot Wt. 130. Torque On/Off Btm 8,500/7,500 Ft Lbs. ECD 11.25 05/16/2006 00:00 12:00 12.00 6,560 7,492 PROD1 DRILL DDRL P Drilled from 6,560' to 7,492' MD 4,078' TVD. ADT 7.84 hrs. WOB 5/15 K RPM 125 GPM 288 PP 2880 psi.. UP Wt. 148 Dn Wt. 110 Rot Wt. 131. Torque On/Off Btm 8,000/7,000 Ft Lbs. ECD 11.45 Lost 238 Bbls MOBM 12 hrs. 12:00 00:00 12.00 7,492 8,618 PROD1 DRILL DDRL P Drilled from 7,492' to 8,618' MD 4,073' TVD. ADT 8.56 hrs. WOB 5/10 K RPM 120 GPM 280 PP 2920 psi.. UP Wt. 155 Dn Wt. 108 Rot Wt. 128. Torque On/Off Btm 9,000/8,000 Ft Lbs. ECD 11.45 Lost 185 Bbls MOBM 12 hrs. 05/17/2006 00:00 12:00 12.00 8,618 9,604 PROD1 DRILL DDRL P Drilled from 8,618' to 9,604' MD 4,066' TVD. ADT 8.08 hrs. WOB 5/10 K RPM 120 GPM 280 PP 3120 psi.. UP Wt. 153 Dn Wt. 110 Rot Wt. 130. Torque On/Off Btm 9,500/8,000 Ft Lbs. ECD 11.9 Lost 100 Bbls MOBM 12 hrs. 12:00 00:00 12.00 9,604 10,404 PROD1 DRILL DDRL P Drilled from 9,604' to 10,404' MD 4,069' TVD. ADT 9.25 hrs. WOB 5/12 K RPM 120 GPM 280 PP 3200 psi.. UP Wt. 155 Dn Wt. 100 Rot Wt. 125. Torque On/Off Btm 9,000/8,000 Ft Lbs. ECD 12 Lost 202 Bbls MOBM 12 hrs. 05/18/2006 00:00 12:00 12.00 10,404 11,278 PROD1 DRILL DDRL P Drilled from 10,404'to 11,278' MD 4,085' TVD ADT 8.61 hrs. WOB 5/15 K RPM 80/120 GPM 280 3380 psi.. UP Wt. 180 Dn Wt. N/A Rot Wt. 128 Torque On/Off Btm 11,000/10,000 Ft Lbs ECD 12.08 Lost 53 Bbls MOBM last 12 hrs. ~~._as _.~ ~ __®~ ~_~ Ti em Logs ~ ~ Date From To Dur th E. Depth Phase Code Subcode T ~M 05/18/2006 12:00 14:30 2.50 11,278 11,540 PROD1 DRILL DDRL P Drilled from 11,278'to 11,540' MD - 4,067' TVD ADT 2.4 hrs. WOB 5/10 K RPM 120 GPM 280 @ 3400 psi.. UP Wt. 180 Dn Wt. N/A Rot Wt. 128 Torque On/Off Btm 10,500/9,000 Ft Lbs ECD 12.16 Lost 116 Bbls MOBM last 12 hrs. 14:30 17:30 3.00 11,540 11,540 PROD1 DRILL CIRC P CBU X 2 280 GPM 3400 psi. 17:30 00:00 6.50 11,540 8,020 PROD1 DRILL WPRT P POOH from 11,540' to 8,020' with um 4 BPM. 05/19/2006 00:00 04:15 4.25 8,020 5,547 PROD1 DRILL WPRT P POOH with pump from 8,020' to 5,547'. 04:15 07:45 3.50 5,547 11,191 PROD1 DRILL WPRT P RIH to 11,191'. 07:45 09:15 1.50 11,191 11,540 PROD1 DRILL REAM P Wash and ream from 11,191' to 11,540'. 280 GPM. 80 RPM. 09:15 11:45 2.50 11,540 11,540 PROD1 DRILL CIRC P Circulated and conditioned mud. 266 GPM 110 RPM. 11:45 21:00 9.25 11,540 6,308 PROD1 DRILL TRIP P POOH with pump @ 4 BPM from 11,540' to 6,308'. Hole fill short. Flow check well static after 14 min. 21:00 22:30 1.50 6,308 8,687 PROD1 DRILL TRIP NP RIH from 6,308' to 8,687'. 22:30 00:00 1.50 8,687 8,687 PROD1 DRILL CIRC NP CBU. MW cut .4 PPG at bottoms up.. 05/20/2006 00:00 06:30 6.50 8,687 5,547 PROD1 DRILL TRIP P POH w/ pump from 8687' to 5547' at 4 bpm - 1150 psi - 30 rpm. Check low at the shoe. Well is static. 06:30 11:30 5.00 5,547 215 PROD1 DRILL TRIP P POH on trip tank from 5547' to 215'. Check flow at top of BHA at 780. Well is static. 11:30 14:00 2.50 215 0 PROD1 DRILL PULD P POH and LD BHA #4. Download MWD. 14:00 15:30 1.50 0 0 PROD1 RPCOh RURD P Laid down Geo Span and cleared rig floor. Ri ed u to run liner. 15:30 22:00 6.50 0 5,537 COMPZ RPCOh RCST P Ran 3 1/2" Slotted liner (Lower completion to 5,537'. Made up XO and checked Rotation for ue 4600 Ft Lbs. 22:00 22:30 0.50 5,537 5,537 COMPZ EVALV~ DLOG NP Trouble shooting Slumberger CET tool to be run on liner hanger. Tool not workin . No back u tool avaiable. 22:30 00:00 1.50 5,537 5,757 COMPZ RPCOh PULD P RIH to 5,693'. Made up running tool. and RIH to 5,757' and loaded Pal Mix in liner to . 05/21/2006 00:00 05:00 5.00 5,757 11,083 COMPZ RPCOh RCST P MU pupjt and XO. RIH w/ 3 1/2" slotted liner on 4" DP to 11,083'. TOL at 5331'. 05:00 06:00 1.00 5,331 5,252 COMPZ RPCOti PACK P Drop and pump down ball. Pressure drill pipe to 4200 psi to set liner hanger and liner top packer. Release setting tool. PU to 5252'. ~ ~ _ _ _ ~_ ~ ~ _m__®.® m m~ _ ~.~ -~ _.~ a ® ® ~~c~ .v ° t t3 Time Lo~s_ Date From To _ Dur th E. Depth Phase Code Subcode _ _ ,OM j 05/21/2006 06:00 07:00 1.00 5,252 5,252 COMPZ RPCOh CIRC P CBU at 5 bpm. 07:00 11:30 4.50 5,252 60 COMPZ RPCOti TRIP P POOH with liner setting tool from 5,252' to 60'. 11:30 13:00 1.50 60 0 COMPZ RPCOti PULD P Laid down liner running tools and cleared ri floor. 13:00 20:00 7.00 0 0 COMPZ WELCT BOPE P Pulled wear bushing and set test plug. Tested rams, floor valves, IBOP, and choke manifold 250/5000 psi. Tested Hydril to 250/3500 psi. Tested closing unit. Pulled test plug and reset wear bushing. Witiness waived by John Cris AGOCC. 20:00 21:30 1.50 0 0 COMPZ RIGMN SVRG P Slipped and cut drilling line. 21:30 00:00 2.50 0 0 COMPZ EVAL1l~ ELOG NP Rigged up Slumberger and logged with USIT. TOC 4,080'. Good bondin . 05/22/2006 00:00 01:15 1.25 0 0 COMPZ EVALV~ ELOG NP POH w/ USIT tool. RD Schlumberger. 01:15 01:45 0.50 0 0 COMPZ RPCOti OTHR P Pull wear bushing. 01:45 02:30 0.75 0 0 COMPZ RPCOh RURD P Rig up to run tubing. 02:30 05:30 3.00 0 3,143 COMPZ RPCO11 RCST P Ran 3 1/2" uper completion to 3,143'. 05:30 06:30 1.00 3,143 3,143 COMPZ RPCOh PULD P Picked up and made up SSSV with control line. 06:30 09:30 3.00 3,143 5,366 COMPZ RPCOh RCST P Ran 3 1/2" uper completion from 3,143' to 5,366'. 09:30 13:30 4.00 5,366 5,366 COMPZ RPCOti HOSO P Spaced out. Made up tubing hanger and connected control line. Landed tubin . 13:30 15:00 1.50 5,366 0 COMPZ RPCOh DHEQ P Changed out landing joints and tested tubing hanger to 5000 psi. Spooled up control line on han er. 15:00 16:30 1.50 0 0 COMPZ RPCOh RURD P Rigged down running tools and flushed MOBM out of BOP. Blew down lines. Set two wa check. 16:30 18:30 2.00 0 0 COMPZ RPCOh NUND P Nippled down BOP. 18:30 22:00 3.50 0 0 COMPZ RPCOh NUND P Nippled up tree and control line. Tested tree to 5000 si. Pulled TWC. 22:00 00:00 2.00 0 0 COMPZ RPCOh DHEO P Dropped ball/bar. RU displacement manifold. Tested Dowell lines to 3500 psi. Tested tubing to 3500 psi for 30 min. 05/23/2006 00:00 01:00 1.00 0 COMPZ RPCOh DHEQ P Finish testing tbg & annulus to 3500 psi for 30 mins. -bleed off pressure - pressure up on annnulus to 3000 psi to shear DK2 valve in GLM 01:00 02:45 1.75 COMPZ RPCOh FRZP P Pump 30 bbls mineral oil followed by 198 bbls diesel for freeze rotect - 02:45 03:30 0.75 COMPZ RPCOh NUND P Flush hard lines with water & air - Rd hardlines & s ueeze manifold 03:30 04:45 1.25 COMPZ RPCOh OTHR P RU FMC lubricator & set BPV -dress out tree -secure tree _. Ww ~ .~._m.,, Time Lo s Date From To Dur ..~~th E_De th Phase Code Subcode T OM 05/23/2006 04:45 12:00 7.25 COMPZ RPCOh OTHR P PJSM - LD 4" DP f/derrick via mouse hole 210 'ts. 12:00 16:30 4.50 COMPZ RPCOh OTHR P Cont. LD 4" DP f/derrick & cleaning mud its 16:30 23:30 7.00 COMPZ RPCOh OTHR P Change over to 5" handling equipment & LD 5" HWDP & 5" DP f/ derrick - LD mouse hole & continue cleaning mud its 23:30 00:00 0.50 COMPZ RPCOCV OTHR P Clean rig of OBM 05/24/2006 00:00 07:00 7.00 COMPZ RPCOA OTHR P Finmish cleaning pits & Clean up on ri flor f/ OBM m ~ _ -~. . . ~ . ®. ~ ~~~R . _~s~ P . Halliburton Company Survey Report ('~imp:ui~: ConocoPhillips Alaska Inc. D;itc: 6i6/200~ I'inu: 10.17.2, I'a,e: I Ficl~: Colville River Unit Cu-urdin>itcl~E) Rc fi•rcncc: Well. CD2-404. Tr ue North - ~ilc: Alpine CD2 ~'crticall"f~l)) Kcle rcncc: CD 2-404 527 ~1cll: CD2-404 ~cctiun (`.~~til llcfere ncc: Well i0 00N.0-OOE,322.02Azi) ~1'ell~~:uh: CD2-404 Sung f_ailcululiun ~Ictlunl: Min imum Curvatu re Db: Oracle Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: CD2-404 Slot Name: CD2-04 Slot Well Position: +N/-S 109.62 ft Northing: 5974751 .48 ft Latitude: 70 20 21.303 N +E/-W -13.39 ft Easting : 371684 .73 ft Longitude: 151 2 28.474 W Position Uncertainty: 0.00 ft Wellpath: CD2-404 Drilled From: Well Ref. Point 501032053000 Tie-on Depth: 36.80 ft Current Da tum: CD2-404: Height 52 .70 ft Above System D atum: Mean Sea Level Magnetic Data: 5/5/2006 Declination: 23.33 deg Field Strength: 57502 nT Mag Dip Angle: 80.65 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.80 0.00 0.00 328.02 Survey Program for Definitive Wellpath Date: 10/22/2003 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 80.00 620.00 CD2-404 g yro (80.00-62 0.00) CB-GYRO-SS Camera ba sed gyro single shot 716.14 11502.67 CD2-404 (716.14-11502 .67) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~1D lucl hum 1 ~~I) S}~ ll~U \i~`; 1~7~~ ~la~~A \la~il: l~uul ft deg deg ft ft ft ft ft ft 36.80 0.00 0.00 36.80 -15.90 0.00 0.00 5974751.48 371684.73 .TIE LINE 80.00 0.30 278.00 80.00 27.30 0.02 -0.11 5974751.50 371684.62 CB-GYRO-SS 170.00 1.70 293.00 169.98 117.28 0.57 -1.57 5974752.08 371683.17 CB-GYRO-SS 260.00 3.00 305.00 259.91 207.21 2.44 -4.73 5974754.00 371680.04 CB-GYRO-SS 350.00 4.10 305.00 349.73 297.03 5.64 --9.30 5974757.28 371675.53 CB-GYRO-SS 440.00 7.20 299.00 439.29 386.59 10.22 -16.87 5974761.99 371668.04 CB-GYRO-SS 531.00 10.00 296.00 529.25 476.55 16.45 -28.96 5974768.42 371656.06 CB-GYRO-SS 620.00 12.50 297.00 616.54 563.84 24.21 -44.49 5974776.45 371640.67 CB-GYRO-SS 620.50 12.50 297.00 617.02 564.32 24.26 -44.59 5974776.50 371640.57 CB-GYRO-SS 716.14 13.63 297.06 710.19 657.49 34.09 -63.84 5974786.65 371621.48 MWD+IFR-AK-CAZ-SC 775.03 13.84 297.62 767.39 714.69 40.51 -76.26 5974793.28 371609.18 MWD+IFR-AK-CAZ-SC 833.60 16.50 293.79 823.92 771.22 47.11 -90.08 5974800.12 371595.47 MWD+IFR-AK-CAZ-SC 929.65 17.60 297.49 915.75 863.05 59.32 -115.45 5974812.76 371570.32 MWD+IFR-AK-CAZ-SC 1024.61 21.05 291.40 1005.35 952.65 72.17 -144.07 5974826.10 371541.92 MWD+IFR-AK-CAZ-SC 1120.13 26.43 288.79 1092.76 1040.06 85.29 -180.20 5974839.83 371506.03 MWD+IFR-AK-CAZ-SC 1214.95 32.19 290.13 1175,41 1122.71 100.79 -223.93 5974856.08 371462.58 MWD+IFR-AK-CAZ-SC 1309.91 35.99 288.44 1254.04 1201.34 118.33 -274.16 5974874.47 371412.65 MWD+IFR-AK-CAZ-SC 1404.92 36.07 287.64 1330.87 1278.17 135.63 -327.30 5974892.68 371359.82 MWD+IFR-AK-CAZ-SC 1499.77 36.49 287.73 1407.34 1354.64 152.68 -380.77 5974910.65 371306.66 MWD+IFR-AK-CAZ-SC 1594.51 36.25 286.64 1483.62 1430.92 169.28 -434.44 .5974928.16 371253.28 .MWD+IFR-AK-CAZ-SC 1690.10 36.84 287.13 1560.42 1507.72 185.82 -488.91 5974945.62 371199.11 MWD+IFR-AK-CAZ-SC 1785.49 34.31 289.40 1638.00 1585.30 203.18 -541.61 5974963.88 371146.72 MWD+IFR-AK-CAZ-SC 1881.15 35.13 289.36 1716.63 1663.93 221.25 -593.00 5974982.83 371095.65 MWD+IFR-AK-CAZ-SC 1974.23 33.55 287.25 1793.48 1740.78 237.76 -642.84 5975000.19 371046.11 MWD+IFR-AK-CAZ-SC 2071.06 34.16 287.94 1873.90 1821.20 254.07 -694.26 5975017.37 370994.98 MWD+IFR-AK-CAZ-SC 2165.98 34.55 288.58 1952.26 1899.56 270.85 -745.12 5975035.02 370944.41 MWD+IFR-AK-CAZ-SC 2261.13 34.05 288.08 2030.86 1978.16 287.72 -796.02 5975052.75 370893.81 MWD+IFR-AK-CAZ-SC 2356.43 34.89 290.07 2109.43 2056.73 305.35 -846.99 5975071.28 370843.16 MWD+IFR-AK-CAZ-SC 2451.80 35.56 290.37 2187.34 2134.64 324.37 -898.60 5975091.15 370791.88 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (~nmpan~: ConocoPhillips Alaska Inc FicIJ: Colville River Unit tiitc: Alpine CD2 ~~'cll: CD2-404 ~1 cllltath: CD2-404 tiuncv X11) Ifll'I ~/1111 ft deg deg 2547.11 35.50 291.39 2642.34 36.33 289.41 2765.79 35.97 289.63 2861.14 35.59 289.10 2956.35 35.40 287.70 3050.34 35.10 287.89 3146.67 34.99 287.71 3241.60 35.11 287.55 3337.21 35.21 287.56 3431.87 35.13 287.30 3528.34 35.32 286.37 3623.75 36.07 289.78 3717.52 36.68 293.24 3812..60 38.08 300.05 3908.06 39.82 305.74 4003.42 41.86 309.28 4098.71 44.22 312.34 4194.23 46.28 315.89 4289.27 50.00 319.82 4384.56 53.16 326.08 4479.25 55.81 328.86 llatc: 6/6/2006 I iwc: 10:17.27 Pa~c: '_ Cu-~nllinatcltla Kclircucc: Well: CD2-404. True North ~'c•rtical f~IFI1) 12c1i•rc•ncc: CD2-404: 52.7 ticrtinn 1~'~til Rcfcrcurc: Well i0 00N•0-OOE32o.02Azi) Sur~cc (alculatiun ~icthu~l: Minimum Curvature Ith: Oracle 1 ~ I) ti~ti I ~ I) ~;',ti I -tip ~1;11~\ ft ft ft ft ft 2264.90 2212.20 344.11 -950 .35 5975111 .77 2342.03 2289.33 363.57 -1002 .71 5975132 .12 2441.71 2389.01 387.90 -1071. 34 5975157 .62 2519.07 2466.37 406.38 -1123. 94. 5975177 .00 2596.59 2543.89 423.83 -1176. 39 5975195 .35 2673.34 2620.64 440.41 -1228. 04 5975212 .81 2752.21 2699.51 457.32 -1280. 71 5975230 .61 2829.92 2777.22 473.83 -1332. 66 5975248. 01 2908.09 2855.39 490.44 -1385. 16 5975265. 51 2985.47 2932.77 506.77 -1437. 18 5975282. 73 3064.27 3011.57 522.89 -1490. 44 5975299. 75 3141.77 3089.07 540.17 -1543. 34 5975317. 93 3217.27 3164.57 560.56 -1595. 05 5975339. 21 3292.86 3240.16 586.46 -1646. 55 5975365. 98 3367.12 3314.42 619.07 -1696. 86 5975399. 44 3439.27 3386.57 657.06 -1746. 28 5975438. 27 3508.91 3456.21 699.58 -1795. 47 5975481. 62 3576.17 3523.47 746.81 -1844. 13 5975529. 67 3639.59 3586.89 799.31 -1891. 54 5975582. 98 3698.84 3646.14 858.89 -1936. 41 5975643. 31 3753.85 3701.15 923.87 -1977. 82 5975708. 98 4573 .51 59.58 331.96 3804.22 3751 .52 993.15 -2017.11 5975778 .92 4669 .51 62.90 334.89 3850.41 3797 .71 1068.40 -2054 .71 5975854 .80 4764 .57 65.52 338.59 3891.78 3839 .08 1147.03 -2088 .48 5975933 .98 4859 .76 67.57 339.66 3929.67 3876 .97 1228.62 -2119 .58 5976016 .09 4955 .34 69.93 341.35 3964.31 3911 .61 1312.58 -2149. 30 5976100 .54 5050 .78 72.51 343.66 3995.03 3942 .33 1398.75 -2176. 45 5976187 .16 5146 .25 76.13 346.30 4020.84 3968 .14 1487.51 -2200. 24 5976276 .30 5241 .50 79.71 348.02 4040.77 3988 .07 1578.31 -2220. 93 5976367 .43 5336 .63 83.70 350.69 4054.49 4001 .79 1670.80 -2238. 30 5976460 .20 5431 .70 86.11 352.68 4062.94 4010 .24 1764.48 -2251. 99 5976554 .10 5489 04 86 40 ~~ 354 7 4066 68 4013 98 1821 33 2258 9 5976611 04 n.5 't . 5526. 66- . 86.36 . 355.21 . 4069.06 4016 . .36 . 1858.71 - . -2261. 4 93 . 5976648. 48 1 ~ SS 5605. - 26 86.57 -355.02 4073.90 4021. 20 1936.88 -2268. 61 5976726. 74 i 5700. 88 88.11 355.08 4078.34 4025. 64 2032.04 -2276. 85 5976822. 02 _ C, 5'x(0 5796. 54 87.30 354.03 4082.17 4029. 47 2127.19 -2285. 92 5976917. 30 5891. 00 88.36 354.05 4085.75 4033. 05 2221.07 -2295. 73 5977011. 33 5986. 01 88.48 353.61 4088.37 4035. 67 2315,49 -2305. 93 5977105. 90 6081. 30 89.71 352.45 4089.87 4037. 17 2410.06 -2317. 49 5977200. 65 6175. 98 92.37 353.55 4088.15 4035. 45 2504.01 -2329. 03 5977294. 78 I 6271. 12 91.19 355.46 4085.20 4032. 50 2598.66 -2338. 14 5977389. 56 6366. 46 90.52 356.02 4083.78 4031. 08 2693.73 -2345. 22 5977484. 72 6461. 44 91.13 355.73 4082.41 4029. 71 2788.45 -2352. 05 5977579. 54 6556. 60 89.96 357.78 4081.50 4028. 80 2883.45 -2357.43 5977674. 61 6649. 89 90.27 356.15 4081.32 4028. 62 2976.60 -2362. 37 5977767. 83 I 6746. 79 91.01 356.43 4080.23 4027. 53 3073.29 -2368. 64 5977864. 61 6841.82 89 .65 354 .93 4079.69 4026.99 3168.05 -2375. 80 5977959.46 6936.67 89 .71 353 .49 4080.22 4027.52 3262.41 -2385. 37 5978053.96 7031.26 88. 54 353. 01 4081.66 4028.96 3356.33 -2396. 49 5978148.05 7126.74 89. 59 353. 37 4083.22 4030.52 3451.12 -2407. 81 5978243.02 7222.16 90. 82 355. 57 4082.88 4030.18 3546.09 -2417. 00 5978338.12 7317.29 91. 50 356. 68 4080.95 4028.25 3640.98 -2423. 43 5978433.10 ~lahl~: hull ft 370740.48 MWD+IFR-AK-CAZ-SC 370688.47 MWD+IFR-AK-CAZ-SC 370620.27 MWD+IFR-AK-CAZ-SC 370568.00 MWD+IFR-AK-CAZ-SC 370515.86 MWD+IFR-AK-CAZ-SC 370464.50 MWD+IFR-AK-CAZ-SC 370412.14 MWD+IFR-AK-CAZ-SC 370360.48 MWD+IFR-AK-CAZ-SC 370308.28 MWD+IFR-AK-CAZ-SC 370256.55 MWD+IFR-AK-CAZ-SC 370203.58 MWD+IFR-AK-CAZ-SC 370150.99 MWD+IFR-AK-CAZ-SC 370099.63 MWD+IFR-AK-CAZ-SC 370048.59 MWD+IFR-AK-CAZ-SC 369998.85 MWD+IFR=AK-CAZ-SC 369950.09 MWD+IFR-AK-CAZ-SC 369901.64 MWD+IFR-AK-CAZ-SC 369853.80 MWD+IFR-AK-CAZ-SC 369807.29 MWD+IFR-AK-CAZ-SC 369763.46. MWD+IFR-AK-CAZ-SC 369723.17 MWD+IFR-AK-CAZ-SC 369685.08. MWD+IFR-AK-CAZ-SC 369648.77 MWD+IFR-AK-CAZ-SC 369616.36 MWD+IFR-AK-CAZ-SC 369586.65 MWD+IFR-AK-CAZ-SC 369558.38. MWD+IFR-AK-CAZ-SC 369532.72 MWD+IFR-AK-CAZ-SC 369510.44 MWD+IFR-AK-CAZ-SC 369491.32 MWD+IFR-AK-CAZ-SC 369475.53 MWD+IFR-AK-CAZ-SC 369463.45 MWD+IFR-AK-CAZ-SC 369457.92 MWD+IFR-AK-CAZ-SC 369455.12 MWD+IFR-AK-CAZ-SC 369449.78 MWD+IFR-,SK-CAZ-SC 369443.17 MWD+IFR-AK-CAZ-SC .369435.73 MWD+IFR-AK-CAZ-SC 369427.53 MWD+IFR-AK-CAZ-SC 369418.94 MWD+IFR-AK-CAZ-SC 369409.00 MWD+IFR-AK-CAZ-SC 369399.08 MWD+IFR-AK-CAZ-SC 369391.60 MWD+IFR-AK-CAZ-SC 369386.14 MWD+IFR-AK-CAZ-SC 369380.93 MWD+IFR-AK-CAZ-SC 369377.17 MWD+IFR-AK-CAZ-SC 369373.83 MWD+IFR-AK-CAZ-SC 369369.22 MWD+IFR-AK-CAZ-SC 369363.68 MWD+IFR-AK-CAZ-SC .369355.73 MWD+IFR-AK-CAZ-SC 369346.22 MWD+IFR-AK-CAZ-SC 369336.53 MWD+IFR-AK-CAZ-SC 369328.96 MWD+IFR-AK-CAZ-SC 369324.16 MWD+IFR-AK-CAZ-SC Halliburton Compan~ Survey Report (~nrupanF: ConocoPl,illips Alaska Inc. I)arc: 6/6i20G6 Iinic: 10:17.2;' I'a,c 3 Ficl~: Colv ille P,iver Unit Cu-~n '~Iinatcl~l:) K efcrcucc Well: CD2-404, Tr ue North Sire: Alpin e CD2 Verti cal ("Il`I)) 12cf ercuce: CD2-404'. 52.7 \~cll: CD2 -404 Secti on ~~Sl ILcferc nce: Well (O.OCN O OOE ,~28-02Azi) ~1'ellpatl~: CD2 -404 Sun g (~alculatinn >ielho~l: Mi nimum Curvatu re l)b: Oracle Snncc SID Intl ~zini 1~`U S.~~IIU \%S l~_:~1 AIa~iA Slat~l; I~niii ft deg deg ft ft ft ft ft ft 7412.61 90.64 354.82 4079.17 4026.47 3736.02 -2430.49 5978528.24 369318.72 MWD+IFR-AK-CAZ-SC. 7505.53 90.76 352.96 4078.04 4025.34 3828.40 -2440.38 5978620.77 369310.42. MWD+IFR-AK-CAZ-SC 7602.58 90.08 352.43 4077.32 4024.62. 3924.66 -2452.72 5978717.21 369299.73 MWD+IFR-AK-CAZ-SC 7697.80 89.10 352.34 4078.01 4025.31 4019.03 -2465.34 5978811.79 369288.73. MWD+IFR-AK-CAZ-SC 7791.40 89.41 :353.37 4079.22 4026.52 4111.90 -2476.98 5978904.83 369278.68 MWD+IFR-AK-CAZ-SC 7887.76 90.89 352.99 4078.97 4026.27 4207.57 -2488.42 5979000.68 369268.88 MWD+IFR-AK-CAZ-SC 7983.08 90.02 352.09 4078.21 4025.51 4302.08 -2500.79 5979095.37 369258.12 MWD+IFR-AK-CAZ-SC 8075.70 90.83 352.37 4077.53 4024.83 4393.85 -2513.32 5979187.33 369247.17 MWD+IFR-AK-CAZ-SC 8170.84 90.46 355.07 4076.45 4023.75 4488.40 -2523.72 5979282.05 369238.39 MWD+IFR-AK-CAZ-SC 8268.85 90.33 356.81 4075.78 4023.08 4586.16 -2530.66 5979379.90 369233.12 MWD+IFR-AK-CAZ-SC 8363.87 89.78 355.70 4075.69 4022.99 4680.97 -2536.87 5979474.80 369228.54 MWD+IFR-AK-CAZ-SC 8459.10 90.08 355.78 4075.80 4023.10 4775.94 -2543.94 5979569.87 369223.09 MWD+IFR-AK-CAZ-SC 8550.99- 90.82 356.96 4075.08 4022.38 4867.64 -2549.76 5979661.64. 369218.85 MWD+IFR-AK-CAZ-SC 8649.93 90.70 357.27 4073.77 4021.07 4966.45 -2554.74 5979760.51 369215.56 MWD+IFR-AK-CAZ-SC 8744.20 89.84 355.70 4073.33 4020.63 5060.54 -2560.52 5979854.68 369211.39 MWD+IFR-AK-CAZ-SC 8839.05 90.46 353.39 4073.08 4020.38 5154.95 -2569.53 5979949.22 369203.99 MWD+IFR-AK-CAZ-SC 8935.87 91.44 353.08 4071.47 4018.77 5251.08 -2580.94 5980045.53 369194.24 MWD+IFR-AK-CAZ-SC 9030.20 90.14 354.89 4070.17 4017.47 5344.88 -2590.82 5980139.47 369185.96 .MWD+IFR-AK-CAZ-SC 9125.62 91.32 356.24 4068.96 4016.26 5440.00 -2598.20 5980234.70 369180.21 MWD+IFR-AK-CAZ-SC 9220.94 90.39 357.37 4067.53 4014.83 5535.16 -2603.51 5980329.93 369176.53 MWD+IFR-AK-CAZ-SC 9316.19 90.21 358.02 4067.03 4014.33 5630.33 -2607.34 5980425.14 369174.33 MWD+IFR-AK-CAZ-SC 9411.61 89.84 354.49 4066.99 4014.29 5725.53 -2613.57 5980520.43 369169.73 MWD+IFR-AK-CAZ-SC 9507.09 90.15 352.81 4067.00 4014.30 5820.42 -2624.13 5980615.48 369160.80 MWD+IFR-AK-CAZ-SC 9602.58 91.07 352.76 4065.98 4013.28 5915.15 -2636.12 5980710.39 369150.43 MWD+IFR-AK-CAZ-SC 9697.71 91.19 352.81 4064.11 4011.41 6009.51 -2648.07 5980804.93 369140.10 MWD+IFR-AK-CAZ-SC 9792.85 88.97 351.63 4063.98 4011.28 6103.76 -2660.95 5980899.39 369128.84 MWD+IFR-AK-CAZ-SC 9888.23 90.76. 350.62 4064.20 4011.50 6198.00 -2675.66 5980993.85 369115.74 MWD+IFR-AK-CAZ-SC 9983.25 90.58 356.04 4063.09 4010.39 6292.33 -2686.69 5981088.35 .369106.32 MWD+IFR-AK-CAZ-SC .10078.25 87.55 358.34 4064.64 4011.94 6387.19 -2691.35 5981183.27 369103.29 MWD+IFR-AK-CAZ-SC 10173.59 88.60 356.83 4067.84 4015.14 6482.38 -2695.36 5981278.51 369100.91 MWD+IFR-AK-CAZ-SC 10268.92 89.59 356.69 4069.35 4016.65 6577.55 -2700.75 5981373.75 369097.15 MWD+IFR-AK-CAZ-SC 10362.23 89.84 353.71 4069.81 4017.11 6670.52 -2708.56 5981466.83 369090.93 MWD+IFR-AK-CAZ-SC 10457.99 92.62 349.92 4067.76 4015.06 6765.26 -2722.18 5981561.78 369078.93 MWD+IFR-AK-CAZ-SC 10553.34 91.32 350.74 4064.48 4011.78 6859.19 -2738.19 5981655.97 369064.54 MWD+IFR-AK-CAZ-SC 10648.52 90.51 353.45 4062.96 4010.26 6953.45 -2751.28 5981750.42 369053.07 MWD+IFR-AK-CAZ-SC 10743.40 88.48 355.50 4063.79 4011.09 7047.87 -2760.41 5981844.98 369045.55 MWD+IFR-AK-CAZ-SC 10838.74 87.74 354.72 4066.94 4014.24 7142.81 -2768.53 5981940.04 369039.06. MWD+IFR-AK-CAZ-SC 10933.82 87.92 355.76 4070.54 4017.84 7237.49 -2776.42 5982034.84. 369032.79 MWD+IFR-AK-CAZ-SC 11028.18 87.55 356.66 4074.27 4021.57 7331.57 -2782.65 5982129.00 369028.17 MWD+IFR-AK-CAZ-SC 11123.18 86.81 357.22 4078.94 4026.24 7426.32 -2787.71 5982223.81 369024.73 MWD+IFR-AK-CAZ-SC 11218.63 88.11 358.00 4083.17 4030.47 7521.59 -2791.69 5982319.13 369022.38 MWD+IFR-AK-CAZ-SC 11313.79 92.80. 358.21 4082.42 4029.72 7616.67 -2794.84 5982414.24 369020.87 MWD+IFR-AK-CAZ-SC 11407.92 93.67 358.64 4077.10 4024.40 7710.61 -2797.42 5982508.21 369019.89 MWD+IFR-AK-CAZ-SC 11502.67 95.21 358.64 4069.77 4017.07 7805.05 -2799.66 5982602.66 369019.27 MWD+IFR-AK-CAZ-SC 11540.00 95.21 358.64 4066.38 - 4013.68 7842.22 -2800.54 5982639.83 ' 369019.02 ~ PROJECTED to TD • WELL LOG TRANSMITTAL • To: State of Alaska June 27, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD2-404, AK-MW-4348860 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 Disc with verification listing. API#: 50-103-2053 0-00. ~v~ -osy # ~ 39~a • 15-Jun-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-404 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.80' MD Window /Kickoff Survey: 11,502.67' MD (if applicable) Projected Survey: 11,540.00' MD 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 „ I n . ~ Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) RECE~vED JUN 2 '7 206 ~ ~~ Cons ~mmisslon Anchorite Oil & Gas Journal -Qannik satellite tested on N~ Slope SUBSCRIBE magazines ~ e-newsletters ~°: i35~o~~,,,~ ~ j.___---_---. _ r°«I,' ~ advanct~t~ map ~ about _ ~_ F `; "' L C~EMtAIL THtS ~uf'RtNTH__{= l; .i f~iwT_~JPULA F', ~ fy ,(~ ~ ~ ___ - ~-_""-j ~ ` `» ,i ~~ ,~,~ 200;.. Home Media Kit OGJ Supplements Login Subscribe Premium Web Features Current Issue Past Issues OGJ200 Index OGJ Online Research Center LNG Observer LNG Observer Past Issues Industry Links '~ Now reaching more i than 60,000* professionals in the ', LNG industry. Click Here for the Current Issue Oil & Gas Journal's LNG Observer is the only information resource of its kind -providing consistent, authoritative, i and comprehensive reporting on the issues affecting today's rapidly Qannik satellite tested on North Slope By OGJ editors ~~ ~ ., HOUSTON, July 14 -- ConocoPhillips and Anadarko Petroleum Corp. reported the discovery of and test production from the Qannik oil accumulation overlying Alpine oil field on the Alaskan North Slope. The Qannik deposit was tested for 19 days in June by the CD2-404 well, which flowed an average 1,200 b/d of 30° gravity oil from a 25-ft thick sandstone at 4,000 ft subsea. The Qannik accumulation would be the third satellite field to be developed near Alpine. The previously announced Fiord and Nanuq satellites are currently being drilled with first production scheduled for later this year (OGJ Online,. Jan. 3, 2005). Current plans are to develop Qannik from the Alpine CD2 drillsite. First production could occur by late 2008. Operator ConocoPhillips holds 78% interest in Alpine and its satellites; Anadarko holds 22%. '.. t; (~ `-'-'JJL THIS f~U f':-1~:1 ~HV.? l ~~ .:.CPU LAR ~: I~~~ /\ A WEBCASTS rT ~~. r ~~~f~"~: -~ flt~1VFT ~ ~laren4 t'34f~YVCi1w The North American Gas Shortage...is LNG the answer? Managing Complex Engineering Content: How BC Hydro Improved Efficiency & Control More WHITE PAPERS W~ ~~ ,.°~r,1,1~~" INFO from OG&PE magazine „II I 1 of 3 7/17/2006 8:59 AM Re: Request to inject Drilling Rinse water at CD4 Subject: Re: Request toinject Grilling Rinse wafer atCD4 )E~rom: "hhomas Maunder ~~=;toi~~ :~naunder@admin.state.ak.us> Date: Thu, ?5 May?OC)6 1 l:?>:14 -O8U(1 To: r~LP Cnsi Env Coord <"ALPCnstl=nvCoord(aconocophilGps.com=~ CC:.lim Re:;~ . jimrc`~`c~iadmin.state.ak.us=> Chuck, ~Q ~~- ~ '~-~ 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 normally 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 5/26/2006 7:08 AM ~~~IVLD s~~ r~ MAY 2 4 2006 Schlumberger-DCS ~ ~~~ 2525 Gambell Street, Suii~~0'" ~ CAS C(NIS. ~0t71(CNSS)0(I Anchorage, AK 99503-2838 AIIt Attn: Beth Well Job # Log Description N0.3816 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Date BL Prints CD CD2-404 11235363 USIT a - C 05/21/06 1 ~'E J SIGNED: (~ ~ i1 _ DATE: T~~~C~ (d 05/23/06 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: iim re~~k~adrr:i:~.state.a?i.us ao~. prud,oe b:~ad:~n=n.s~tate.ak.us bole eckenster~:n~~admi:~.stUte.a>c.~~s~ Contractor: Doyon Rig No.: 19 DATE: 5/21/2006 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.: Lutrick/Hill Field/Unit & Well No.: Colville Rv CD2-404 PTD # 206-t?54 Operation: Drlg: x Workover: Explor.: Test: Initial: Weekly: x Bi-Weekly 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 3-1/8 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 Number of Failures: 0 Test Time: 5_0 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: jim reg~'~adrr:in.state.a>i.us~ Remarks: Changed out relief valve on the accumulator (bad) prior to BOP test. Good test. CHOKE MANIFOLD: Quantity Test R 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 1675 P 200 psi Attained 44 P Full Pressure Attained 2 min 30 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2100 psi Test Results FLOOR SAFETY VALVES: Quantity Test Res Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P 24 HOUR NOTICE GIVEN YES X NO Date 05/20/06 Time 7:OOam Waived By John Test start Finish 7:00 Witness Krupa/Lutrick BOP Test (for rigs) BFL 11/09/04 Doyon19 5-21-06 CD2-404-1.xls `~ STATE OF ALASKA ~ 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ~i€~ reg~;;~3adn:i:~.stute.ak.u~~ ~cn I/`€_Ed~oe bz:~~.admn.state.Uk.~s br;i ~ feckenstein ~yad€~:i:~.state.ak.u~~ Contractor: Doyon Rig No.: 19 DATE: 5/14/2006 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 CD2-404 PTD # 206-054 Operation: Drlg: x Workover: Explor.: Test: Initial: Weekly: x Bi-Weekly Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: ', Test Result Test Result Quantity Test R Location Gen.: P Well Sign P Upper Kelly 1 P ', Housekeeping: P Drl. Rig P Lower Kelly 1 P ', PTD On Location P Hazard Sec. P Ball Type 1 P ', Standing Order Posted P Inside BOP 1 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 3-1/8 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 Results 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 2950 P Pressure After Closure 1650 P 200 psi Attained 29 P Full Pressure Attained 2 min 40 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2150 psi Number of Failures: 0 Test Time: 4.25 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~~~'~~adrr:i~.s_f~_f~.a>~.us~ Remarks: Excellent test 24 HOUR NOTICE GIVEN YES X NO Date 05/13/06 Test start Time 7:OOam Finish Waived By Witness Kru Chuck Scheve ill/Lu BOP Test (for rigs) BFL 11/09/04 Doyon19 5-14-06 CD2-404.x1s ~ STATE OF ALASKA ~ 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to:~ re~~;~~3adr~:i:~.state.a>t.uc uC~~h prud`~oe ~;v~ad:~l~n.stae.alE.us b+~lv f€eckensten:~acr~:in.state.a~.u~~ Contractor: Doyon Rig No.: 19 DATE: 5/11/2006 Rig Rep.: Welsh/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 CD2-404 PTD # 206-054 Operation: Drlg: x Workover: Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test R Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 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 3-1/8 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 CHOKE MANIFOLD: Quantity Test R No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3000 P Pressure After Closure 1650 P 200 psi Attained 28 P Full Pressure Attained 2 min 38 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2150 psi Test Results Number of Failures: 0 Test Time: 14.5 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 Supervises at: jim re~g :~~admi:~.state.ak.us Remarks: Had to change out API ring between mud cross and blind rams-retest good-c/o test hose- 24 HOUR NOTICE GIVEN YES X NO Date 05/08/06 Time 9:30pm est start Finish Waived By Jeff Jones Witness Lupton/Hill/Burl BOP Test (for rigs} BFL 11/09/04 Doyon19 5-11-06 CD2-404.x1s ~~~ O a ~ ~ ~H. MU OWSKI, GOVERNOR DEPARTMENT OF NATURAL RESOURCES 550 WEST 7TH AVENUE, su~rE soo ANCHORAGE, ALASKA 99509-3560 DlVISlON OF OlL AND GAS PHONE: (907) 269-8800 FAX: (907) 269-8938 Apri126, 2006 Dora I. Soria Senior Landman ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 ~- - Via Fax (263-4966) and Mail Subject: Request to Drill and Test CD2-404: and Request to Commingle CD2-404 Test Production. with Alpine Participating Area Production Dear Ms. Soria: By letters, dated April 17, 2006 and April 24, 2006, ConocoPhillips Alaska, Inc. (ConocoPhillips) applied for tract operations approval to drill and test produce CD2-404. CorocoPhillips also applied to commingle the produced fluids generated from the well with production from the Alpine Participating Area (APA) in the Colville River Unit (CRU) through the Alpine Central Facility. CD2- 404 will be tract operation to test the K-2 Reservoir. The K-2 Reservoir is within the CRU, but not included within any existing participating area. CD2-404 will be a deviated horizontal wellbore with a beginning horizontal bottomhole location in Section 35, T12N-R4E, UM, and an ending horizontal bottomhole location in Section 26, T12N-R4E, UM. The plan is to drill and test produce CD2-404 to evaluate the K-2 Reservoir. The planned test production sequence would be for a period of up to 21 days with the well completed as an injection well afterwards. The proposed Tract Operation, as outlined in ConocoPhillips' two letters, would determine if the well is capable of producing or contributing to production of hydrocarbons in paying quantities to justify developing and producing the K-2 Reservoir as a new participating area within the CRU. I approve your plan to drill, test produce, and commingle the CD2-404 test production from the K-2 Reservoir through the CRU-APA facilities. This approval is for a period of 6 months, that is, until October 31, 2006. ConocoPhillips shall notify the Division, in writing, of the spud date of the well and start date of test production from the well. At the June 2006, Section 3.9.8 Review Meeting, ConocoPhillips shall provide a status report of the activities conducted under the CD2-404 Tract Operation. The status report should list the spud date of the well, the start and stop dates of each testing period, the volume and final disposition of any produced fluids and state whether the well meets the "Qualified Injection or Producing Well" criteria of the CRU Agreement. "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans. " • • Ms. Dora I. Soria CD2-404 Tract Operation Apri126, 2006 Page 2 All produced fluids from CD2-404 shall be allocated on the basis of the total length of the productive portion of the well actually drilled under and attributable to Section 26 and 35, respectively. Once the actual length of the productive interval of the well is established, ConocoPhillips shall inform Arctic Slope Regional Corporation and the Division of Oil and Gas concerning the proportionate share of the wellbore that is associated with each of the two sections. Then for the portion of the wellbore within Section 26, 50% of the production shall be allocated to CRU Tract 26 and 50% shall be allocated to CRU Tract 27; and for the portion of the wellbore within Section 35, 80% of the production shall be allocated to CRU Tract 36 and 20% shall be allocated to CRU Tract 37. Accounting Code "CR09" is assigned to the K-2 Reservoir fluids allocated to CD2-404 Tract Operation. ConocoPhillips, as the CRU Operator, shall separately account for the production allocated to the CD2-404 Tract Operation on the monthly CRU production report. Finally, this approval is only for the general CD2-404 Tract Operation plan.. Specific on-site operations may require additional approvals: Sincerely, %~ / ~,.. William Van Dyke Acting Director cc: AOGCC Teresa Imm - ASRC CRU_Kanik CD2-404_Tract Operation.doc Re: CD2-404 permit to drill # 206-054 diverter waiver Subject: Re: CD2-404 pez-mit to drill # 206-054 diverter waiver From: Thomas Maunder~~tommaunder cr adrrtin.state.ak.us> Date: Fri, 21 Apr 2006 08:(~?:(i? -0800 To: ".lohnson, Vern" <Vern.John~on(u.~:conocophi llips.c~m% Vern, Sorry about that. I had noted the request on our check list, however it did not make to the permit. Yes, it is acceptable to waive the diverter on CD2-404. As stated in the application, there has not been any indication of shallow gas in the 50+ wells drilled from CD2. A copy of this message should be included with the permit at the rig. Call or message with any questions. Tom Maunder, PE AOGCC Johnson, Vern wrote, On 4/20/2006 4:52 PM: Tom, As discussed, the letter accompanying the Permit to Drill application for CD2-404 requested a waiver for the diverter requirement under 20 AAC 25.035 (h)(2) The signed permit we received did not include a comment regarding the diverter waiver. Please confirm whether or not the diverter waiver is approved. If you need any further information, let me know. Vern Johnson 907-265-6081 1 of 1 4/21 /2006 8:05 AM • ~ ~ ~ ~' ~;~ 1 w ~ ~ ~~~~ ~ ~ '~~ ~ ~ ~ ~ ~LA58iA OIL A1QD GAS COI~TSERQATI011T CO1rIItIISSIOI~T Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 • FRANK H. MURKOWSKI, GOVERNOR f 9~ ~ 333 W. T" AVENUE, SUITE 100 ~` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 i FAX (907) 276-7542 Re: Colville River Unit, Kanik Undefined Oil Pool, CD2-404 ConocoPhillips Alaska, Inc. Permit No: 206-054 Surface Location: 1606' FNL, 1559' FEL, SEC. 2, T11N, R4E, UM Bottomhole Location: 4323' FNL, 4369' FEL, SEC. 26, T12N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced exploration well. This application states that CD2-404, if successful, could become a horizontal injection well in the Kanik (K2) sand. Regulation 20 AAC 25.402(a) prohibits injection except as ordered by the Commission. Accordingly, injection operations in CD2-404 may not begin until the Commission issues an area injection order governing the Kanik sand. In order to convert this well to injection, ConocoPhillips Alaska, Inc. must demonstrate that the injection zone is isolated as required by 20 AAC 25.402(b). 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. 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). CD2-404 Permit No: 206-054 DATED this~day of April, 2006 ~J cc: Department of Fish 8a Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Chairman ConocoPhilli s Alaska, Inc. p Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 13, 2006 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-404 Dear Sir or Madam: i Conoco~illips ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore exploration/injector well from the CD2 drilling pad. The intended spud date for this well is 4/28/06 It is intended that Doyon Rig 19 be used to drill the well. CD2-404 will be an exploration well, which if successful, could become a development horizontal - injection well in the Kanik (K2) sand. After post rig well work, and flow back for clean up (+/- 4 days), CD2-404 will be flow tested for +/- 2 weeks to determine well deliverability. It is requested that the packer placement requirement be relaxed to place the completion packer +/-250 ft TVD above the Nseht~ki 'formation. 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. tGc~r.;4 ~~11,( M~l~ti A waiver for the diverter requirement is requested. This will be the 60th welt on the CD2 pad and there has been no indication of significant gas or shallow gas hydrates. 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 proposed completion diagram. 5. A drilling fluids program summary. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. 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 is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Riser setup If you have any questions or require further information, please contact Vern Johnson, 265-6081, or Chip Alvord at 265-6120. • • Sinc y, Y/3/~ ~- c_._------- Vern Johnson Drilling Engineer Attachments cc: CD2-404 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Tim Crumrine ATO 1706 Lanston Chin Kuukpik Corporation STATE OF ALASKA ~' i; ~ ~ ~a~~ n'i ' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~~ `~' 20 AAC 25.005 ~~~~,`~~ ~l,l ~~. «~ G°ts' Commission.. ,~~~horage 1a. Type of Work: 1 b. Current Well Class: Exploratory Q Development Oil ^ 1 c. Specify if well is proposed for: Drill Q . Re-drill ^ Stratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone^ Single Zone ^ Shale Gas ^ 2. Operator Name: 5. Bond: ~ Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 CD2-404 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11533' ' TVD: 4062' Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: ~ k (/~'Y' ~pp (iA~t Surface: 1606' FNL, 1559' FEL, Sec. 2; T11 N, R4E, UM ~ ADL 380075, 25530 ' / . ~ c(.(1• D~ Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 5013' FNL, 8821' FEL; Sec. 85, T12N, R4E, UM `~ ALK 380075 4/28/2006 ' Total Depth: 9. Acres in Property: 14. Distance to 4323' FNL, 4369' FEL, See. 26, T12N, R4E, UM ° 2560 Nearest Property: 11780' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 371686 y- 5974751 Zone- 4 (Height above GL): 36' RKB feet Well within Pool: CD2-03 , 450 '' 16. Deviated wells: Kickoff depth: 150 ~ ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90° deg Downhole: 1838 psig Surface: 1570 psig ' 18. Casing Program if ti S Setting Depth Quantity of Cement Si ica ons pec B T tt f k ze om o op c. . or sac s Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 52.5# H-40 ~~eided 75 37 37 112 112 pre-installed 13,5" 10-314" 45.5# L-80 E3TC 2676 37 37 2713 2400 639 sx AS Lite, 270 sx LiteCRETE 9.875" 7-5/8" 29.7# L-80 BTCM 5500 37 37 5537 4067 313 sx Class G 6.75" 3.5" 9.3# L-80 SLHT 6146 5387 4060 11533 4062 slotted (finer in open hole 3.5" 9.3 L-80 EUEM 5361 32 32 5393 4060 Tubing completion 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (tt): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling ProgramQ Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Repoli ^ Drilling Fluid Program Q 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 2&5-&081 Printed Name Chip Alvord Title WNS Drilling Team Lead Signature ~ Phone Date ~1(~I ZD±~(o V hnson • Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ~,~(P `~,~~ 50-`b ~ ~-l7 ~~ ~ (~ Date: . ~ . for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: C„t~I,rw,ICir~~r C,kav,t~~`O~, Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [~ Other: H2S measures: Yes ^ No ~ Dire al svy req'd: Yes [~ No ^ 30b0 ~5:..•.;ht nutiv.~+~4 'tc~~, W,O ~ ~ et~~...¢,e•~e-~ 1+~ e ~'i ~~ ~ee~tot--oe'~~~~ ~ 5. ~••~ soCr,,? , ga~''~es~i+~'~rrcc~~4"~1c~c,~s. P~Jck~~c'apkh,occr b AAc» ~ PRO D BY T COMMISSION ~ ,COMMISSIONER DATE: ~ ' O Form 10-401 Revised 12/2005 ' ~~ ~~,~~ Su~[t in~ pli~ te~~ CD2-404 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13-1 /2" Hole / 10-314" Casina Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro 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 temperatures 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 9-7/8" Hole / 7-5/8" Casing 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 HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-3/4" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate 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, 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 HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL « • Procedure 1. Move on Doyon 19. 2. Rig up riser, dewater cellar as needed. 3. Drill 13-1/2" hole to the surface casing point as per the directional plan. (Directional/MWD). 4. Run and cement 10-3/4" surface casing. 5. Install and test BOPE to 5000 psi. 6. Pressure test casing to 2500 psi. 7. Drill out 20' of new hole. Perform leak off test. 8. Pick up and run in hole with 9-7/8" drilling BHA. 9. Drill 9-7/8" hole to intermediate casing point in the Kanik sand. (LWD Program: GR/RES/PWD) 10. Run and cement 7-5/8" casing as per program. Carry out a leak off test down the 10-3/4"x7-5/8" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. ROPE test to 5000 psi. 12. Drill 6-3/4" horizontal section to well TD (LWD Program: GR/RES/PWD/sonic for bond log). 13. Circulate the hole clean and pull out of hole. 14. Run lower completion with 3-1/2" slotted liner and liner hanger. 15. Rig up a-tine and run a cement evatuetion l09 ~ the LWD sonic log is inconclusive. 16. Run 3-%, 9.3#, L-80 tubing with SCSSSV, gas lift mandrels, tubing conveyed pressure gauges, packer and stinger assembly. Sting in, space out and land hanger. 17. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 18. Install tubing head adapter assembly. Pressure test adapter assembly to 5000. psi. Remove 2 way check. 19. Circulate tubing to diesel and install freeze protection in the annulus. 20. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 21. Set BPV and secure well. Move rig off. ORIGINAL • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-03 is the nearest existing well to the CD2-404 plan at 11.3' well to well separation at 275' MD. Drillins~ Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. 2 Lost circulation: Faulting within the Nechelik'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. Annular Pumpins~ Operations: Incidental fluids developed from drilling operations on well CD2-404 will be injected into a permitted annulus on CD2, likely CD2-56 or the class 2 disposal well on CD1 pad. The CD2-404 surtace/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel. to 1700' TVD. ORIGINAL • • DRILLING FLUID PROGRAM SPUD to 10-3/4"surface casing point - 13- 1/2" Intermediate hole to 7- 5/8"" casing point - 9-7/8" Production Hole Section - 6 3/4" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 PP9 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 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 PH 6 KCL Surface Hole: A standard high viscosity fresh water /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 Nechelik 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 interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with t 30PPB 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. Ongoing analysis on mud compatiblity may force the use of mineral oil based mud. If so the mix would likely be a 60/40 LVT200 base oil mix, similar to other WNS wells. !~'IL ~~~~ ~ ~ CD2-404 Kanik Injector Completion 16" Insulated Conductor to 114' 3'/z' x 4-'/2' cross-over, 2 jts below 4-'/z" hanger 3-''/2' 9.3 ppf L-80 EUE 8rd Mod Tubing 2.813" TRMAXX SCSSSV 10-'/." 45.5 ppf L-80 BTCM Surface Casing 2713' MD / 2400' TVD Sperry Sun Directional Plan WP04 04I07I06 Circulate 9.4 ppg inhibited brine before setting packer after tubing is spaced out and landed. URne r Completion: Top MD ZLQ !t!<m 1) Tubing Hanger 32' 32' 2) 4-''/z' 12.6 #/ft IBT-Mod Tubing (2) 3) Crossover 4) 3-''/z', 9.3#Ift, EUE 8rd Mod Tubing 5) Camco TRMAXX SCSSSV 2224' 2000' 6) 3 '/z', 9.3#/ft, EUE 8rd Mod Tubing 7) Camco KBMG- GLM (2.867" ID) 3447' 3000' 8) 3 '/z', 9.3#/ft, EUE 8rd Mod Tubing 9) Camco KBMG- GLM (2.867" ID) w/ RP shear valve installed 4620' 3829' 10) 3-Y:", 9.3#/ft, EUE 8rd Mod Tubing (2) 11) Baker Premier Packer 4700' 3868' 12) 3'h'", 9.3#/ft, EUE 8rd Mod Tubing (1) 13) HES "XN" (2.750")- 63.0° inc 4750' 3891' 14) 3-''/:', 9.3#/ft, EUE 8rd Mod Tubing +/- 20 jts 15) BOT Stinger with Fluted VVLEG/ stinger 5384' 4060' Stung into tieback extension 10', bottom at 5397' Lower Com letion: I9D AAL) IYQ 1IgQ1 16) Baker 5" x 7" Flexlock Liner Hanger 5387' 4060' 17) 3-''/z', 9.3#/ft, SLHT Tubing +/- 4 jts 18) 3-''/z' 9.3#/ft L-80 SLHT liner w/ blank across shale and slots across sand 19) Baker Shoe wl packoff bushing 11523' 4062' Top of cement ~ 4400' MD / 3708' TVD Reservoir at +/- 7-5/8" 29.7 ppf L-80 BTC Mod Production Casing @ +/-90° 5537' MD, 4067' TVD 3 '/z' 9.3#/ft SLHT liner: 8 slots / ft, 2-''/i' x 1/8" Slots TD 6-1/8" hole 11533' MD / 4062' TVD ORIGINAL ~ ~ PRESSURE INFORMATION (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 10-3/4" 2713 / 2400 14.5 1086 1570 7-5/8" 5537 / 4067 16.0 1840 1433 N/A 11533 / 4062 16.0 1838 ~ N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP1 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 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1086 - (0.1 x 2400') =846 psi 2. Drilling below surface casing (10-3/4") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1] x 2400 = 1570 psi OR ASP =FPP - (0.1 x D) = 1840 - (0.1 x 4067) = 1433 psi 3. Drilling below intermediate casing (7-5/8") ASP =FPP - (0.1 x D) = 1838 - (0.1 x4062') = 1432 psi ORIGINAL • Cementing Program: • 10-3/4" Surface Casing run to 2713' MD / 2400' TVD. Cement from 2713' MD to 2213' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2213' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1273' MD). Lead slurry: (2213-1798') X 0.3637 ft3/ft X 1.5 (50% excess) = 226.4 ft3 below permafrost 1798' X 0.3637 ft3/ft X 4 (300% excess) = 2615.7 ft3 above permafrost Total volume = 226.4 + 2615.7 = 2842.1 ft3 => 639 Sx @ 4.45 ft3/sk System: 639 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% BWOW~ D044 freeze suppressant Tail slurry: 500' X 0.3637 ft3/ft X 1.5 (50% excess) = 272.8 ft3 annular volume 80' X 0.5397 ft3/ft =.43.1 ft3 shoe joint volume Total volume = 272.8 + 43.1 = 315.9 ft3 => 270 Sx @ 1.17 ft3/sk System: 270 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 5537 MD / 4067' TVD Cement from 5537' MD to 4400+/-' MD (minimum 300' MD above the packer) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (5537' X400') X 0.2146 ft3/ft X 1.4 (40% excess) = 341.6 ft3 annular vol. 80' X 0.2577 ft3/ft = 20.6 ft3 shoe joint volume Total volume = 341.6 + 20.6 = 362.2 ft3 => 313 Sx @ 1.16 ft3/sk System: 313 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant, 0.07% B155 retarder and 0.4% D 167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement OR161NAL • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-404 Plan: CD2-404 Plan: CD2-404wp04 Proposal Report 07 April, 2006 HALLIBt~RTON Sperry Drilling Services ORIGINAL . Cdwlefbn Methotl: Minimum CUrveAU~ Erro System: ISCwSA COt1000Pi'II~~IpS ~;,a~ ;; ;~ E, a~ ~ ° we,nin Metiwd: ReN, ee.ea Colville River Unit Alaska o o.oaalcorum: NAD19271NADCONCONUS) "'°°""`~°~°' Alpine CD2 Plan: CD2-404 CD2-404wp04 MALLIBUR"~rON Groun~lLeveL ts9:~ Plan: CD2-404 S NR Dd11M S~rvie~s RKB. Planned Doyon 19 ~ 5220N iDOyon X9136.3 * 15.911 y p I NorthmglASP V~ 5974751.48 CD2-404wp04 8000 6 314" Open Hole CD2-404wp04 ~ Target (Toe); 11533' MD, 4062' ND, 4323' FNL & 4369' FEL; Sec26-T12N-R04E c 6000 0 0 0 N 4000 __ - -- 0 z ' ^ a-+ 7 ~ 2000 -- Target (Heel); 5537' MD, 4067' ND 7" Csg - 8 3/4" Hole 7" Csg Pt; 5537' MD, 4067' ND; 5013' FNL 8 3821' FEL; Sec35-T12N-R04E Begin Dir; 4° DLS, 70° TFO, 3623' MD, 3144' ND 9 5/8" Csg - 12 1/4" Hole Start Sail; 35.18° INC, 1398' MD, 1325' ND 9-5/8" Csg Pt; 2713' MD, 2400' ND e^ Continue Dir; 3° DLS, -15° TFO, 550' MD, 548' ND 0 $HL; 1606' FNL 8 1558' FEL; Sec02-T11 N-R04E ' Begin Dir; 3° DLS, 0° TFO, 350' MD, 349' ND ~ Kickoff Poi t; 2° DLS, 300° TFO, 15 ' MD, 150' ND -8000 -6000 -4000 -2000 0 2000 4000 West(-)/East(+) (2000 ft/in) SHL; 1606' FNL 8 1558' FEL; Sec02-T11 N-R04E ' 0 0 Kick-off Point; 2° DLS, 300° TFO, 150' MD, 150' ND ' ^ C Begin Dir; 3° DLS, 0° TFO, 350' MD, 349' ND 1 Continue Dir; 3° DLS, -15° TFO, 550' MD, 548' ND Q 20 O ~ ~ ~ `- 1500- Base Permafrost Start Sail; 35.18° INC, 1398' MD, 1325' ND Q- C-ao N C-30 g51 9 5/8" Csa - 12 1 /4" Hole 9-5/8" Csg Pt; 2713' MD, 2400' ND ~ C-20 U Target (Toe); 11533' MD, 4062' ND, 4323' FNL 8 4369' FEL; Sec26-T12N-R04E ' ~] Begin Dir; 4° DLS, 70° TFO, 3623' MD, 3144' ND `~ 000 7" Csg - 8 3/4" Hole ~ Ad 7" Csg Pt; 5537' MD, 4067' ND; 5013' FNL & 3821' FEL; Sec35-T12N-R04E K-3 K-3 Basal go Target (Heel); 5537' MD, 4067' ND 6 3/4" Open Hole ~~ ^, K-2 `° ~ n 0 4500 g A 0 1500 3000 4500 6000 7500 0 9000 Vertical i, O ~~-- ~-' ConocoPhillips Alaska Database:: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD2 Well: Plan: CD2-404 Wellbore: Plan: CD2-404 Design: CD2-404wp04 Sperry DrilNeg Services Locat Co-ordinate Reference: Well Plan: CD2-404 TVD Reference: Planned Doyon 19 @ 52.20ft (Doyon 19 (36.3 + 15.9)) MD Reference: Planned Doyon 19 @ 52.20ft (Doyon 19 (36.3 + 15.9)) North Reference: True , Survey Calculation Method: 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 Well. Plan: CD2-404 Well Position +N/-S 0.00 ft Northing: 5,974,751.48 ft ~ Latitude: 70° 20' 21.303" N +E/-W 0.00 ft Easting: 371,685.60 ft Longitude: 151 ° 02' 28.449" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 15.90ft -- Welibore Plan: CD2-404 Magnetics.: Model Name Sample-Date Declination Dip Angle Field Strength °) (°) (n~ BGGM2005 4/6/2006 23.36 80.65 57,501 Design CD2-404wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From (TVD) +Nl.S +Ef.IN Direction (ft) (ft) (ft) (°) 36.30 0.00 0.00 357.00 Plan Summary Measured Vertical Dogleg 'Build Turn Depth Inclination Azimuth Depth +N/.S +E/ W Rate Rate Rate ~p (~) (°) (°) (~) (ft) (ft) (°/100ft) (°f100it) (°/100ft) (°) 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 150.00 0.00 0.00 150.00 0.00 0.00 0.00 0.00 0.00 0.00 350.00 4.00 300.00 349.84 3.49 -6.04 2.00 2.00 0.00 300.00 550.00 10.00 300.00 548.26 15.67 -27.14 3.00 3.00 0.00 0.00 1,398.32 35.18 288.57 1,325.47 132.25 -327.56 3.00 2.97 -1.35 -15.41 3,623.61 35.18 288.57 3,144.21 540.54 -1,543.03 0.00 0.00 0.00 0.00 5,537.65 90.05 354.71 4,067.20 1,873.59 -2,264.78 4.00 2.87 3.46 70.10 ~11,533.21 90.05 354.71 4,062.20 ' 7,843.59 -2,817.86 0.00 0.00 0.00 0.00 4!7/2006 10:04:24AM Page 2 of 6 COMPASS 2003.11 Build 50 S D "II' S • perry rl Ing ervlces t-iALLIBURTON Planning Report -Geographic ---- -- ------ ~?!eiNa~ ~i ~J ConacaPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD2 Well: Plan: CD2-404 Wellbore: Plan: CD2-404 Design: CD2-404wp04 Sperry Drilling Services MALLIBURTON Planning Report -Geographic --- ----------------- --- Sperry Drilling Services Local Co=ordinate Reference: Well Plan: CD2-404 ND Reference: Planned Doyon 19 Q 52.20ft (Doyon 19 (36.3 + 15.9)) MD Reference: Planned Doyon 19 @ 52.20ft (Doyon 19 (36.3 + 15.9)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey CD2-404wp04 Map Map ;MD ` Inclination Azimuth ND SSTVQ +N/-S +E(-W Northing `Fasting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (~) (ft) (°/100ft) (ft) 36.30 0.00 0.00 36.30 -15.90 0.00 0.00 5,974,751.48 371,685.60 0.00 0.00 SHL; 1606' FNL & 1558' FEL; Sec02-T11N-R04E 100.00 0.00 0.00 100.00 47.80 0.00 0.00 5,974,751.48 371,685.60 0.00 0.00 150.00 0.00 0.00 150.00 97.80 0.00 0.00 5,974,751.48 371,685.60 0.00 0.00 Kick-off Point; 2° DLS , 300° TFO, 150' MD, 150' TVD 200.00 1.00 300.00 200.00 147.80 0.22 -0.38 5,974,751.70 371,685.23 2.00 0.24 300.00 3.00 300.00 299.93 247.73 1.96 -3.40 5,974,753.50 371,682.23 2.00 2.14 350.00 4.00 300.00 349.84 297.64 3.49 -6.04 5,974,755.07 371,679.62 2.00 3.80 Begin Dir; 3° DLS, 0° TFO, 350' M D, 349' TVD 400.00 5.50 300.00 399.66 347.46 5.56 -9.63 5,974,757.20 371,676.07 3.00 6.06 500.00 8.50 300.00 498.91 446.71 11.65 -20.18 5,974,763.47 371,665.62 3.00 12.69 550.00 10.00 300.00 548.26 496.06 15.67 -27.14 5,974,767.61 371,658.73 3.00 17.07 Continue Dir; 3° DLS, -15° TFO, 5 50' MD, 548' TVD 600.00 11.45 297.99 597.38 545.18 20.17 -35.29 5,974,772.25 371,650.67 3.00 21.99 700.00 14.39 295.19 694.84 642.64 30.12 -55.30 5,974,782.54 371,630.83 3.00 32.97 800.00 17.34 293.32 791.02 738.82 41.31 -80.24 5,974,794.15 371,606.09 3.00 45.45 900.00 20.31 291.98 885.66 833.46 53.71 -110.03 5,974,807.06 371,576.52 3.00 59.39 1,000.00 23.29 290.97 978.50 926.30 67.28 -144.59 5,974,821.22 371,542.19 3.00 74.76 1,100.00 26.27 290.18 1,069.28 1,017.08 82.00 -183.83 5,974,836.61 371,503.21 3.00 91.51 1,200.00 29.26 289.54 1,157.76 1,105.56 97.81 -227.64 5,974,853.16 371,459.68 3.00 109.59 1,300.00 32.24 289.01 1,243.69 1,191.49 114.68 -275.90 5,974,870.85 371,411.72 3.00 128.96 1,398.32 35.18 288.57 1,325.47 1,273.27 132.25 -327.56 5,974,889.30 371,360.37 3.00 149.21 Start Sail; 35.18° INC, 1398' MD, 1 325' TVD 1,400.00 35.18 288.57 1,326.84 1,274.64 132.55 -328.48 5,974,889.62 371,359.46 0.00 149.56 1,500.00 35.18 288.57 1,408.57 1,356.37 150.90 -383.10 5,974,908.90 371,305.17 0.00 170.75 1,600.00 35.18 288.57 1,490.30 1,438.10 169.25 -437.72 5,974,928.18 371,250.87 0.00 191.93 1,700.00 35.18 288.57 1,572.03 1,519.83 187.60 -492.34 5,974,947.46 371,196.58 0.00 213.11 1,798.09 35.18 288.57 1,652.20 1,600.00 205.60 -545.92 5,974,966.37 371,143.32 0.00 233.89 Base Permafrost 1,800.00 35.18 288.57 1,653.76 1,601.56 205.95 -546.96 5,974,966.74 371,142.29 0.00 234.29 1,900.00 35.18 288.57 1,735.49 1,683.29 224.29 -601.58 5,974,986.02 371,087.99 0.00 255.47 2,000.00 35.18 288.57 1,817.22 1,765.02 242.64 -656.20 5,975,005.30 371,033.70 0.00 276.65 2,100.00 35.18 288.57 1,898.95 1,846.75 260.99 -710.83 5,975,024.57 370,979.40 0.00 297.83 2,200.00 35.18 288.57 1,980.68 1,928.48 279.34 -765.45 5,975,043.85 370,925.11 0.00 319.02 2,300.00 35.18 288.57 2,062.41 2,010.21 297.69 -820.07 5,975,063.13 370,870.81 0.00 340.20 2,391.50 35.18 288.57 2,137.20 2,085.00 314.48 -870.05 5,975,080.77 370,821.13 0.00 359.58 C-40 2,400.00 35.18 288.57 2,144.14 2,091.94 316.03 -874.69 5,975,082.41 370,816.52 0.00 361.38 2,500.00 35.18 288.57 2,225.88 2,173.68 334.38 -929.31 5,975,101.69 370,762.23 0.00 382.56 2,600.00 35.18 288.57 2,307.61 2,255.41 352.73 -983.93 5,975,120.97 370,707.93 0.00 403.74 2,700.00 35.18 288.57 2,389.34 2,337.14 371.08 -1,038.55 5,975,140.25 370,653.64 0.00 424.92 2,713.05 35.18 288.57 2,400.00 2,347.80 373.47 -1,045.68 5,975,142.76 370,646.55 0.00 427.69 9-5/8" Csg Pt; 2713' MD, 2400' TV D - 9 5/8" Csg -12 1/4" Hole 2,715.74 35.18 288.57 2,402.20 2,350.00 373.97 -1,047.15 5,975,143.28 370,645.09 0.00 428.26 C-30 2,800.00 35.18 288.57 2,471.07 2,418.87 389.43 -1,093.17 5,975,159.52 370,599.34 0.00 446.10 4/7/2006 10:04:24AM Page 3 of 6 COMPASS 2003.11 Build 50 ORIGINAL ' ~ ~- C01"IOCOPI'11II1 5 S err Drillin Services P y 9 Pl i R t hi G HALLIBURTON ann ng epor - eograp c ~ ~~ ~ri~~3ng ~~~~$ Databases EDM 2003.11 Single User Db Local. Go-ordinate Reference: Weli Plan: CD2-404 Company: ConocoPhiliips Alaska Inc. ND'Reference: Planned Doyon 19 ~ 52.20ft (Doyon 19 (36.3 + 15.9)) Protect: Colville River Unit MD Reference:- Planned Doyon 19 Q 52.20ft (Doyon 19 (36.3 + 15.9)) Site: Alpine CD2 North: Reference: True Weil: Plan: CD2-404 Survey Calculation Method: Minimum Curvature WeNbore: Plan: CD2-404 Design: CD2-404wp04 Planned Survey CD2-404wp04 Map Map. MD Inclination Azimuth. TVD SST/D +N/-S +Ef-W Northing Fasting DLSEV Vert Section (ft) (°) (°) (it) (ft) (ft) (ft) (ft) (~) (°/100ft) (ft) 2,900.00 35.18 288.57 2,552.80 2,500.60 407.77 -1,147.79 5,975,178.80 370,545.05 0.00 467.29 3,000.00 35.18 288.57 2,634.53 2,582.33 426.12 -1,202.41 5,975,198.08 370,490.75 0.00 488.47 3,100.00 35.18 288.57 2,716.26 2,664.06 444.47 -1,257.03 5,975,217.36 370,436.46 0.00 509.65 3,174.56 35.18 288.57 2,777.20 2,725.00 458.15 -1,297.76 5,975,231.73 370,395.98 0.00 525.44 C-20 3,200.00 35.18 288.57 2,797.99 2,745.79 462.82 -1,311.65 5,975,236.64 370,382.17 0.00 530.83 3,300.00 35.18 288.57 2,879.72 2,827.52 481.17 -1,366.27 5,975,255.92 370,327.87 0.00 552.01 3,400.00 35.18 288.57 2,961.45 2,909.25 499.51 -1,420.89 5,975,275.20 370,273.58 0.00 573.19 3,500.00 35.18 288.57 3,043.18 2,990.98 517.86 -1,475.51 5,975,294.47 370,219.28 0.00 594.38 3,600.00 35.18 288.57 3,124.91 3,072.71 536.21 -1,530.14 5,975,313.75 370,164.99 0.00 615.56 3,623.61 35.18 288.57 3,144.21 3,092.01 540.54 -1,543.03 5,975,318.30 370,152.17 0.00 620.56 Begin Dir; 4° DLS, 70° TFO, 3623' MD, 3144' ND 3,700.00 36.32 293.42 3,206.22 3,154.02 556.55 -1,584.66 5,975,335.02 370,110.82 4.00 638.72 3,800.00 38.09 299.36 3,285.88 3,233.68 583.45 -1,638.75 5,975,362.84 370,057.21 4.00 668.42 3,900.00 40.13 304.81 3,363.49 3,311.29 616.99 -1,692.11 5,975,397.28 370,004.43 4.00 704.70 4,000.00 42.41 309.80 3,438.67 3,386.47 656.99 -1,744.51 5,975,438.17 369,952.73 4.00 747.39 4,100.00 44.89 314.35 3,511.03 3,458.83 703.26 -1,795.67 5,975,485.31 369,902.37 4.00 796.28 4,200.00 47.53 318.52 3,580.25 3,528.05 755.58 -1,845.35 5,975,538.47 369,853.60 4.00 851.13 4,300.00 50.31 322.33 3,645.97 3,593.77 813.69 -1,893.31 5,975,597.38 369,806.64 4.00 911.66 4,400.00 53.20 325.85 3,707.87 3,655.67 877.31 -1,939.32 5,975,661.77 369,761.74 4.00 977.60 4,500.00 56.19 329.11 3,765.66 3,713.46 946.12 -1,983.14 5,975,731.32 369.,719.10 4.00 1,048.62 4,600.00 59.26 332.14 3,819.06 3,766.86 1,019.80 -2,024.57 5,975,805.69 369,678.94 4.00 1,124.36 4,646.26 60.71 333.48 3,842.20 3,790.00 1,055.43 -2,042.87 5,975,841.63 369,661.25 4.00 1,160.90 K-3 4,700.00 62.40 334.98 3,867.80 3,815.60 1,097.98 -2,063.41 5,975,884.52 369,641.45 4.00 1,204.47 4,800.00 65.59 337.67 3,911.64 3,859.44 1,180.28 -2,099.46 5,975,967.42 369,606.81 4.00 1,288.54 4,900.00 68.83 340.22 3,950.38 3,898.18 1,266.31 -2,132.56 5,976,053.99 369,575.20 4.00 1,376.18 5,000.00 72.10 342.66 3,983.82 3,931.62 1,355.63 -2,162.53 5,976,143.81 369,546.76 4.00 1,466.96 5,100.00 75.40 345.01 4,011.80 3,959.60 1,447.83 -2,189.24 5,976,236.44 369,521.64 4.00 1,560.42 5,200.00 78.73 347.29 4,034.18 3,981.98 1,542.44 -2,212.54 5,976,331.43 369,499.95 4.00 1,656.12 5,215.79 79.25 347.65 4,037.20 3,985.00 1,557.57 -2,215.91 5,976,346.61 369,496.85 4.01 1,671.41 K-3 Basal 5,300.00 82.07 349.52 4,050.87 3,998.67 1,639.01 -2,232.34 5,976,428.32 369,481.81 4.00 1,753.60 5,400.00 85.42 351.72 4,061.76 4,009.56 1,737.07 -2,248.53 5,976,526.63 369,467.30 4.00 1,852.37 5,477.82 88.04 353.41 4,066.20 4,014.00 1,814.10 -2,258.59 5,976,603.81 369,458.57 4.00 1,929.82 K-2 5,500.00 88.78 353.89 4,066.82 4,014.62 1,836.13 -2,261.04 5,976,625.89 369,456.50 4.00 1,951.95 5,537.65 90.05 354.71 4,067.20 4,015.00 1,873.59 -2,264.78 5,976,663.40 369,453.40 4.00 1,989.55 Target (Heel); 5537' M D, 4067' TVD - 7" Csg Pt; 5537' MD, 4067' TVD; 5013' FNL 8 3821' FEL; Sec35-T12N-R04E - 7" Csg - 8 314" Hole -CD2• 5,600.00 90.05 354.71 4,067.15 4,014.95 1,935.68 -2,270.53 5,976,725.57 369,448.71 0.00 2,051.86 5,700.00 90.05 354.71 4,067.06 4,014.86 2,035.25 -2,279.75 5,976,825.28 369,441.19 0.00 2,151.78 5,800.00 90.05 354.71 4,066.98 4,014.78 2,134.83 -2,288.98 5,976,924.99 369,433.67 0.00 2,251.70 5,900.00 90.05 354.71 4,066.90 4,014.70 2,234.40 -2,298.20 5,977,024.70 369,426.16 0.00 2,351.62 6,000.00 90.05 354.71 4,066.81 4,014.61 2,333.97 -2,307.43 5,977,124.41 369,418.64 0.00 2,451.54 6,100.00 90.05 354.71 4,066.73 4,014.53 2,433.55 -2,316.65 5,977,224.12 369,411.12 0.00 2,551.46 6,200.00 90.05 354.71 4,066.65 4,014.45 2,533.12 -2,325.88 5,977,323.82 369,403.60 0.00 2,651.38 6,300.00 90.05 354.71 4,066.56 4,014.36 2,632.69 -2,335.10 5,977,423.53 369,396.08 0.00 2,751.30 4/7/2006 10:04:24AM Page 4 of 6 COMPASS 2003.11 Build 50 ORIGINAL ~-' Sperry Drilling Services MALLIBURTDN COnoCOPhillips Planning Report -Geographic - --- - ----- AI~Ska Sperry DrfiNng Services Database: EDM 2003.11 Single User Db Local Coordinate Reference: Well Plan: CD2-404 Company:. ConocoPhillips Alaska Inc. TVD Reference:. '- Planned Doyon 19 @ 52.20ft (Doyon 19 (36.3 + 15.9)) , Project: Colville River Unit MD Reference: Planned Doyon 19 Q 52.20ft (Doyon 19 (36.3 + 15.9)) Site: Alpine CD2 North Reference: True Well: Plan: CD2-404 SurveyCalculatiortMethod: Minimum Curvature Wellbore: Pian: CD2-404 Design: CD2-404wp04 Planned Survey CD2-404wp04 Map Map MD Inclination Azimuth TVD SSTVD +Nl-S +E!=W Northing Fasting DLSEV Vert Section lft), (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100ft) (ft) 6,400.00 90.05 354.71 4,066.48 4,014.28 2,732.27 -2,344.33 5,977,523.24 369,388.56 0.00 2,851.22 6,500.00 90.05 354.71 4,066.40 4,014.20 2,831.84 -2,353.55 5,977,622.95 369,381.04 0.00 2,951.14 6,600.00 90.05 354.71 4,066.31 4,014.11 2,931.41 -2,362.78 5,977,722.66 369,373.52 0.00 3,051.06 6,700.00 90.05 354.71 4,066.23 4,014.03 3,030.99 -2,372.00 5,977,822.37 369,366.00 0.00 3,150.98 6,800.00 90.05 354.71 4,066.15 4,013.95 3,130.56 -2,381.23 5,977,922.08 369,358.49 0.00 3,250.90 6,900.00 90.05 354.71 4,066.06 4,013.86 3,230.14 -2,390.45 5,978,021.78 369,350.97 0.00 3,350.82 7,000.00 90.05 354.71 4,065.98 4,013.78 3,329.71 -2,399.68 5,978,121.49 369,343.45 0.00 3,450.74 7,100.00 90.05 354.71 4,065.90 4,013.70 3,429.28 -2,408.90 5,978,221.20 369,335.93 0.00 3,550.66 7,200.00 90.05 354.71 4,065.81 4,013.61 3,528.86 -2,418.13 5,978,320.91 369,328.41 0.00 3,650.58 7,300.00 90.05 354.71 4,065.73 4,013.53 3,628.43 -2,427.35 5,978,420.62 369,320.89 0.00 3,750.49 7,400.00 90.05 354.71 4,065.65 4,013.45 3,728.00 -2,436.58 5,978,520.33 369,313.37 0.00 3,850.41 7,500.00 90.05 354.71 4,065.56 4,013.36 3,827.58 -2,445.80 5,978,620.04 369,305.85 0.00 3,950.33 7,600.00 90.05 354.71 4,065.48 4,013.28 3,927.15 -2,455.03 5,978,719.75 369,298.33 0.00 4,050.25 7,700.00 90.05 354.71 4,065.40 4,013.20 4,026.72 -2,464.25 5,978,819.45 369,290.81 0.00 4,150.17 7,800.00 90.05 354.71 4,065.31 4,013.11 4,126.30 -2,473.48 5,978,919.16 369,283.30 0.00 4,250.09 7,900.00 90.05 354.71 4,065.23 4,013.03 4,225.87 -2,482.70 5,979,018.87 369,275.78 0.00 4,350.01 8,000.00 90.05 354.71 4,065.15 4,012.95 4,325.44 -2,491.93 5,979,118.58 369,268.26 0.00 4,449.93 8,100.00 .90.05 354.71 4,065.06 4,012.86 4,425.02 -2,501.15 5,979,218.29 369,260.74 0.00 4,549.85 8,200.00 90.05 354.71 4,064.98 4,012.78 4,524.59 -2,510.38 5,979,318.00 369,253.22 0.00 4,649.77 8,300.00 90.05 354.71 4,064.90 4,012.70 4,624.17 -2,519.60 5,979,417.71 369,245.70 0.00 4,749.69 8,400.00 90.05 354.71 4,064.81 4,012.61 4,723.74 -2,528.82 5,979,517.42 369,238.18 0.00 4,849.61 8,500.00 90.05 354.71 4,064.73 4,012.53 4,823.31 -2,538.05 5,979,617.12 369,230.66 0.00 4,949.53 8,600.00 90.05 354.71 4,064.65 4,012.45 4,922.89 -2,547.27 5,979,716.83 369,223.14 0.00 5,049.45 8,700.00 90.05 354.71 4,064.56 4,012.36 5,022.46 -2,556.50 5,979,816.54 369,215.63 0.00 5,149.37 8,800.00 90.05 354.71 4,064.48 4,012.28 5,122.03 -2,565.72 5,979,916.25 369,208.11 0.00 5,249.29 8,900.00 90.05 354.71 4,064.40 4,012.20 5,221.61 -2,574.95 5,980,015.96 369,200.59 0.00 5,349.21 9,000.00 90.05 354.71 4,064.31 4,012.11 5,321.18 -2,584.17 5,980,115.67 369,193.07 0.00 5,449.13 9,100.00 90.05 354.71 4,064.23 4,012.03 5,420.75 -2,593.40 5,980,215.38 369,185.55 0.00 5,549.05 9,200.00 90.05 354.71 4,064.15 4,011.95 5,520.33 -2,602.62 5,980,315.09 369,178.03 0.00 5,648.97 9,300.00 90.05 354.71 4,064.06 4,011.86 5,619.90 -2,611.85 5,980,414.79 369,170.51 0.00 5,748.89 9,400.00 90.05 354.71 4,063.98 4,011.78 5,719.47 -2,621.07 5,980,514.50 369,162.99 0.00 5,848.81 9,500.00 90.05 354.71 4,063.90 4,011.70 5,819.05 -2,630.30 5,980,614.21 369,155.47 0.00 5,948.73 9,600.00 90.05 354.71 4,063.81 4,011.61 5,918.62 -2,639.52 5,980,713.92 369,147.96 0.00 6,048.65 9,700.00 90.05 354.71 4,063.73 4,011.53 6,018.20 -2,648.75 5,980,813.63 369,140.44 0.00 6,148.57 9,800.00 90.05 354.71 4,063.65 4,011.45 6,117.77 -2,657.97 5,980,913.34 369,132.92 0.00 6,248.49 9,900.00 90.05 354.71 4,063.56 4,011.36 6,217.34 -2,667.20 5,981,013.05 369,125.40 0.00 6,348.41 10,000.00 90.05 354.71 4,063.48 4,011.28 6,316.92 -2,676.42 5,981,112.76 369,117.88 0.00 6,448.33 10,100.00 90.05 354.71 4,063.40 4,011.20 6,416.49 -2,685.65 5,981,212.46 369,110.36 0.00 6,548.25 10,200.00 90.05 354.71 4,063.31 4,011.11 6,516.06 -2,694.87 5,981,312.17 369,102.84 0.00 6,648.17 10,300.00 90.05 354.71 4,063.23 4,011.03 6,615.64 -2,704.10 5,981,411.88 369,095.32 0.00 6,748.09 10,400.00 90.05 354.71 4,063.15 4,010.95 6,715.21 -2,713.32 5,981,511.59 369,087.80 0.00 6,848.01 10,500.00 90.05 354.71 4,063.06 4,010.86 6,814.78 -2,722.55 5,981,611.30 369,080.29 0.00 6,947.93 10,600.00 90.05 354.71 4,062.98 4,010.78 6,914.36 -2,731.77 5,981,711.01 369,072.77 0.00 7,047.85 10,700.00 90.05 354.71 4,062.89 4,010.69 7,013.93 -2,741.00 5,981,810.72 369,065.25 0.00 7,147.77 10,800.00 90.05 354.71 4,062.81 4,010.61 7,113.50 -2,750.22 5,981,910.43 369,057.73 0.00 7,247.69 10,900.00 90.05 354.71 4,062.73 4,010.53 7,213.08 -2,759.45 5,982,010.13 369,050.21 0.00 7,347.61 11,000.00 90.05 354.71 4,062.64 4,010.44 7,312.65 -2,768.67 5,982,109.84 369,042.69 0.00 7,447.53 11,100.00 90.05 354.71 4,062.56 4,010.36 7,412.23 -2,777.90 5,982,209.55 369,035.17 0.00 7,547.45 11,200.00 90.05 354.71 4,062.48 4,010.28 7,511.80 -2,787.12 5,982,309.26 369,027.65 0.00 7,647.37 11,300.00 90.05 354.71 4,062.39 4,010.19 7,611.37 -2,796.35 5,982,408.97 369,020.13 0.00 7,747.29 11,400.00 90.05 354.71 4,062.31 4,010.11 7,710.95 -2,805.57 5,982,508.68 369,012.62 0.00 7,847.21 4/7/2006 10.~04:24AM Page 5 of 6 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhitlips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD2 Well: Plan: CD2-404 Welibores Plan: CD2-404 :Design: CD2-404wp04 Sperry Drilling Services Local Co-ordinate Reference: Well Plan: CD2-404 TVD Reference: Planned Doyon 19 @ 52.20ft (Doyon 19 (36.3 + 15.9)) MD Reference: Planned Doyon 19 @ 52.20ft (Doyon 19 (36.3 + 15.9)) North Reference: True Survey Calculation Method:. Minimum Curvature fined Survey CD2-404wp04 :Map Map MD Inclination Azimuth TVD SSTVD +N/.S +E/.W 'Northing Fasting DLSEV Vert Section (ft) {°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 11,500.00 90.05 354.71 4,062.23 4,010.03 7,810.52 -2,814.80 5,982,608.39 369,005.10 0.00 7,947.13 11,533.21 90.05 354.71 4,062.20 4,010.00 7,843.59 -2,817.86 5,982,641.50 369,002.60 0.00 7,980.31 Target (Toe); 11533' MD, 4062' TV D, 4323' FNL 8 4369' FEL ; Sec26-T12 N-R04E - 6 3/4" Open Hole -CD2-404wp04 Toe Geologic Targets Plan: CD2-404 TVD Target Name. +N/-S +E/-W Northing Fasting (ft) =Shape ft ft (ft) (ft) 4,067.20 CD2-404wp04 Heel 1,873.59 -2,264.78 5,976,663.40 369,453.40 - Point 4,062.20 CD2-404wp04 Toe 7,843.59 -2,817.86 5,982,641.50 369,002.60 - Point Prognosed Casing. Points Measured Vertical. Casing Hole Depth Depth Diameter Diameter 2,713.05 2,400.00 9-5/8 12-1/4 5,537.65 4,067.20 7 8-3/4 11,533.20 4,062.20 6-3/4 6-3/4 Prognosed Formation Intersection Points Measured Vertical Depth' .Inclination Azimuth DeptF +N/-E +FJ-W (~) (°) (°) (~) (ft) (ft) Name 1,798.09 35.18 288.57 1,652.20 205.60 -545.92 Base Permafrost 2,391.50 35.18 288.57 2,137.20 314.48 -870.05 C-40 2,715.74 35.18 288.57 2,402.20 373.97 -1,047.15 C-30 3,174.56 35.18 288.57 2,777.20 458.15 -1,297.76 C-20 4,646.26 60.71 333.48 3,842.20 1,055.43 -2,042.87 K-3 5,215.79 79.25 347.65 4,037.20 1,557.57 -2,215.91 K-3 Basal 5,477.82 88.04 353.41 4,066.20 1,814.10 -2,258.59 K-2 4/7/2006 10:04:24AM Page 6 of 6 COMPASS 2003.11 Build 50 s S D 'II' S • perry rl Ing ervices HALLIBUf~TON Planning Report -Geographic --------------- OR161NAL • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-404 Plan: CD2-404 CD2-404wp04 Anticollision Report 06 April, 2006 HAL..L.IE3URTON Sperry Drilling Services ORIGINAL ARncowslDR SETrlr2as i ~' r•-^ °" ]•"° Critical Issues: ConoeoPhillips CD2-404wp04 Ir..~pY.n,nM.n,~ MD InanY ~a~Ben. -_ ,, -_ ,.. Mlnor risk 1/200 applied t0 CD2-15 due to CIOSe approach CY•W9en MrNOd. MirAmuntwvWn 4Faska 36.30 To 11533.21 Mu~mum Rmpe: 1M96Ytl%xOwba '° Ernr M•del: ISCW9A .. ,~,- - SranlMtlwE: Tr•v. CYIirW9r NaM , Erica SUr1~•r: Eligdul Cenb ._. h1ALLIBLIRTON w.min MsBSOd: Rubr B•ssd - st»~ tMlllp Swvka BI'R\"E1' PROGRAM -"' Mfr: 290602-06T99:96:90 \'rlMrrrd: l'n s'rnbn: ~~~~ •r ~~ -•=w ereo »'.a isen sraa r~'so xM.o ..« ..M.. m~ ~ ->no vmo~ DrMh Fnm DrMb Ts Bunev/Plss i.N r-......,w.wu..e i.. M!0 1208.BR CD2JOInpi CBG\'R0.ff5 +~ -r.s~ sxuwx ~snn --svao nau =sro .im,r w.~ c°x~M CD2-02PB1 .._.._. ,..,,. ~...,. ~ 0 ~~~ ~ CD2-02 /~- -30 / 33 VT / 1 , 10/300,,., /~./ (~~~ V / / /:. ~~~ - r _ -90/27Dr-'-- _ t""" / ~,~ CD2-27PBi CD2-21 \ _ ~~ -120 / CD2-i5PB2 - _ CD2-15PB1- x_150 CD2 75 AZ-BC CD2-09L1 CD2-09PB1 V '2.L';,y I..uvwro ~~ l~{t ~ _~.. i ~1-Sam` CD2-14 ~~~ ~r ~~,~ ~, _ CD2-18IBag) -78C. '.5., CD2-16 CD2-tePB1 CD2-17A CD2-05 ~ CD2-20 I Nor: CD2-OSL1 ~ CD2-19 NEGATIVE TFOrArI wba hom Ihs CD2-18 4urwy Edibr oI TrawYina CYlindar Report should M pbtbd on the NR sills of Na TravIllna tyllndor. Travelling Cylinder Azimuth (TFO+AZI) [°~ w Centre to Centre Separation 125 Nine TraYelYne C\linder ArimurY ITFOeAlp I°I vs Cenmr b Creme Srpsnrin I4 fubl BECTIO!r' DETABS car bfn br .A:1 nm .rv/s .Er-w Dlq TF.re eser TsrYrl 1 2n2o auo aro 2c-to aao nao o.oo aao o.oo 2 15aaa noo aoo Isaoo aeo aao a.ao aoo aao ~ 2:aao am 2aaao 2ri.82 2.J9 a.w z.ao 2aaoo 2.tlo ~ 4raou Inoo 2aaan slaw lsn .z].u 2.09 nao n.m ,< u9a2x 241e ztlas] ux.n uz~s an_~+ 2.ao -Ica u9n 6 J622.61 2(18 xM24] 21Ja21 410_SJ -1 W.03 0.00 0.00 620.K ] !NT.69 90.0.\ 241]1 iU6].x0 181!_[9 -x2N]8 A.00 ]0.10 19891 CD2LMp01 Heel tl 11422.51 9Q04 3K]I J116L20 ]tlIJ 4f -xtll].esi O.Ip Q00 ]980!1 CDi-0Jnp0l Tor • 4/6/2006 5:14 PM cozatlll -180 / 180 lance Cono~oPh iilips Alaska Company: ConocoPhillips Alaska Inc. Project: Colville River Unit .Reference Site: Alpine CD2 Site Error: O.OOft Reference Well: Plan: CD2-404 Well Error:- O.OOft .Reference Wellbore Plan: CD2-404 Reference: Design: CD2-404wp04 • Sperry Drilling Services HALLIBUFlTON Anticollision Report ---• Sperry Drilling Services Local co-ordinate Reference: Well Plan: CD2-404 TVD Reference: Planned Doyon 19 Q 52.20ft (Doyon 19 (36.3 + 15.9)) MD Reference: Planned Doyon 19 @ 52.20ft (Doyon 19 (36.3 + 15.9)) North: Reference; True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM 2003.11 Single User Db Offset TVD Reference: Offset Datum Reference CD2-404wp04 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refere Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,349.69ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 4/6/2006 From: To (ft) (ft) Survey ('Wellbore) Tool Name Description 36.30 1,200.00 CD2-404wp04 (Plan: CD2-404) CB-GYRO-SS Camera based gyro single shot 1,200.00 11,533.21 CD2-404wp04 (Plan: CD2-404) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/6/2006 5:01:39PM Page 2 of 3 COMPASS 2003.11 Build 50 ORIGINAL ~. ConocoPhillips Alaska Company::.. ConocoPhillips Alaska Inc. Project: Colville River Unit Reference Site: Alpine CD2 Site Error: O.OOft Reference Well: Plan: CD2-404 Well Error: O.OOft Reference Welibore Plan: CD2-404 Reference Design: CD2-404wp04 Sperry Drilling Services Anticollision Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey.Galculation Method: Output errors are at Databases Offset ND References: HALLIBUTATON Sperry Drilling Services Well Plan: CD2-404 `Planned Doyon 19 @ 52.20ft (Doyon 19 (36.3 + 15.9)) Planned Doyon 19 @ 52.20ft (Doyon 19 (36.3 + 15.9)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Summary Reference Offset. .Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Dis#ar-ce (ft) from Plan Offset Well - Wellbore -Design (ft) (ft) (ft) (ft) Alpine CD2 CD2-01 -CD2-01 -CD2-01 349.97 350.00 29.27 7.42 21.86 Pass -Major Risk CD2-01 -CD2-01 L1 -CD2-01 L1 349.97 350.00 29.27 7.42 21.86 Pass -Major Risk CD2-01 -CD2-01 PB1 -CD2-01 PB1 349.97 350.00 29.27 7.42 21.86 Pass -Major Risk CD2-02 -CD2-02 -CD2-02 400.43 400.00 18.46 8.54 9.94 Pass -Major Risk CD2-02 -CD2-02PB1 -CD2-02P61 400.43 400.00 18.46 8.54 9.94 Pass -Major Risk CD2-03 -CD2-03 -CD2-03 275.37 275.00 11.32 5.92 5.40 Pass -Major Risk CD2-03 -CD2-03L1 -CD2-03L1 275.37 275.00 11.32 5.92 5.40 Pass -Major Risk CD2-05 -CD2-05 -CD2-05 199.50 200.00 11.22 4.14 7.08 Pass -Major Risk CD2-05 -CD2-05L1 -CD2-05L1 199.50 200.00 11.22 4.14 7.08 Pass -Major Risk CD2-06 -CD2-06 -CD2-06 472.07 475.00 16.31 9.15 7.25 Pass -Major Risk CD2-07 -CD2-07 -CD2-07 372.27 375.00 25.46 7.82 17.65 Pass -Major Risk CD2-07 -CD2-07PB1 -CD2-07PB1 372.27 375.00 25.46 7.93 17.54 Pass -Major Risk CD2-07 -CD2-07P62 -CD2-07PB2 372.27 375.00 25.46 7.93 17:54 Pass -Major Risk CD2-08 -CD2-08 -CD2-08 347.54 350.00 40.93 7.37 33.56 Pass -Major Risk CD2-09 -CD2-09 -CD2-09 813.24 825.00 28.04 16.75 12.15 Pass -Major Risk CD2-09 -CD2-09L1 -CD2-09L1 813.24 825.00 28.04 16.75 12.15 Pass -Major Risk CD2-09 -CD2-09P61 -CD2-09P61 813.24 825.00 28.04 16.75 12.15 Pass -Major Risk CD2-10 -CD2-10 -CD2-10 248.76 250.00 61.11 4.59 56.52 Pass -Major Risk CD2-10 -CD2-10P61 -CD2-10P61 248.76 250.00 61.11 4.74 56.37 Pass -Major Risk CD2-11 -CD2-11 -CD2-11 371.85 375.00 72.53 7.93 64.61 Pass -Major Risk CD2-12 -CD2-12 -CD2-12 661.68 675.00 85.36 12.95 72.66 Pass -Major Risk CD2-13 -CD2-13 -CD2-13 393.39 400.00 92.24 8.42 83.82 Pass -Major Risk CD2-13 -CD2-13PB1 -CD2-13PB1 393.39 400.00 92.24 8.42 83.82 Pass -Major Risk CD2-13 -CD2-13PB2 -CD2-13P62 393.39 400.00 92.24 8.42 83.82 Pass -Major Risk CD2-14 -CD2-14 -CD2-14 222.76 225.00 100.50 4.10 96.40 Pass -Major Risk CD2-15 -CD2-15 -CD2-15 3,588.63 3,700.00 83.20 37.67 51.34 Pass -Minor 1/200 CD2-15 -CD2-15PB1 -CD2-15P61 3,588.63 3,700.00 83.20 49.92 39.11 Pass -Minor 1/200 CD2-15 -CD2-15PB2 -CD2-15PB2 3,588.63 3,700.00 83.20 37.67 51.34 Pass -Minor 1/200 CD2-16 -CD2-16 -CD2-16 247.23 250.00 120.84 4.94 115.91 Pass -Major Risk CD2-16 -CD2-16 (Sag) -CD2-16 (Sag) 247.23 250.00 120.84 4.49 116.36 Pass -Major Risk CD2-17 -CD2-17 -CD2-17 271.39 275.00 131.06 5.04 126.03 Pass -Major Risk CD2-17 -CD2-17A -CD2-17A 271.39 275.00 131.06 5.04 126.03 Pass -Major Risk CD2-18 -CD2-18 -CD2-18 319.93 325.00 142.24 6.78 135.46 Pass -Major Risk CD2-18 -CD2-18P61 -CD2-18P81 319.93 325.00 142.24 6.78 135.46 Pass -Major Risk CD2-19 -CD2-19 -CD2-19 222.66 225.00 150.51 4.09 146.42 Pass -Major Risk CD2-20 -CD2-20 -CD2-20 318.83 325.00 161.37 6.77 154.60 Pass -Major Risk CD2-21 -CD2-21 -CD2-21 2,356.24 2,475.00 148.72 55.48 96.09 Pass -Major Risk CD2-21 -CD2-21 P61 -CD2-21 P61 2,356.24 2,475.00 148.72 55.59 95.98 Pass -Major Risk CD2-22 -CD2-22 -CD2-22 222.06 225.00 180.77 4.08 176.69 Pass -Major Risk CD2-23 -CD2-23 -CD2-23 4,951.49 5,000.00 164.71 110.87 67.65 Pass -Major Risk CD2-23 -CD2-23P61 -CD2-23PBi 4,951.49 5,000.00 164.71 110.87 67.65 Pass -Major Risk CD2-24 -CD2-24 -CD2-24 221.35 225.00 200.86 4.08 196.79 Pass -Major Risk CD2-24 -CD2-24P61 -CD2-24P61 221.35 225.00 200.86 4.08 196.79 Pass -Major Risk CD2-25 -CD2-25 -CD2-25 245.17 250.00 211.10 4.85 206.26 Pass -Major Risk CD2-26 -CD2-26 -CD2-26 410.59 425.00 221.46 7.75 213.78 Pass -Major Risk CD2-26 -CD2-26PB1 -CD2-26PB1 221.99 225.00 221.12 4.52 216.60 Pass -Major Risk CD2-26 -CD2-26P62 -CD2-26PB2 221.99 225.00 221.19 4.37 216.82 Pass -Major Risk CD2-28 -CD2-28 -CD2-28 268.53 275.00 241.30 5.68 235.63 Pass -Major Risk CD2-28 -CD2-28P61 -CD2-28PB1 268.53 275.00 241.30 5.68 235.63 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/6/2006 5:01:39PM Page 3 of 3 COMPASS 2003.11 Build 50 ORIGINAL ~~~~g • a g ~ gB~~ ~ I ! 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Meas. Incl. TRUE Subsea N(+yS(-) View VS Meas. Incl. TRUE Subsea N(+yS(-) View VS Dist. Depth Angle Azi. ND E(+yyy(_) (357°) Comments Depth Angle Azi. ND E(+yW(_) (357°) Comments POOL Min POOL Min Distance (450.36 ft Distance (450.36 ft in POOL (5537.65 in POOL (5537.65 11533.21 MD) to 11533.21 MD) to CD2-03 Rig IFR CD2-404wp04 Pla 430. 830 90.0 354.71 4012.7 5979418. 369245. 4749.67 (4014 - 4105 700 61.4 334.2 4079.06 5979499. 369683. 4815.09 (4014 - 4105 Closest Approach: Reference Well: CD2-404wp04 P lan Offset Well: CD2-23 coons. - words. - 3-0 ctr- ASP ASP ctr Mln. Meas. InG. TRUE Subsea N(+yS(-) View VS Meas. InG. TRUE Subsea N(+yS(-) View VS Dist. Depth Angle Azi. ND E(+yW(_) (357°) Comments Depth Angle Azi. ND E(+yW(_) (357°) Comments POOL Min POOL Min Distance (544.95 ft Distance (544.95 ft in POOL (5537.65 in POOL (5537.65 11533.21 MD) to 11533.21 MD) to CD2-23 IIFR (4014 CD2-404wp04 Pla 341.9 5537.6 90.0 354.71 4015.11 5976663. 369453. 1989.5 4105 TVDss) 510 44.2 304.9 4069.7 5976156. 369645. 1476.19 (4014-4105 Closest Approach: Reference W ell: CD2-404wp04 P lan Offset Well: CD2-0 9 Coords.- Coords.- 3-0 ctr- ASP ASP ctr MIn. Meas. InG. TRUE Sutuea N(+yS(_) View VS Meas. Incl. TRUE Subsea N(+yS(-) View VS Oist. Depth Angle Azi. ND E(+yW(_) (357°) Comments Depth Angle Azi. ND E(+yW(_) (357°) Comments POOL Min POOL Min Distance (618.19 ft Distance (618.19 ft in POOL (5537.65 in POOL (5537.65 11533.21 MD) to 11533.21 MD) to CD2-09 (4014 - CD2-404wp04 Pla 918.1 700 90.0 354.71 4013.83 5978121. 369343. 3450.71 4105 TVDss) 56.4 314. 4054.25 5978117. 368726. 3468.77 (4014 - 4105 CD2-404wp04 POOL Summary.xls Page 1 of 2 4/7/20116 9:49 AM • • Closest in POOL ,w°....r ., Closest Approach: Reference Well: CD2-404wp04 P lan Offset Weli: CD2-11 Coords.- Coords.- 3-0 ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+yS(-) View VS Meas. Incl. TRUE Subsea N(+yS(-) View VS Dist Depth Angle Azi. TVD E(+yW(_) (357°) Comments Depth Angle Azi. TVD E(+yW(_) (357°) Comments POOL Min POOL Min Distance (700.11 ft Distance (700.11 ft in POOL (5537.65 in POOL (5537.65 11533.21 MD)to 11533.21 MD)to CD2-11 Rig IFR CD2-404wp04 Pla 700.1 620 90.0 354.71 4014.53 597732 369403. 2651.3 (4014-4105 610 59.3 309.0 4022.26 5977234. 368709. 2586.0 (4014-4105 Closest Approach: Reference Well: CD2-404wp04 P lan offset Welt: CDZ-12 Coords. - Cooros. - 3-0 ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+yS(-) View VS Meas. Incl. TRUE Subsea N(+yS(-) View VS Dist. Depth Angle Azi. TVD E(+yW(_) (357°) Comments Depth Angle Azi. TVD E(+yW(_) (357°) Comments POOL Min POOL Min Distance (914.93 ft Distance (914.93 ft in POOL (5537.65 in POOL (5537.65 11533.21 MD) to 11533.21 MD) to CD2-12 IIFR (4014 CD2-404wp04 Pla 914.9 5537.6 90.0 354.71 4015.11 5976663. 369453. 1989.52 4105 TVDss) 480 34.4 320.1 4099.2 5976398. 370325. 1694.29 (4014 - 4105 Closest Approach: Reference W ell: CD2-404wp04 P lan Offset Well: CD2-1 5 Caoros. - words. - 3-0 ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+yS(-) View VS Meas. Incl. TRUE Subsea N(+yS(-) View VS Dlst. Depth Angle Azi. TVD E(+yW(-) (357°) Comments Depth Angle Azi. TVD E(+yW(_) (357°) Comments POOL Min POOL Min Distance (1103.27 Distance (1103.27 ft) in POOL R) in POOL (5537.65 - 11533.2 (5537.65 - 11533.2 MD) to CD2-15 MD) to CD2- (4014 - 4105 404wp04 Plan (40 11032 5537. 90.0 354.71 4015.11 5976663. 369453. 1969.52 TVDss) 51 45. 290. 4069.9 5975583. 369236. 917.433 -410,5 TVDss) CD2-404wp04 POOL Summary.xls Page 2 of 2 4/7/2006 9:49 AM • • • __ .SHARON K. ALLSUP-DRAKE 1143 CONOCOPHILLIPS ATO 1530. i-~ 700 G ST. DATE ~ ~ ~ ~ ~ L%'~-'L~C/ 56-1551 /441 ANCHORAGE AK 99501 {/~' I /~- (~j/~/~ J ~ / /~ ~ ) PAY TO THE / ~ / ~ ! ~ N (S t-r 1 ~Il/~~ CC-.. ~ ~~C/ U V ORDER OF - !~ ,~"" G(.G ~~ ~v ~'S ~-~- ~~ 60` DOLLARS ' oe~° ~ax~PS JPMorganChase ~ j Valid Up To5o00Dollars JPMorgan Chase Bank, N.A. Columbus, OH / _ ~~ ~. MEMO ---------------------- -------- ---------- -- . ~:D44LL55L1~:528747L90792711'LL43 • C TRANSMITTAL LETTER CHECKLIST WELL NAME Cf~L~ C~ Z - ~~ ~f PTD# 2-~ ~ "' ~S~" Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples ar~k first caug~it apd 1 ample intervals ~~ ~ ~ s,c s~ v f through tar et zones. ND~ v~I-~d v Please note the following special conditi of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of welly until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ~ ro ram. ~, ~i~ ~e,/ls.• l•/7~6 Rev: 1/25/06 C:\j ody\transmittal_checkl i st • • ^ ^ 0 0 'c ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ui ~ ~ ~ c ~a m 3 m o- ~ 0 ~ y y a o ~ , , ~ C ~ ~ tq: C ~ N O Q L , ~ ~ ~ ~ ~ ~ C ~ ~ ~ ~ D: i L' a ~ ~ ~ ~ ~ ~ ~ O d e- N U ~ C ~ ~ ~ ~ ~ ~ ~ ~ y ~ ~ ~ ~ ~ ~ ~ a~ , N M• ~ ~ ~ ~ X~ . N p d 0 C ~ ~ ~ ~ ~ ~ ~ c ~ ~ ~ ~ i ~ ~ ~ O. ~~ ~ O, ~ ~ ~ ~ c N Q C O O ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ y ~ N, a ~ ., I ~ ~ f6 C E ~ a~ ° C m y. 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"_ d, °--, o; m, m, U, ~ " ~ o., o, cn, cn, U, w n ' 4' O ~ N M V' tq (p O N M r 00 CA f~ ~~ O 00 O _ O N N N N M V N N ACS <O f~ 00 N N N N O O N M M N M tt M M M ~ CO f~ M M _M M M O f M U _ _ _ _ c ~ ~ w ~ r 1S1 O ~ O~ oo.N to a ~ ~ ~ ~ ~ '~ °~~ N •C ~ ~ O C L O Q 0 U a Q a ~ w a w~ .... . ~ a~ Well History File APPENDIX u 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 We11 History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~o~ -osY~ * r 394 ~ Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 26 14:57:46 2006 Reel Header Service name .............LISTPE Date .....................06/06/26 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/06/26 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 Kanik Test Well MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA Scientific Technical Services Scientific Technical Services CD2-404 501032053000 ConocoPhilips Alaska, Inc Sperry Drilling Services 26-JUN-06 MWD RUN 2 MWD RUN 3 JOB NUMBER: W-0004348860 W-0004348860 LOGGING ENGINEER: R. KRELL R. KRELL OPERATOR WITNESS: D. BURLEY D. BURLEY SURFACE LOCATION SECTION: 2 TOWNSHIP: 11N RANGE: 4E FNL: 1606 FSL: FEL: 1559 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 52.70 GROUND LEVEL: 15.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2693.0 2ND STRING 6.750 7.625 5560.0 3RD STRING PRODUCTION STRING 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 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) RUN 3 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT THE CONOCOPHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 6. MWD RUNS 1 - 3 REPRESENT WELL CD2-404 WITH API#: 50-103-20530-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11540'MD/4066'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/26 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; DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH GR 2656.5 RPD 2670.0 FET 2670.0 RPS 2670.0 RPM 2670.0 RPX 2670.0 ROP 2702.5 all bit runs merged. STOP DEPTH 11483.0 11490.0 11490.0 11490.0 11490.0 11490.0 11540.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED ~TH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2656.5 5571.0 MWD 3 5571.0 11540.0 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 .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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2656.5 11540 7098.25 17768 2656.5 11540 RPD MWD OHMM 0.21 2000 23.1339 17641 2670 11490 RPM MWD OHMM 0.21 2000 19.1901 17641 2670 11490 RPS MWD OHMM 0.2 1711.68 13.2533 17641 2670 11490 RPX MWD OHMM 0.33 58.02 12.2484 17641 2670 11490 FET MWD HOUR 0.24 66.14 1.17782 17641 2670 11490 GR MWD API 27.75 191.17 87.1892 17654 2656.5 11483 ROP MWD FT/H 2.88 283.95 143.235 17676 2702.5 11540 First Reading For Entire File..........2656.5 Last Reading For Entire File...........11540 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/26 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name............~SLIB.002 • Service Sub Level Name... Version Number...........1.0.0 Date. of Generation.......06/06/26 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2656.5 5524.5 FET 2670..0 5517.0 RPX 2670.0 5517.0 RPS 2670.0 5517.0 RPM 2670.0 5517.0 RPD 2670.0 5517.0 ROP 2702.5 5571.0 LOG HEADER DATA DATE LOGGED: 13-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5571.0 TOP LOG INTERVAL (FT) 2702.0 BOTTOM LOG INTERVAL (FT) 5571.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 35.0 MAXIMUM ANGLE: 86.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 2693.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Fresh Water Gel 9.80 270.0 9.5 1200 8.8 1.350 74.0 .870 118.0 3.400 74.0 2.200 74.0 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 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2656.5 5571 4113.75 5830 2656.5 5571 RPD MWD020 OHMM 0.21 2000 16.4345 5695 2670 5517 RPM MWD020 OHMM 0.21 1780.2 8.76455 5695 2670 5517 RPS MWD020 OHMM 0.2 22.2 4.995 5695 2670 5517 RPX MWD020 OHMM 0.33 17.83 4.7474 5695 2670 5517 FET MWD020 HOUR 0.24 66.14 1.31136 5695 2670 5517 GR MWD020 API 49.24 191.17 111.377 5737 2656.5 5524.5 ROP MWD020 FT/H 3.96 283.95 171.112 5738 2702.5 5571 First Reading For Entire File..........2656.5 Last Reading For Entire File...........5571 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/26 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.......06/06/26 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5517.5 11490.0 RPD 5517.5 11490.0 RPM 5517.5 11490.0 FET 5517.5 11490.0 RPS 5517.5 11490.0 GR 5525.0 11483.0 ROP 5571.5 11540.0 LOG HEADER DATA DATE LOGGED: 18-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11540.0 TOP LOG INTERVAL (FT) 5571.0 BOTTOM LOG INTERVAL (FT) 11540.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.6 MAXIMUM ANGLE: 95.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT): 5560.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 9.90 MUD VISCOSITY (S) 64.0 MUD PH: .0 MUD CHLORIDES (PPM): 65000 FLUID LOSS (C3) 1.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 134.6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification R~rd • 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 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5517.5 11540 8528.75 12046 5517.5 11540 RPD MWD030 OHMM 0.22 2000 26.3276 11946 5517.5 11490 RPM MWD030 OHMM 0.64 2000 24.1602 11946 5517.5 11490 RPS MWD030 OHMM 2.77 17 11.68 17.1903 11946 5517.5 11490 RPX MWD030 OHMM 1.82 58.02 15.8244 11946 5517.5 11490 FET MWD030 HOUR 0.25 55.13 1.11415 11946 5517.5 11490 GR MWD030 API 27.75 112.6 75.5447 11917 5525 11483 ROP MWD030 FT/H 2.88 2 47.51 129.835 11938 5571.5 11540 First Reading For Entire File..........5517.5 Last Reading For Entire File...........11540 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/26 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/26 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date .....................06/06/26 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Library. Scientific Technical Services Next Reel Name..........~KNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File