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208-025
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, May 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD3-118 COLVILLE RIV UNIT CD3-118 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/22/2024 CD3-118 50-103-20570-00-00 208-025-0 W SPT 6593 2080250 4000 2328 2334 2334 2334 387 402 402 402 REQVAR P Brian Bixby 4/14/2024 MITIA to MAIP as per AIO 18E.002 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD3-118 Inspection Date: Tubing OA Packer Depth 680 4200 4150 4140IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240415154534 BBL Pumped:5.1 BBL Returned:4.8 Wednesday, May 22, 2024 Page 1 of 1 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-118 (PTD 208-025) Report of IA pressure increase above operating limits Date:Monday, May 6, 2024 11:50:46 AM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Monday, May 6, 2024 11:18 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD3-118 (PTD 208-025) Report of IA pressure increase above operating limits Chris, CD3-118 has completed well work and the 30-day monitor on water will end on May 9,2024. The well is stable. The next step is to wag the well to gas for a 30-day monitor. CPAI will follow up with proper notifications after the 30-day monitor. Let me know if you have any questions or disagree with this plan. Kate From: WNS Integrity Sent: Wednesday, January 24, 2024 11:00 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD3-118 (PTD 208-025) Report of IA pressure increase above operating limits Hi Chris, Operations has decided to change the plan of this well. CPAI is going to WAG the well to water and bring it online to help fluid pack the well. Once weather and equipment availability allow, the well will be secured and circ’d out. As a reminder, this well is waivered (AIO 18E.002) for water alternating gas (WAG) injection with a known tubing by inner annulus (TxIA) pressure communication. Please let me know if you disagree or have any questions with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Monday, January 15, 2024 8:43 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; WNS Integrity <WNSIntegrity@conocophillips.com> Subject: CRU CD3-118 (PTD 208-025) Report of IA pressure increase above operating limits Chris, CRU CD3-118 (PTD 208-025) (AIO 18E. 002) Operations reported the IA pressure exceeded MAOP on 1/12/24. The well was remotely shut in the same day. Operations was able to bleed the IA pressure on 1/14/24. The current T/I/O= 3518/1728/372. The immediate plan is for Slickline to secure the well as soon as possible, taking into account recent bad weather conditions and the need for significant snow removal prior work execution. Any proper paperwork for continued injection or corrective action will be submitted once a plan forward has been determined. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 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. You don't often get email from wnsintegrity@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-118 (PTD 208-025) Report of IA pressure increase above operating limits Date:Thursday, January 25, 2024 2:20:23 PM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Wednesday, January 24, 2024 11:00 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD3-118 (PTD 208-025) Report of IA pressure increase above operating limits Hi Chris, Operations has decided to change the plan of this well. CPAI is going to WAG the well to water and bring it online to help fluid pack the well. Once weather and equipment availability allow, the well will be secured and circ’d out. As a reminder, this well is waivered (AIO 18E.002) for water alternating gas (WAG) injection with a known tubing by inner annulus (TxIA) pressure communication. Please let me know if you disagree or have any questions with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Monday, January 15, 2024 8:43 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; WNS Integrity <WNSIntegrity@conocophillips.com> Subject: CRU CD3-118 (PTD 208-025) Report of IA pressure increase above operating limits Chris, CRU CD3-118 (PTD 208-025) (AIO 18E. 002) Operations reported the IA pressure exceeded MAOP on 1/12/24. The well was remotely shut in the same day. Operations was able to bleed the IA pressure on 1/14/24. The current T/I/O= 3518/1728/372. The immediate plan is for Slickline to secure the well as soon as possible, taking into account recent bad weather conditions and the need for significant snow removal prior work execution. Any proper paperwork for continued injection or corrective action will be submitted once a plan forward has been determined. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-118 (PTD 208-025) Report of IA pressure increase above operating limits Date:Tuesday, January 16, 2024 9:18:15 AM Attachments:AnnComm Surveillance TIO for CD3-118.pdf Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Monday, January 15, 2024 8:43 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; WNS Integrity <WNSIntegrity@conocophillips.com> Subject: CRU CD3-118 (PTD 208-025) Report of IA pressure increase above operating limits Chris, CRU CD3-118 (PTD 208-025) (AIO 18E. 002) Operations reported the IA pressure exceeded MAOP on 1/12/24. The well was remotely shut in the same day. Operations was able to bleed the IA pressure on 1/14/24. The current T/I/O= 3518/1728/372. The immediate plan is for Slickline to secure the well as soon as possible, taking into account recent bad weather conditions and the need for significant snow removal prior work execution. Any proper paperwork for continued injection or corrective action will be submitted once a plan forward has been determined. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 CD3-118 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD3-118 2024-01-14 2880 1600 -1280 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CD3-118 triplwj Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: RESET INJ VALVE CD3-118 1/29/2019 boehmbh Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 7/22/2008 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 34" 16 15.25 36.0 114.0 114.0 62.50 H-40 Welded SURFACE 9 5/8 8.83 36.3 3,244.0 2,489.0 40.00 L-80 BTC-M INTERMEDIATE 7 6.28 33.9 13,694.0 6,943.0 26.00 L-80 MBTC OPEN HOLE 6 1/8 6.15 13,694.0 21,228.0 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.3 Set Depth … 13,131.7 Set Depth … 6,861.4 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.3 31.3 0.00 HANGER 10.850 FMC TUBING HANGER FMC 4.500 137.2 137.2 0.44 XO Reducing 4.500 XO REDUCED TUBING 4.5 TO 3.5 3.500 2,255.6 2,014.7 52.81 SAFETY VLV 5.170 CAMCO TRMAXX 5-EE W/2.813 PROFILE (FLAPPER LOCKED OUT 1/19/2009) CAMCO TRMAX X-5EE 2.812 5,238.9 3,399.4 62.86 GAS LIFT 5.390 Gas Lift Mandrel w/Dummy CAMCO KBG-2 2.920 10,054.8 5,610.1 62.77 GAS LIFT 5.390 Gas Lift Mandrel w/Dummy CAMCO KBG-2 2.920 12,146.5 6,557.2 66.06 GAS LIFT 5.390 Gas Lift Mandrel w/SOV CAMCO KBG-2 2.920 12,194.4 6,576.5 66.50 NIPPLE 3.875 HES X NIPPLE HES X 2.813 12,236.3 6,593.1 66.90 PACKER 5.937 BAKER PREMIER PACKER BAKER PREMIE R 2.870 12,352.0 6,637.3 68.10 SLEEVE-C 4.270 BAKER CMD SLIDING SLEEVE W/2.813 X PROFILE (CLOSED 1/12/2009) BAKER CMD 2.813 12,936.8 6,820.1 75.54 BLAST RING 4.500 PUP W/6' BLAST RING PUP 2.992 12,946.1 6,822.4 75.71 BLAST RING 4.500 TUBING W/30' BLAST RING T&C Upset 2.992 13,053.1 6,846.6 78.33 PACKER 5.980 BAKER PREMIER PACKER BAKER PREMIE R 2.870 13,100.7 6,855.8 79.27 NIPPLE 4.250 HES XN NIPPLE W/NO GO HES XN 2.750 13,131.2 6,861.4 79.69 WLEG 4.120 BAKER WIRELINE ENTRY GUIDE BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,255.6 2,014.7 52.81 VALVE 3.5" A-1 INJECTION VALVE (S/N: HABS-0224) 1/29/2019 1.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 5,238.9 3,399.4 62.86 1 Gas Lift DMY BK 1 0.0 1/22/2009 0.000 10,054.8 5,610.1 62.77 2 Gas Lift DMY BK 1 0.0 1/22/2009 0.000 12,146.5 6,557.2 66.06 3 Gas Lift DMY BK 1 0.0 1/22/2009 0.000 12,292.9 6,615.0 67.51 4 INJ CV REK 1 1/2 0.0 12/18/2012 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 13,694.0 6,943.0 85.32 OPEN HOLE 6.125 6.151 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 12,950.0 12,970.0 6,823.4 6,828.2 KUPC, CD3-118 3/26/2008 6.0 IPERF 3.5" OMEGA-WL PJ 3500 DEVIATED, CD3-118, 6/13/2023 2:12:17 PM Vertical schematic (actual) OPEN HOLE; 13,694.0-21,228.0 INTERMEDIATE; 34.0-13,694.0 PACKER; 13,053.1 IPERF; 12,950.0-12,970.0 INJECTION; 12,292.9 PACKER; 12,236.3 GAS LIFT; 12,146.5 GAS LIFT; 10,054.8 GAS LIFT; 5,238.9 SURFACE; 36.3-3,244.0 VALVE; 2,255.6 SAFETY VLV; 2,255.6 CONDUCTOR Insulated 34"; 36.0-114.0 WNS INJ KB-Grd (ft) 36.10 RR Date 3/29/2008 Other Elev… CD3-118 ... TD Act Btm (ftKB) 21,228.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032057000 Wellbore Status INJ Max Angle & MD Incl (°) 93.70 MD (ftKB) 14,349.87 WELLNAME WELLBORECD3-118 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-118 (PTD#208-025-10) IA Pressurization Date:Tuesday, February 22, 2022 9:34:21 AM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Friday, February 18, 2022 4:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD3-118 (PTD#208-025-10) IA Pressurization Chris— Per our conversation this afternoon, we have revised our plan on CRU well CD3-118 (PTD#208-025- 0). We would like to put this well on a 30-day monitoring period on gas injection and perform the DHD diagnostics while on gas injection. We will update you at the conclusion of this monitoring period, or if the conditions of the well change during the monitoring period. Please let me know if you have any questions or disagree with the plan. Travis From: Smith, Travis T Sent: Tuesday, February 15, 2022 5:08 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-118 (PTD#208-025-10) IA Pressurization Chris— CRU well CD3-118 (PTD#208-025-0) has exhibited TxIA communication while on MI injection. Our intent is to WAG the well back to water injection for a 30-day monitoring period as soon as practical. While on water injection service we will conduct standard DHD diagnostics. Based on these results we will propose a path forward to either waiver the well for water-only injection service or attempt a repair to return the well to WAG injection service. A 90-day TIO and well schematic are attached. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-118 (PTD#208-025) IA Pressurization Date:Wednesday, February 16, 2022 9:38:36 AM Attachments:CD3-118.pdf CD3-118 90-day TIO.pdf From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, February 15, 2022 5:08 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-118 (PTD#208-025-10) IA Pressurization Chris— CRU well CD3-118 (PTD#208-025) has exhibited TxIA communication while on MI injection. Our intent is to WAG the well back to water injection for a 30-day monitoring period as soon as practical. While on water injection service we will conduct standard DHD diagnostics. Based on these results we will propose a path forward to either waiver the well for water-only injection service or attempt a repair to return the well to WAG injection service. A 90-day TIO and well schematic are attached. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com Annular Communication Surveillance 17-Nov-2021Well Name:CD3-118 Start Date:17-Nov-2021 15-Feb-2022Days:90 End Date:15-Feb-2022 50 60 70 80 90 100 110 120 130 140 150 0 500 1000 1500 2000 2500 3000 3500 4000 4500 17-Nov-2120-Nov-2123-Nov-2126-Nov-2129-Nov-212-Dec-215-Dec-218-Dec-2111-Dec-2114-Dec-2117-Dec-2120-Dec-2123-Dec-2126-Dec-2129-Dec-211-Jan-224-Jan-227-Jan-2210-Jan-2213-Jan-2216-Jan-2219-Jan-2222-Jan-2225-Jan-2228-Jan-2231-Jan-223-Feb-226-Feb-229-Feb-2212-Feb-2215-Feb-22Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 2000 4000 6000 8000 10000 12000 17-Nov-2120-Nov-2123-Nov-2126-Nov-2129-Nov-212-Dec-215-Dec-218-Dec-2111-Dec-2114-Dec-2117-Dec-2120-Dec-2123-Dec-2126-Dec-2129-Dec-211-Jan-224-Jan-227-Jan-2210-Jan-2213-Jan-2216-Jan-2219-Jan-2222-Jan-2225-Jan-2228-Jan-2231-Jan-223-Feb-226-Feb-229-Feb-2212-Feb-22Injection 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: CD3-118 triplwj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: RESET INJ VALVE 1/29/2019 CD3-118 boehmbh Casing Strings Casing Description CONDUCTOR Insulated 34" OD (in) 16 ID (in) 15.25 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) 9 5/8 ID (in) 8.83 Top (ftKB) 36.3 Set Depth (ftKB) 3,244.0 Set Depth (TVD) … 2,489.0 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC-M Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 33.9 Set Depth (ftKB) 13,694.0 Set Depth (TVD) … 6,943.0 Wt/Len (l… 26.00 Grade L-80 Top Thread MBTC Casing Description OPEN HOLE OD (in) 6 1/8 ID (in) 6.15 Top (ftKB) 13,694.0 Set Depth (ftKB) 21,228.0 Set Depth (TVD) …Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.3 Set Depth (ft… 13,131.7 Set Depth (TVD) (… 6,861.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.3 31.3 0.00 HANGER FMC TUBING HANGER 4.500 137.2 137.2 0.44 XO Reducing XO REDUCED TUBING 4.5 TO 3.5 3.500 2,255.6 2,014.7 52.81 SAFETY VLV CAMCO TRMAXX 5-EE W/2.813 PROFILE (FLAPPER LOCKED OUT 1/19/2009) 2.812 12,194.4 6,576.5 66.50 NIPPLE HES X NIPPLE 2.813 12,236.3 6,593.1 66.90 PACKER BAKER PREMIER PACKER 2.870 12,352.0 6,637.3 68.10 SLEEVE-C BAKER CMD SLIDING SLEEVE W/2.813 X PROFILE (CLOSED 1/12/2009) 2.813 12,936.8 6,820.1 75.54 BLAST RING PUP W/6' BLAST RING PUP 2.992 12,946.1 6,822.4 75.71 BLAST RING TUBING W/30' BLAST RING 2.992 13,053.1 6,846.6 78.33 PACKER BAKER PREMIER PACKER 2.870 13,100.7 6,855.8 79.27 NIPPLE HES XN NIPPLE W/NO GO 2.750 13,131.2 6,861.4 79.69 WLEG BAKER WIRELINE ENTRY GUIDE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,255.6 2,014.7 52.81 VALVE 3.5" A-1 INJECTION VALVE (S/N: HABS- 0224) 1/29/2019 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 12,950.0 12,970.0 6,823.4 6,828.2 KUPC, CD3-118 3/26/2008 6.0 IPERF 3.5" OMEGA-WL PJ 3500 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 5,238.9 3,399.4 CAMCO KBG-2 1 Gas Lift DMY BK 0.000 0.0 1/22/2009 2 10,054.8 5,610.1 CAMCO KBG-2 1 Gas Lift DMY BK 0.000 0.0 1/22/2009 3 12,146.5 6,557.2 CAMCO KBG-2 1 Gas Lift DMY BK 0.000 0.0 1/22/2009 4 12,292.9 6,615.0 CAMCO MMGW 1 1/2 INJ CV REK 0.000 0.0 12/18/2012 Notes: General & Safety End Date Annotation 7/22/2008 NOTE: View Schematic w/ Alaska Schematic9.0 DEVIATED, CD3-118, 5/28/2020 4:16:55 PM Vertical schematic (actual) OPEN HOLE; 13,694.0-21,228.0 INTERMEDIATE; 34.0-13,694.0 WLEG; 13,131.2 NIPPLE; 13,100.7 PACKER; 13,053.1 BLAST RING; 12,946.1 IPERF; 12,950.0-12,970.0 BLAST RING; 12,936.8 SLEEVE-C; 12,352.0 INJECTION; 12,292.9 PACKER; 12,236.3 NIPPLE; 12,194.4 GAS LIFT; 12,146.5 GAS LIFT; 10,054.8 GAS LIFT; 5,238.9 SURFACE; 36.3-3,244.0 VALVE; 2,255.6 SAFETY VLV; 2,255.6 CONDUCTOR Insulated 34"; 36.0-114.0 HANGER; 31.3 WNS INJ KB-Grd (ft) 36.10 Rig Release Date 3/29/2008 CD3-118 ... TD Act Btm (ftKB) 21,228.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032057000 Wellbore Status INJ Max Angle & MD Incl (°) 93.70 MD (ftKB) 14,349.87 WELLNAME WELLBORECD3-118 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: P.I.Supervisor DATE: Tuesday,February 20,2018 Jim Rpelj Z Z7ll6 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD3-118 FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-118 Petroleum Inspector Src: Inspector Reviewed By: Y P.I.Supry J 62— NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-118 API Well Number 50-103-20570-00-00 Inspector Name: Lou Laubenstein Permit Number: 208-025-0 Inspection Date: 2/11/2018 Insp Num: mitLOL180212124555 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well-1 CD3-118 6593 Tubing2443 • 2443 - 2443 • 2443 PTD 2080250 Type Test sPT ITestD psi ypp 1648 jA 790 1900 - 1880 1880 - BBL Pumped: 7 0.6 BBL Returned: 0.6 ' OA 278 -1 281 281 -I 281 Interval4YRTST - TP/F P ,� Notes: SCANNED Tuesday,February 20,2018 Page 1 of 1 • ®r anizin (done) g g ^ Two-sided III Ilillllllll VIII ^ Rescan Needed ill IIIIIIIIII ill 111 RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ D /s/ Pro "ect Proofin I g II I II'I II I I III I I III BY: ~ Maria Date: ® ~s/ Scanning Preparation _,~ x 30 = BY: Maria Date: Production Scanning + =TOTAL PAGESQ (Count does not include cover sheet) /s/ Stage 1 Page Count from Scanned File: ~~ ~ (Count does include cover sheet) Page Count Matches Number in Scanni g Preparation: ~~YES _ BY: Maria Date: ~, g f O Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO /s/ ~~ NO I ~IIIIIIIIIIIIBIIIII I~eScanned BY: Maria Comments about this file: Date: Quality Checked 10/6/2005 Well History File Cover Page.doc • MEMORANDUM To: Jim Regg ~ ~ ~ 3~~~~p P.I. Supervisor FROM: JOhTI Cr1Sp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, March O1, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHII,LIPS ALASKA INC CD3-118 COLVILLE RIV FIORD CD3-118 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Jr~2' Comm Well Name: COLVILLE RIV FIORD CD3-118 API Well Number: 50-103-20570-00-00 Inspector Name: John Crisp Insp Num: mitJCr100227175541 Permit Number: 208-025-0 Inspection Date: 2/26/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We ~ CD3-118Type Inj. W TVD 6593 IA ~ -~- -- ~ ' ~ 1790 2567 ~ 2540 2537 2080250 T),peTCSt SPT ~ TeSt pSl 1648 OA ~ P.T.D ~ 376 381 _ 381 381 0 TUbing p~ P Int CVaI 4YRTST 2000 I 2050 2050 205 __ NOtes:.7 bbl pumped for test. Monday, March O1, 2010 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 21112010 Permit to Drill 2080250 Well Name/No. COLVILLE RIV FIORD CD3-118 Operator CONOCOPHILLIPS ALASKA INC MD 21228 TVD 6879 Completion Date 3/28/2008 Completion Status 1-OIL Current Status WAGIN API No. 50-103-20570-00-00 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/RES Well Log Information: Logl Electr Data Digital Dataset Samples No Directional Surv _Yes (data taken from Logs Portion of Master WeII Data Maint Log Log Run Interval OH / e...,~e uie.u~ .~,, es~.+ Conn CH Rar_aivPd Comments og Induction/Resistivity 2 Col 114 21228 Open 4/21/2008 MD DGR, BAT Bi-Modal BAT Cement, EWR, ALD, CTN fir' Rpt LIS Verification 3217 21228 Open 5/21/2008 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP ` ~~D C Lis 16288~duction/Resistivity 3217 21228 Open 5/21/2008 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP og Induction/Resistivity 25 Col 114 21228 Open 6/19/2008 MD ROP, DGR, EWR g Induction/Resistivity 25 Col 114 21228 Open 6/19/2008 TVD DGR, EWR ED C 16466~~ Induction/Resistivity 0 0 Open 6/19/2008 MD and TVD logs in PFS, EMF and CGM graphics :~D C Las og 16934"~Spinner _S~ S f~+^wP-v- BS 4916 4920 12238 12451 Case Open 9/23/2008 9/23/2008 Spin, Temp, Pres, GLS, MPL, Pres, GR, CCL, FCAP, ILS, Temp, Spin 11- Sep-2008 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments rl DATA SUBMITTAL COMPLIANCE REPORT 2/1/2010 Permit to Drill 2080250 Well Name/No. COLVILLE RIV FIORD CD3-118 Operator CONOCOPHILLIPS ALASKA INC MD 21228 TVD 6879 ADDITIONAL INFORMATION Well Cored? Y Chips Received? Y / N Analysis Y / N Received? Completion Date 3/28/2008 Completion Status 1-OIL Current Status WAGIN Daily History Received? ~ N Formation Tops API No. 50-103-20570-00-00 UIC Y Comments: Compliance Reviewed By: Date: t C~ ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Othef 0 convert to WAG Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 208-025 / ' 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20570-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 49.5' CD3-118 8. Property Designation: 10. Field/Pool(s): ADL 380092025526, 372105, 389725 Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 21228' feet true vertical 6879' feet Plugs (measured) Effective Depth measured 21228' feet Junk (measured) true vertical 6879' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 16" 114' 114' Surface 3208' 9-5/8" 3244' 2489' Production 13661' 7" 13694' 6943' RECEIVE[ Perforation depth: Measured depth: 12950'-12970', 13694'-21228' (openhole) JUN 1 6 2009 true vertical depth: 6823'-6828', 6943'-6879' Alaska Oil & Gas Cons. Commiscien Tubing (size, grade, and measured depth) 3.5", L-80, 13131' MD. AnChora~e ~ Packers &SSSV (type & measured depth) 2 Baker Premier pkrs @ 12236', 13053' Camco TRMAXX 5-EE SSSV @ 2256' 12. Stimulation or cement squeeze summary: ~~~~~, ` `~~ a ~~~ ®~ K~ Intervals treated (measured) not applicable ~~ ~ Treatment descriptions including volumes used and final pressure: ~~ 13. Representative Daily Average Prod uction or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation -- Subsequent to operation 7740 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^~ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-453 contact Jack Walker @ 266-6268 Printed Name Jack Walker Title Alpine Production Engineer Signature Phone: 265-6268 Date ~~ ~j~ P aced b h n Allsu Drake 263-4612 U Form 10-404 Revised 04/2006 ~ Submit Origi al Ortjy ~~ /~./~ CD3-118 Well Events Summary DATE SUMMARY 1/12/09 CLOSED CMD @ 12,352' RKB. WILL RETURN TO LOCK OUT TRDP. IN PROGRESS. 1/19/09 MEASURED BHP @ 12,300' RKB: 2454 PSI. LOCKED OUT TRDP @ 2255' RKB USING HYDRAULIC DEFORMATION TOOL (C/L STILL ISOLATED FROM TUBING). IN PROGRESS. 1/20/09 MADE MULTIPLE ATTEMPTS TO SET 2.81" XX PLUG IN CMD @ 12,353' RKB, NO SUCCESS. IN PROGRESS. 1/21/09 SET 2.81" XX PLUG IN CMD an 12,352' RKB, TEST 2.81" XX PLUG C~ 12352' RKB TO 3000 PSI GOOD TEST, PULLED 1" GLV @ 5239' RKB, LDFN JOB IN PROGRESS 1/22/09 PULLED 1" GLV @ 10055' RKB, PULLED 1" OV @ 12146' RKB, SET 1" DUMMY VLV @ 5239' RKB, SET 1" DUMMY VLV @ 10055' RKB, LRS PUMP 450 BBLS INHIBITED SEA WATER & 100 BBLS DIESEL DOWN TBG, U-TUBE TBG TO IA, SET 1" DUMMY V_LV @ 12146' RKB LDFN. JOB IN PROGRESS 1/23/09 PULLED 1.5" DUMMY VLV @ 12293' RKB, SET 1.5" SIDE POCKET GAUGE C~ 12293' RKB MIT TUBING TO 3000 PSI GOOD TEST, MIT IA TO 3000 PSI GOOD TEST, PULLED 2.81" XX PLUG @ 12352' RKB, SET 2.81" INJ VALVE W/ 1" BEAN @ 2255' RKB_(SER# HKS-235), WELL ON VAC UNABLE TO PREFORM CLOSURE TEST. JOB COMPLETE MOVE TO CD2-466 4/19/09 DRIFT TUBING TO A-1 INJ VALVE @ 2255' RKB TUBING CLEAR, JOB SUSPENDED MOVE TO CD2-59 4/25/09 PULLED 2.81 A-1 INJ VALVE @ 2256' RKB (SER# HKS-235), DRIFTED TUBING TO XN NIPPLE @ 13100' RKB W/ 2.79" GAUGE TUBING CLEAR, SET CAT STANDING VALVE IN XN NIPPLE @ 13100' RKB, JOB IN PROGRESS 4/26/09 PULLED 1.5" SIDE POCKET GAUGE FROM STA # 4 @ 12293' RKB, SET 1.5" DUMMY VALVE Cad 12293' RKB. PRESSURE TEST DUMMY VALVE GOOD TEST, PULLED CAT STANDING VALVE BEAN @ 2256' RKB (SER# HKS-235) GOOD CLOSURE TEST. JOB COMPLETE • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri16, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~. _ , n.~ APR ~ 2005 ~l~~~n Ov9 ~~~ ~nn~n Cn issi®n ~~a~~~:° a/ /• ~ ~ 4~ a ~~ C~~ ~ 1 Enclosed please fmd a spreadsheet with a list of wells from the Coville River Unit (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped Apri15~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, , MJ Loveland ConocoPhillips Well Integrity Projects Supervisor t. * 4 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) n~to Alpine Field 4/6/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD3-301 206-020 9" NA 9" NA 0.85 4/5/2009 CD3-302 206-010 5" NA 5" NA 0.43 4/5/2009 CD3-303 208-013 9" NA 9" NA 1.70 4/5/2009 CD3-305 208-193 8" NA 8" NA 0.85 4/5/2009 CD3-316A 208-011 26" NA 26" NA 8.93 4/5/2009 CD3-107 206-189 34" NA 34" NA 11.05 4/5/2009 CD3-108 205-033 10" NA 10" NA 1.26 4/5/2009 .CD3-109 205-059 9" NA 9" NA 2.13 4/5/2009 CD3-110 205-041 4" NA 4" NA 0.43 4/5/2009 CD3-111 206-030 5" NA 5" NA 0.85 4/5/2009 CD3-112 206-032 3" NA 3" NA 0.43 4/5/2009 CD3-113 207-004 14" NA 14" NA 1.28 4/5/2009 CD3-114 207-033 5" NA 5" NA 0.85 4/5/2009 CD3-115 209-006 8" NA 8" NA 1.28 4/5/2009 CD3-117 209-026 6" NA 6" NA 0.43 4/5/2009 CD3-118 208-025 8" NA 8" NA 0.85 4/5/2009 MEMORANDUM To: Jim Regg !_ 7 P.Y. Supervisor `-~ 3177109 FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, Mazch 17, 2009 SUBJECT: Mechanical Integrity Tests corrocori~.Lms aLasxa Il~rc cD3-118 COLVILLE RIV FIORD CD3-118 Src: Inspector NON-CONFIDENTIAL Reviewed B,yy, P.I. Suprv ~!s k-- Comm Well Name: COLVILLE RIV FIORD CD3-118 API Well Number: 50-103-20570-00-00 Inspector Name• Jeff Jones Insp Num: mitJJ090310064857 Permit Number: 208-025-0 Inspection Date: 3/7/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3-118 Type Inj. W TVD 6847 IA 1760 2700 2680 2680 P•.I.• 2080250 TypeTest SPT Test psi 1711.75 ., QA 340 400 368 366 Interval ~iT``~ P/F r - Tubing 2130 2130 2135 2135 NOtes • Mr. Alexander (CPAI Rep.) requested to use the well head mounted Rosemont digital gauge for the test but no calibration data was available for that • instrument so I requested a calibrated test gauge which he provided. Pump truck was rigged up to the opposite side of well with VR plug installed. Subsequently, the plug was removed. 1 BBL diesel pumped. 1 well inspected; no exceptions noted Tuesday, Mazch 17, 2009 Page 1 of 1 ~`L ~ ~~ ~~ SARAH PAL/N, GOVERNOR ~~~ ~~ ~ ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERRA~`IOP1T COMl-IISSIOl~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jack Walker Production Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-118 Sundry Number: 308-453 Dear Mr. Walker: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ Daniel T. Seamount, Jr. .,~ j1 Chair DATED this ~~day of December, 2008 Encl. (~ ,~ '~~. ~~ STATE OF ALASKA ~ ~~~~i~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~n nnr` ~~ ~Rn 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ '~ fo Change approved program Q Pull Tubing ^ Perforate New Pool ^ Re-enter S uspended Well ~-y~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ^ 208-025 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20570-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where 8. Well Name and Number: ownership or landownership changes: Spacing Exception Required? Y2S NO ^d CD3-118 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380092, 025526, 372105, 389725 RKB = 49.5' Colville River Field / Fiord Oil Pool 12. P RESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 21228' 6879 Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 3208' 9-5/8" 3244' PRODUCTION 13661' 7" 13694' Pertoration Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12950' -12970' & 13694' - 21228' 6823' - 6828' Kuparuk (openhole) & Nechelik 6943' - 6879' (openhole) 3.5" L-80 13131' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier Packer Packer = 12236' MD ~ -- Camco TRMAXX 5E SSSV SSSV = 2255' MD 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q • 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 15, 2009 Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: WAG Q ' GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker Printed Name Jack Walker Title: Production Engineer Signature ~ ~~1--~ Phone 265-6268 Date J S ~~ -'ZC>O`~1 Commission Use Only Sundry Number: Conditions of approval: Notity Commission so that a representative may witness ~ .% ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: '~.~~ APPROVED BY f 'L ~ I Approved by: COMMISSIONER THE COMMISSION Date: t Form 10-403 Revised 06/2006 ( 1~~~ ~ Submit in Duplicate ConocoPhillips December 15, 2008 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Colville River Field Well CD3-118 Conversion to WAG Service Dear Chairman Seamount: Jack Walker Western North Slope Development ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Phone: 907-265-6268 A sundry approval is requested to convert well CD3-118 (permit to drill 208-025) from Development class, Oil status to Service WAG. A 10-403 form for the CD3-118 conversion is attached in duplicate. I would be happy to answer any question regarding this sundry approval request. Sincerely, /~~~~ ~ Jack Walker Western North Slope Development ConocoPhillips Alaska, Inc. Attachments • CD3-118 Permit to Drill 208-025 API 50-103-20570-00 Application for Sundry Approval Description of Summary Proposal December 15, 2008 1. Shut in CD3-118 production. Close sliding sleeve to isolate Kuparuk interval. 2. Set up well for injection. a. Load IA with inhibited seawater. b. Replace GLV's with dummies. c. Lock out TRMAXX 5E SSSV and set Al injection valve SSSV. d. Complete mechanical integrity test. e. Convert surface lines from production to injection system. 3. Measure static pressure. 4. Put well (Nechelik interval) on injection. ~ ~- ~ ~--2-~ c~ ~ ~~ • ~~`--\ INNS CD3-118 • ~ ,~ ~~-C~~-~ 1`~C:iAriICAL INTEGRITY R~'ORT • - ~~UD v:--= - - C~a~'"o `~ Og£R ~ F~£L~ C:~ ~~- ~tZ,~ ~~~0~~ ~ :.G n~:.S~_.._ . - ~~~~~ _~ 15 h~L:s. NIIMB£R ~.~ ~j ~~~ ~tLL SAT = w:~~~ ~-g.?~--b~s~~ ';"~fl; _~Tn_ ~ 1~~~~n ~~s~15'_'w~ _____, Cas i~ _~-Q ~= ~~l Shoe: I~~~~IMD (~~1~{ TVD; i~V: ?~ -____.._ _~:,e= . Shoe : '~3 '?'t,TD - ';'Gr . ?-~ ~..._~ •~ - `i ~ - I~ P ~ C iC 8~ Qi~"' ~ T'~3 C e t ~ ~ ` ole S_;.e ~~~~1 end ~ `~g Perks la~tSC~ `o ~~~~0~--~1 :..c ~ i.'r'..e~?~ i Cam.?. INT£GR?"TY - ? ±~.RT # ~ ~'~~~ ~lW ~ \~ ~Cl ~ - c~ ~ ~'~-~ r`_rii?u1L:S '-~'reSS ~'eS~: ~ i.5 I11I1 ; .,a iII1I2 Comments : ~~~-~ - OAS -~J'bz '~'CHA N1C~..:~. `+_NTEGR?'T~ -PART # 2 ~ ~~ ~ ~ ~ S - Cement Volt~es : A.mt. ~iner Csg y® ~y ~r~l i ; C~~ voI to cove= oe==5 ~~b . ~ S~3~'r~L'Z~T Cc~y~~ ~ \US heoret:ical I'7C ~ ~~~~ ~ ~~~.. ~1 ~ tom" ~, . , ~_ ~1 Cesieut Bona Lo Yes r No ~. "`~~~-®K F. ~ _ __ b' ~ ~ In AOGCC a.1.e - - C~L £valuation, gone abbove erfs ~j ~~~~~~~, '~ :~~~._ i~~~`° ~L G~ Vic, \c~~ ~ .. - Production i.og: 'ryae £valuation CON~LJS iOt~S ~ ~~ ?arm :1 - ~ - Part T2: ,~, l ~5 `t~~c-G: CJUWUL7 V~W~VV d DEPARTMENT OF NATURAL RESOURCES DIVISION OF DlL AND GAS November 24, 2008 Dora I. Soria Senior Landman ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 PAL,N, G®VE~N®~ 550 WEST 7TH AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 FAX.• (907) 269-8938 Subject: Request to Extend Well Tract operations -CD3-118 Kuparuk Well Dear Ms. Soria: By letter, dated November 18, 2008, ConocoPhillips Alaska, Inc. (ConocoPhillips) requested that the Division of Oil and Gas' March 25, 2008 tract operations approval to produce the shallower Kuparuk Sand interval within the CD3-118 wellbore be amended to allow an additional three-month and four day period, until February 28, 2009, to conduct further well testing and operations. In addition to the information provided with the extension request letter, ConocoPhillips provided a status report of the activities conducted under the initial eight-month CD3-118 Kuparuk interval Tract Operation. I approve the extension request subject to the following terms and conditions: 1) This approval is for a period of three-months and four days, that is, until February 28, 2009. At the end of the tract operation extension period, ConocoPhillips shall provide a status report of the activities conducted under the CD3-118 Kuparuk interval Tract Operation and outline the plans forward for the Kuparuk Formation in the area. 2) All CD3-118 Kuparuk interval produced fluids shall be allocated to CRU Tract 91 (ADL 25526), and Accounting Unit Code "CR17" is assigned to the Kuparuk interval fluids allocated to the CD3-118 Tract Operation. The Nechelik interval produced fluids shall be allocated to the Fiord Nechelik Participating Area. ConocoPhillips, as the CRU Operator, shall separately account for the Kuparuk production allocated to CD3-118 on the monthly CRU production report. 3) Finally, this approval is only for the general CD3-118 Kuparuk Tract Operation extension plan. Specific on-site operations may require additional approvals. Sincere y, {{e 'n R. Banks Acting Director "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans. " ~~LL LAG '~ ~~,411/~/1~~4L I~. ProActive Diagnostic Services, Inc. To: State of Alaska - AOGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907J 793-1225 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 following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) 2J Gas Lift Survey 11 Sep~08 C03-118 Mylar Film / BL / E~ 50-103-20570-00 ~~~~(~S ~ ~~~3C/ U C~(e~se d~ ~~~~ iNl~r lci~ ~ ~ ~' SEP t~, ~~ 2008 r~ fi~ Signed Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-mA1L : pdsanchararl_eCa~memorylaq.cam WEBSITE : www.memotyloa cam C:\DocumenLs and Settit~gs\Uwner\Desktop\Transmit Conoco.doc . ~ Page 1 of 1 Maunder, Thomas E {DOA) From: Maunder, Thomas E (DOA) Sent: Sunday, July 20, 2008 1:23 PM 70: 'Noel, Brian'; Chambers, Mark A Subject: FW:208-025_CD3-118 407.pdf Attachments: 208-025_CD3-118 407.pdf Another one. From: Maunder, Thomas E (DOA) Sent: Sunday, July 20, 2008 1:21 PM To: Allsup-Drake, Sharon K Cc: 'Chip Alvord'; Liz Galiunas Subject: 208-025_CD3-118_407. pdf Sharon, et al, I am in catching up and reviewing the 407 for this well. 1 have attached a copy of page 1 and the wellbore drawing. It appears that the PBTD entered is not correct. The depth entered is the 7" casing shoe and the completed interval for the well is the 6-118" open hole from the 7" shoe to TD and the (presently isolated) Fiord-Kuparuk pertorated interval that was noted on the the 407. 1 have made hand corrections on the 407, so there is no need to send in a new one. I have also included the wellbore drawing. The drawing seems to be incomplete since there is no indication of the 7534' of 6-1/8" hole drilled below the 7" shoe and open to production. Please let me know if you agree with this determinations. If corrections are made to the drawing, please submit a new drawing. Email is fine. As I noted in a prior message, I will check reports as I can in an attempt to find out if other 407s have been submitted similarly, however it may be appropriate to confirm that there aren't other reports out there with similar errors. Call or message with any questions. Tom Maunder, PE AOGCC 7/20/2008 ConocoPhillips Alaska INC Alaska Oil and Gas Conservation Commission Monthly Production Report Form: 10-405 Field Name: Colville River Unit -Development Operator Name: 158068 ConocoPhillips Alaska, Inc. Production Month: May-08 Prd Prod TBG Press Daily Daily Daily Total Total Well Number API Number CMP TYP Field Code Mth Days Average OIL Water Gas Total Oil Water Gas CR13 50-103-20570-00 1 120120 1 20 253 1028 0 634 20,552 0 12,689 • ..__.-..~ ~ CD3 118 WNS - ~ , ~ p~s I ~1 S ~t)t1C3~i~ , 'Well Attributes Max Angle 8 MD l TD 1 p irl t f~GSil:i } _ ~ t '' Wellbore APVUWI Field Name __ Well Status Intl (°( MD (ftKB) Act Btm (fl KB) 9370 1434987 209650 HANGER. 31 CONUJCTOR lo~ela,ed, - 36 114 %O TUBING, -. --.. 137 SSSV. 2,256 VALVE, 2,256 suRFACE,- ___. 36-3.244 GAS LIFT, _ _ 5,239 GAS LIFT, 10,055 GAS LIFT, 12,146 JIPPLE, 12,194 PACKER, 12 236 INJECTION, 12 29's SLEEVE-C, 12,352 BLAST RINGS, __ 12.937 IPERF, 12950-12,970 BLAST RINGS, \.. 12.946 13.101 -- ---- WLEG. 13,131 50703205700_0 _ (FIORD NECHELIK INJ , Comment H2S (ppm) Date Annotalion End Date KB-Grd (H) Rig R lease Date I SSSV TRDP Last WO: I 36 10 3!29/2008 Annotat on (Depth (flK8) (End Oats (Annotation Entl Date Last Tag: Rev Reason' GLV C/O, RESEI INJ VLV I 4127/2009 Casin Strin s Casing Description String O._ String ID ... CONDUCTOR i6 75250 Top (ftKB) 360 Set Depth ((_. 114.0 Set Depth (ND) ... String Wt... 174.0 62.50 String ...' H~0 String Top Thrd Weltletl Insulatetl (Casing Description String 0... String ID ... 3 R A Top (ftKB) Set Depth (f... U Sat Depth (ND) ...String Wt... D Str ng ... L 80 String Top Thrd BTC-M D ... Description Str ng O._ I~Str ng G s g INTERMEDIATE 7 6.276 _I Tubin Strin s Top (itK6) 33.9 Set Dep11h (f... 13,694.0 Wt... Set Deplh (ND) .. (Str ng 6,943.0 2600 Str ng L80 String Top Thrd MBTC Tubin Descn [ion Strin 0... Strin ID ... ComGletion Detalls 1 z 2.992 op (ftKB) Set D pth (f Set Depth (ND) . (Siring Wf... Str g String TopThM g p g g 31 3 13 131 7 6.561 S I 9 30 L 80 P _ - - __ _ Top Depihl '. ~' (ND) lop Intl ' Item Descnpuon comment ID (inj (flK8) (") I To P 31 3 31 3 0.04 HANGER FMC TUBING HANGER 4.500 2,255.6 2,074. 6 52.81 SSSV CAMCO TRMAXX 5-EE W/2.813 PROFILE (FLAPPER LOCKED OUT 2 812 1/7912009) 12,194.4 -- - - 6,576.4 -- ~ 66.46 1I NIPPLE HES X NIPPLE - --~ _-- __- 2.813 12,236.3 6,593.1 66.90 PACKER BAKER PREMIER PACKER 2 870 72,352.0 6,636.7 67.77 SLEEVE-C BAKER CMD SLIDING SLEEVE W/2.813 X PROFILE (CLOSED 2.813 1/72!2009) 12,936.9 6,819.5 75.151 6LAST RINGS PUP W/6' BLAST RINGS 2.992 12,946.1 6,822.0 75 40 BLAST RINGS TUBING Wl30' BLAST RINGS 2992 13,053.1 6,846 6 78.fi2 PACKER BAKER PREMIER PACKER 2870 13,100. /. 6,856.1 80.03 NIPPLE HES XN NIPPLE W/NO GO 2.750 __ 6861.5' 8009. WLEG i 13,1312 (BAKER WIRELINE ENTRY GUIDE 3.000 1 Wireline retrievable Other In Ho I um s, fish, etc plugs valves P B 1 -- - -- ~ P h , , _ -, - (fVD) Top Intl TOp (ftKB) (ftKB( (`) Description 2.256 2,014.61 52.81 VALVE 1 Comment Run Dat 2/81" INJ VALVE w/1" BEAN (SERt! HKS 235) 4/26/2009 10(inJ- 1 000 tions & Slots PerFor a _ _ _ Shot p ( ) To ftKB 12,950 Top (TVD) Btm (ftKB)., (ftKB) 72,970' 6,823.1 eim (TVDj (ftKB) Zone 6,828.2 1 Dens Date '. (sh... Type '~~ Comment _ _ ,3126/2008 6.0'IPERF 35"OMEGA-WL PJ 3500 Notes: General & Safet End Date Annotation _ - _ 7/22/2008 . NOTE: VIEW SCHEMATIC w/9.0 v~Q2~ Po~Ck~~ `~~ ~~ D etails Mandrel _. _ __ ._ _ Top Depth Top I PoR (TVD) Intl OD Valve Latch Size TRO Run Sin Top (ftKB) (flK8) (°) Make Modal (in) Serv Type Type (in) (psi) Run Date Com... 11 5 238.9, 3,399 4 62.86 CAMCO KBG-2 1 Gas Lift DMY BK 0.000 0.0 1!22/2009 2 10,054.8 5,610.4 62 97 CAMCO KBG-2 1 Gas Lift DMY BK 0.000 0 0 7/22/2009 3 12,146.5 6,556.6 65.94 CAMCOKBG-2 1 Gas Lift DMY BK 0.000 0.0 1/22/2009 __ _ ._ I 4 12,292.9 6,615.0 67.51 iCAMCO MMGW 7 1/2 INJ DMY BK 0 OOO_- 0 0 4/26/2009 34-13,694 ~- -~ T0. 20.965 To: State of Alaska WELL L,OG TRANSMITTAL, Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-118 CD3-118 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-103-20570-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-103-20570-00 Digital Log Images: 50-103-20570-00 June 11, 2008 AK-MW-5700035 1 Color Logs 1 Color Logs 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: _. ~ . . 1 ~; i ~ / Signed: f~ ~~ _- '~ Regarding 4 year state witnesse~ITIA's on CD3 pad • 1 Regg, James B DOA ~ ~ ~,~1~ From: Regg, James B (DOA) ~~ Sent: Wednesday, June 10, 2009 12:51 PM To: 'NSK Problem Well Supv' Cc: Fleckenstein, Robert J (DOA) Subject: RE: Regarding 4 year state witnessed MITIA's on CD3 pad ~i (e :__---- ~'~ Zt} 5 - X41 ~~~ _ czS ,. 2c~6 -- c~ t c: ~u fa v c)~ 1 ?.o r~ -- i 4 '~ Your request to defer MITs at Colville River Unit CD3 pad until February 2010 is approved. The agreement to test in summer was driven by weather considerations and efficiency at CPAI's request. Testing the below listed wells in February 2010 will still accomplish the requirement to test at least every 4 years. We will make the necessary changes in our database to reflect a new due date of February 28. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, June 09, 2009 2:28 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Maunder, Thomas E (DOA) Subject: Regarding 4 year state witnessed MITIA's on CD3 pad Jim, By prior agreement with the Commission, Alpine CD3 pad is due for 4 year state witnessed MITIA's in July of 2009. Due to the remote location of that pad, the only available way to perform the MIT's during July would be to use a small triplex pump. The small triplex pumps have a 3 bbl capacity of fluid on board. With 8 wells to test on that pad, that would require to refill the triplex tank several times during the testing, possibly extending the testing time from 1 day to 2 or even 3 days, pending diesel availability. ConocoPhillips requests the testing cycle of CD3 to be deferred until February of 2010 when the pad is accessible with a larger pump by ice road. In reviewing our records of test dates, CD3-108 (PTD 205-033) has the oldest test date of 09-29-06. The other wells have more recent tests than that date (see table below). All of the wells will still be in compliance in February. February would become the new test month for CD3 and 2010 would be the start of the 4 year cycle. CD3-110 (PTD 205-041) last tested on 01/12/07 - ~~Ce `"`~~~ `~ iZ~z~"~ CD3-112 (PTD 206-032) last tested on 04/28/07 ~ ~~~ "-'~~~~s ~~~~~' CD3-114 (PTD 207-033) last tested on 04/02/08 - f~CC w~-less 4(ZJ z ~~jCD3-118 (PTD 208-025) last tested on 03/07/09 - f~cxti-cc ~.;~ss 3~~~ze~~R CD3-302 (PTD 206-010) last tested on 07/19/07 _ ~~C w;ir¢~s ~~t~ zc~ ,~ 6I SDI ~~ CD3-316A (PTD 208-011) lasttested on 05/16/08 _. /~~;~~ ~,-1-~,e~s 5~~r~,~~y 1 CD3-305 (PTD 208-193) tentatively scheduled to have initial witnessed test on 06/13/09. Please let me know if you have any questions and if this is acceptable. Brent Rogers/Martin Walters 6 c~~-111 - ~~ 6/10/2009 Regarding 4 year state witnesse~ITIA's on CD3 pad • Page 2 of 2 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 6/10/2009 CRU CD3-110 PTD 205-041 6/9/2009 TIO Pressures CHOKE FTP FTT~ i,~ oaP TIIIO Plot -CD3-110 200 2500 ....................................................................................................................................................... 150 2000 ....................................................................................................................................................... a E o~ ~ 1500 .................................................. 100 ~, ~ _~- ~.._~ -~~ti ,~ , o '4 ~i t v 1000 ...................................................................................................................................................... _. - _ _ 50 500 ........................................... .............................................................. 0 0 01-Apr-09 01-May-09 01-Jun-09 Date L~ WELL LOG TRANSMITTAL To: State of Alaska May 16, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Data: CD3-118 AK-MW-5700035 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20570-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. AnchArag~,: Alaskam99~~18 _~ .~a Date: Signed: ~~-~~ ~~~ 2 ~ ~ ConocoPhillips April 22, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD3-118 Dear Commissioner: G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ~~~~~ M ~® APR 2 3 20p8 Alaska Oil 8 Gas Cans, Commission ~.,..._~. Anchorage Per the request from AOGCC, ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the Fiord well CD3-118. 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 STATE OF ALASKA ~ APR 2 3 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION a ~ G S. Commissiptl WELL COMPLETION OR RECOMPLETION REPO~~`A~I 1a. Well Status: Oil ^ • Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: March 28, 2008 12. Permit to Drill Number: 208-025 / ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 26, 2008 13. API Number: 50-103-20570-00 4a. Location of Well (Governmental Section): Surface: 3978' FNL, 1010' FEL, Sec. 5, T12N, RSE, UM 7. Date TD Reached: March 23, 2008 14. Well Name and Number: CD3-118 Top of Productive Horizon: 570' FNL, 1255' FEL, Sec. 12, T12N, R4E, UM 8. KB (ft above MSL): 49.5' RKB Ground (ft MSL): 12.8' AMSL 15. Field/Pool(s): Colville River Field Total Depth: 577' FSL, 2127' FEL, Sec. 35, T13N, R4E, UM ,}~ 9. Plug Back Depth (MD + ND): ~~~C }~ 4' MD / ' ND l Fiord Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388033 , y- 6003798 Zone- 4 10. Total epth (MD + ND): 21228' MD / 6879' ND ~ 6. Property Designation: ~ , ~vt~7 ,l.~vr~ 38oos2, 025526, 372105 TPI: x- 377712 y- .6002088 Zone- 4 Total Depth: x- 373779 ~ - 6008582 Zone- 4 11. SSSV Depth (MD + ND): 2255' MD / 2014' TVD 17. Land Use Permit: ALK 380077 ~ `i 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1249' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE NTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEME PULLED 16" 62.5# H-40 36' 114' 36' 114' 24" Portland Type III 9-5/8" 40# L-80 36' 3244' 36' 2489; 12.25" 489 sx ASLite, 234 sx Class G 7" 26# L-80 36' 13694' 36' 6943' 8.75" 40o sx Class G, 195 sx Class G 23. Open to production or injection? Yes / No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 13131' 12236', 13053' 12950' - 12970' MD 6823' - 6828' TVD 6 spf ~~~ ,~~~ . ~\ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 1'~G~1'-t' ~`~",a$ ~~ ~ ^ `~ (i"+ 0~ ft.`\ r „ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~ ~ , fJ ` `V) rOE1~"'`3 - So4sRlfir '!v~ . none 28. PRODUCTION TEST Date First Production April 11, 2008 Method of Operation (Flowing, gas lift, etc.) gas lift oil producer Date of Test 4/19/2008 Hours Tested 6 hrs Production for Test Period -> OIL-BBL 924 GAS-MCF 544 WATER-BBL 3 CHOKE SIZE 100% GAS-OIL RATIO 742 Flow Tubing press. 245 psi Casing Pressure 1491 Calculated 24-Hour Rate -> OIL-BBL 3396 • GAS-MCF 2519 WATER-BBL 11 OIL GRAVITY -API (corn) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes No / • If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. t ~~V° "1.;~ C901~ J`'~¢ 'Z~~7 3 ~ tJA'T~ NONE / p ~R /z.a `j •O ~~ Form 10-407 Revised 2/2007 ~ ~ I G I ~! A L CONTINUED ON REVERSE SIDE ~ ~-~ /r ~, ~ "G, Jv ~/Lf~~' n 28. GEOLOGIC MARKERS (List all formations and ~ rkers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes 0 No . If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefry summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1268' 1249' ' needed, and submit detailed test information per 20 AAC 25.071. C-30 3245' 2490' C-20 4073' 2858' K-3 6219' 3851' K-2 6593' 4020' Nanuq 10499' 5816' K-1 12649' 6739' Kuparuk C 12942' 6821' Nuiqsut 12974' 6829' Nechelik 13555' 6928' N/A Formation at total depth: Nechelik ' 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: Liz Galiunas @ 265-6247 Printed Name hi Alvord Title: Drilling Team Leader Signature Phone -ZG5_ ~ ~ Zo Date gI2.Z~ O 8 INSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~t~p~oP~iltip~ Al;~~k~~ ~~. TUBING (113-13131, OD:3.500, ID:2.992) PRODUCTION (33-13694, OD:7.000, wt:2s.oo) NIP ;12194-12195, OD:3.875) PACKER :12236-12237, OD:5.980) APL 501032057000 Well T e: SVC An le TS: de SSSV Type: TRDP Orig Completion: Angle @ TD: deg @ Annt~ar Fluid: Last W/O: Rev Reason: NEW WELL Reference Lo Ref Lo Date: Last U date: 3/29/2008 Last Ta TD: 13694 ftK6 Last Tag Date: Max Hole Angle: 0 deg @ f'acinn Ctrinn _ DI I CTRIIJ(~C bescri lion Size To Bottom ND V1R Grade Thread CONDUCTOR 16.000 0 114 114 62.50 H-40 WELDED PRODUCTION 7.000 33 13694 13694 26.00 L-80 MBTC SURFACE 9.625 36 3244 3244 40.00 L-80 MBTC Tubing String -TUBING Size To Bottom TVD Ult Grade Thread 4.500 31 113 113 12.60 L-80 IBT 3.500 113 13131 -- 13131 9.30 L-80 EUE8rdMO D Perforations Su Interval 1295[1 1:'970 1 mmary ND Zone Status 2950 - 1 ~~?0 _ Ft _ 20 SPF Date 6 3126/2(p8 _ Type _ IPERF _ Comment 3-5"OMEGA WL PJ ~500~ Gas Lift Mandr eisNalves I ~,_._ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VN Cmnt 1 5239 5239 CAMCO KBMG-2 DMY 1.0 BK-5 0.000 0 3/26/2008 DCK-2 2 10055 10055 CAMCO KBMG-2 DMY 1.0 BK-5 0.000 0 3/26/2008 3 12146 12146 CAMCO KBG-2 -- -- SOV 1 0 BEK-5 0.000 0 3/26/2008 Injection MandrelsNalves ___ V Mfr ~ t i MD ND ~- YP YP OD Latch V TRO _ _ Vlv l Cmnt a 1 1 3 CAMCO MMGW DMY ) `, 0 000 3 262008 .Other (plu ss~, e~ui ..~ etc.) -COMPLETION j Depth i TVD I Type I _ _ Description _ L I ID ~ 31 31 HANGER FMC TUBING HANGER 4.500 "X" PROFILE SLEEVE-C - 12352-12353, i OD:4.270) PACKER 12942-12943, OD:5.980) Blast Rings ;12945-12946, OD:3.500) NIP ;13100-13101, OD:4.250) WLEG -~- "13131-13132, OD:4.120) ALPINE CD3-118 13100 13100 NIP HES'XN' NIPPLE w/NO GO & RHC PLUG 2.750 13131 13131 WLEG BAKER WIRELINE GUIDE 3.000 CD3-118 Well Events Summary DATE SUMMARY 3/23/08 PREPARED FOR PERFORATION JOB ON DOYON 19 IN ALPINE. 3/24/08 PERFORATED INTERVAL 12950'-12970' WITH 3.5" POWERJET OMEGA 3/25/08 STANDBY FOR COMPLETION TIE-IN LOG ON DOYON 19. 3/26/08 STANDBY FOR COMPLETION TIE-IN LOG ON DOYON 19. 3/27/08 RAN A GR/CCL LOG TO CORRELATE THE COMPLETION STRING TO OPEN HOLE LOG DEPTHS DETERMINED THAT AN ADDITIONAL 23.7' OF TUBING WOULD BE REQUIRED TO POSITION THE BLAST JOINTS PROPERLY 4/1/08 PULL BALL AND ROD @13,100 RKB. LDFN JOB IN PROGRESS 4/2/08 PULL SOV @ 12146' RKB, PULL DMY @ 10055' RKB & PULL DMY @ 5293'RKB. SET OV @ 12146' RKB, SET GAS LIFT VALVES @ 10055' RKB & 5293' RKB. 4/3/08 PULL RHC PLUG BODY IN XN NIP @ 13100' RKB, CHECK CMD @ 12352' RKB (CLOSED) RUN BHP SURVEY TO 13146' RKB FOR 30 MIN STOP, 15 MIN GRADIENT STOP @ 13046' RKB. Cc~nocoPhillips Time Log Summary We17v7ew Web RepaKf~rg Well Name: CD3-118 Job Type: DRILLING ORIGINAL Time Logs I _ From To Dur S. De th E De th Phase Code Subcode T COM Date 02/25/2008 _ 17:00 00:00 7.00 0 0 MIRU MOVE PSIT P Moved out pits and motor complex's, skid floor to moving position, moved Doyon 19 rig off CD3-113 and began to s of over well. 02/26/2008 00:00 03:00 3.00 0 MIRU MOVE PSIT P Fin. leveling rig over well, skidded rig floor into position then set in pits and motor complex's and connected service loops. Rig on highline and ACCEPTED RIG 03:00 hrs. 03:00 09:30 6.50 0 0 MIRU MOVE RURD P R/U Riser, install flowline & mouse hole. P/U tools, Load pipe shed, strap DP & HWDP. Take on s ud mud. 09:30 17:00 7.50 0 0 MIRU MOVE RURD P P/U, Drift and stood back 5" DP & HWDP. 17:00 17:30 0.50 0 0 SURFA DRILL RURD P RU Sperry Sun Gyro and a-line . 17:30 21:30 4.00 0 65 SURFA DRILL PULD P PU and MU 12 1/4" BHA#1, PU 8" motor and bent to 1.5 deg, motor was frozen, LD and PU 2nd. motor w/1.5 bend, MU MWD and oriented same, flooded conductor and pressure tested mud lines to 3,500 psi while downloadin . 21:30 22:00 0.50 65 65 SURFA DRILL SFTY P Held pre-spud meeting with rig crew and service co. ersonnel. 22:00 22:30 0.50 65 114 SURFA DRILL PULD P Orient UBHO sub and RIH with NMFDC's and jars, tagging up at 110' and cleaned out to 114'. 22:30 00:00 1.50 114 200 SURFA DRILL DDRL P $oudded well drilling 12 1/4" hole from 114' to 200' MD/200' TVD, ART .9 hrs, AST -0-, ADT .9 hrs. 4-7K wob, 50 rpm's, 450 gpm at 740 psi, rot wt 95K, up wt 95K, do wt 95K, off btm torque 4,000 ft-Ibs, on btm 4,500 ft-Ibs. 02/27/2008 00:00 02:45 2.75 200 350 SURFA DRILL DDRL P Drilled 12 1/4" hole from 200' to 350', ART 2 hrs. 02:45 06:00 3.25 350 350 SURFA DRILL SRVY T Ran 3 E-line gyros, 1st run did not match MWD (later found that it was mis-read) ran 2nd tool and didn't compare to MWD or 1st run, re-ran 1st tool and was able to tie into MWD. ~~_ ---- Page 1 raf 2Q r ~ Time Lags ___ I __ _ __ Date From To D ur 5 De th E. De th Phase Code Subcode T COM 02/27/2008 06:00 12:00 _ 6.00 350 740 SURFA DRILL DDRL P Drilled 12 1/4" hole per directional plan from 350' to 740' MD/739' TVD (390') ART 2.04 hrs, AST 2.35 hrs, ADT 4.39 hrs.5-10K wob, 70 rpm's, 450 gpm, off btm press. 800 psi, on btm 880 psi, off btm torque 4,000 ft-Ibs, on btm 4,500 ft-Ibs, rot wt 115K, up wt 106K, do wt 115K 12:00 17:30 5.50 740 1,255 SURFA DRILL DDRL P Drilled f/ 740' to 1,255' MD/1,238' TVD ( 515') ART 1.02 hrs, AST 3.28 hrs, ADT 4.3 hrs. 22-28K wob, 70 rpm's, 450 gpm, off btm press. 880 psi, on btm 1,040 psi, off btm torque 5,000 ft-Ibs, on btm 7,000 ft-Ibs, rot wt 125K, up wt 125K, do wt 125K, after slide was unable to et to drive to rotate. 17:30 00:00 6.50 1,255 1,255 SURFA RIGMN' RGRP T Trouble shoot electrical problem in top drive control panel. Stood 1 std back, breaking circ often while working on TD. 02/28/2008 00:00 05:30 5.50 1,255 1,255 SURFA RIGMN' RGRP T Trouble shoot electrical problem in top drive control panel. Pump & Reciprocate drill string periodically. 40 SPM @ 350 PSI PU 120 SO 120. determined pressure switch to the traction motor failed, by passed same to get top drive to work and ordered new switch. 05:30 12:00 6.50 1,255 1,852 SURFA DRILL DDRL P Drilled 121/4" holew/motorf/1,255' to 1852' MD, 1746' TVD (597') ADT 3.68, RT 1.72, ST 1.96 550 GPM @1330 PSI WOB - 15/25, RPM - 70 String Wt: PU 130, SO 128, ROT 132 Tor ue on/off btm: 7500/6000 12:00 12:30 0.50 1,852 1,973 SURFA DRILL DDRL P Drilled from 1,852' to 1,973' MD/ 1,830' TVD 121' 12:30 12:45 0.25 1,973 1,973 SURFA RIGMN SVRG P Lubricate rig while C/O spring on #1 mud um 12:45 00:00 11.25 1,973 2,905 SURFA DRILL DDRL P Drilled from 1,973' to 2,905' MD/ 2,332' TVD (932') ART 6.7 hrs, AST 1.63 hrs, ADT 8.33 hrs, 25-35K wob, 70 rpm's, 625 gpm, 2,140 psi, off btm torque 6,500 ft-Ibs, on btm 8,500 ft-Ibs, rot wt 130K, up wt 130K, do wt 120K, 9.8 MW with 300 vis. 02/29/2008 00:00 04:00 4.00 2,905 3,254 SURFA DRILL DDRL P Drilled 12 1/4" hole w/motor f/ 2905' to 3254' MD 2494' TVD cs t ADT 3.82, RT 3.36, ST 0.46 650 GPM @ 2380 PSI WOB - 25/35, RPM - 70 String Wt: PU 133, SO 118, ROT 133 Tor ue on/off btm: 8500/7000 04:00 05:00 1.00 3,254 3,063 SURFA DRILL CIRC P Circulate hole clean 650 GPM, 2130 PSI, 70 RPM Stand Back two stands while circulatin Page ~ oaf 2t3 Time Lois Date From To Dur S. De th E De th Phase Code Subcode T COM 02/29/2008 05:00 10:00 5.00 3,063 906 SURFA DRILL REAM P Monitored well-static, backreamed out from 3,063' to 1,586', BROOH at 550 gpm, 1,950 psi and 60-70 rpm's, BROOH from base of the permafrost at (/1,586' to HWDP at 906' at 400 gpm, monitored well-static, oriented to hi h side and blew down to drive. 10:00 11:15 1.25 906 3,183 SURFA DRILL TRIP P RIH to 3183' 11:15 12:30 1.25 3,183 3,254 SURFA DRILL REAM P Wash down to bottom, staging pump rate to 650 GPM @ 2150 PSI, 70 RPM, Circulate hole clean 12:30 12:45 0.25 3,254 3,254 SURFA DRILL OWFF P Monitored well-static, blew down top drive. 12:45 14:30 1.75 3,254 906 SURFA DRILL TRIP P POOH wet on elevators from 3,254' to BHA at 906', no roblems. 14:30 18:15 3.75 906 0 SURFA DRILL PULD P Monitored well-static, POOH standing back HWDP and jars, LD NMFDC's, downloaded MWD then fin LD BHA #1 and cleared ri floor. 18:15 19:45 1.50 0 0 SURFA CASIN( RURD P RU to run 9-5/8" casing. PU csg elevator, bails, slips, casing tongs, work latform and MU fill u tool. 19:45 20:00 0.25 0 0 SURFA CASIN SFTY P Held PJSM with crew and tong o erator. 20:00 23:30 3.50 0 1,627 SURFA CASIN( RNCS P RI with 9-5/8" 40# L-80 BTC-M casin as follows: Float Shoe "Ray oil tools Silver Bullet" - 2 jts csg - Halliburton Float Collar and 40 jts of csg RIH to 1,627'. First 4 jts made up with Baker Loc -Fill pipe & check floats -Bow spring centralizers on jts #1-13 & every otherjt after. Stop rings on 'ts #1 & 3. 23:30 00:00 0.50 1,627 1,627 SURFA CASIN CIRC P Began to circ a csg vol. at 1,627', staged pump rate up to 5 bpm at 300 si, st wt u 127K, do wt 118K. 03/01/2008 00:00 02:15 2.25 1,627 3,244 SURFA CASIN( RNCS P Cont. to RIH with 41 jts 9-5/8" BTC-M csg, (83 total jts) MU FMC fluted Hgr and Landing joint, land csg hanger on landing ring with shoe at 3,244', & float collar 3162'. st wt up 190K do wt 130K 02:15 02:45 0.50 3,244 3,244 SURFA CASINC RURD P LD Franks fill up tool and blow down top drive, MU Dowell cement head and lines. 02:45 05:15 2.50 3,244 3,244 SURFA CEME~ CIRC P Circ and condition mud for cementing, establish circulation at 2 bpm at 250 staging pump rate up to 7 bpm @ 330 psi. Held PJSM for csg cement job. St wt up 165K, do wt 130K, mud properties before /after: 10.1/9.85 300/56 Vis, 23/20 PV, 70/19 YP, 05:15 05:30 0.25 3,244 3,244 SURFA CEME~ SFTY P PJSM for Cement job Pay.. ~ ~af Zit Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/01/2008 05:30 08:15 2.75 3,244 3,244 SURFA CEME~ DISP P Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/nut plug as marker, switched to Dowell and pumped 5 bbls water. Pressure tested lines to 4000 psi. Dropped btm plug and Pumped 50 bbls MUD PUSH@10.5 ppg@400 psi@6 bbls/min -Mixed & pumped 404 bbls ~ 10.7 @ 7.6 lead slurry (ASL bbls/min @ 400 psi (" Observed nut plug marker @ shakers w/ 378 bbls lead pumped -pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg, @ 4.8 bpm at 380 psi. Dropped top plug w/ 20 bbls water f/ Dowell. Switched over to rig pumps & displaced cmt w/ 219.8 bbls 9.8 ppg water base mud. Displaced @ 7.0 bbls/min for first 189.8 bbls then slowed to 3.5 bbls/min for last 30 bbls. Bumped plug w/ 1050 si (pre bump pressure 560 psi ) Check float (held OK) CIP @ 0800 hrs. Had full circulation throughoutjob w/ 110 bbls 10.7 ppg cmt returns to surface. Reci rotated i e while circulating & throu h cement'ob until be innin of tail. 08:15 08:30 0.25 3,244 3,244 SURFA CEME SFEO P RU and test 9 5/8" casing to 3,500 psi. for 30 Min. lost 250 psi in 15 mins.- Bad sensor bleed off ressure 08:30 10:00 1.50 3,244 3,244 SURFA CEME~ RURD P RD cmt head & lines - LD landing jt and long bales. blow down mud lines, drain riser. 10:00 15:15 5.25 0 0 SURFA WELCT NUND P N/D Riser, ND surface adapter and NU csg head & tested same. NU BOP stack. 15:15 15:45 0.50 0 0 SURFA DRILL RURD P Installed elevator bales and installed mousehole. 15:45 17:00 1.25 0 0 SURFA DRILL PULD P Held PJSM and began to LD 4" DP out of the derrick from the mousehole. 17:00 17:30 0.50 0 0 SURFA DRILL PULD P PU Geospan and BHA equip. to the ri floor. 17:30 23:00 5.50 0 0 SURFA DRILL PULD P Fin. LD excess 4" DP out of the derrick, LD a total of 59 stds. 23:00 00:00 1.00 0 0 SURFA DRILL RURD P C/O elevator bales and roughneck dies re arin to PU and std back 5" DP. 03/02/2008 00:00 00:30 0.50 0 0 SURFA DRILL OTHR P Set wear bushing 00:30 10:15 9.75 0 0 SURFA DRILL PULD P PU & Std back 5" DP f/pipe shed 10:15 12:00 1.75 0 0 SURFA RIGMN' RGRP T Change out hydraulic cylinder on iron rou hneck 12:00 15:00 3.00 0 0 SURFA DRILL PULD P RIH w/ 5" DP f/ shed to 2760' 15:00 16:30 1.50 0 0 SURFA RIGMN SVRG P Cut & slip 120' of drill line -Service TD Paga 1 ~f 2l? Time Lo s Date From To Dur 5. De th E. De th Ph se Code Subcode T COM 03/02/2008 16:30 17:45 1.25 0 0 SURFA DRILL PULD P POOH & stand back 29 stands of 5" DP 91 stds total PU 17:45 18:15 0.50 0 0 SURFA DRILL PULD P Pulled wear bushing 18:15 23:30 5.25 0 0 SURFA WELC BOPE P RU and tested BOPE, tested rams, valves and choke manifold to 250 psi low and 3,500 psi high, tested annular to 250 low and 2,500 psi high. Tested Koomey initial press 3,100 psi, 1,700 psi after functioning rams, took 29 seconds to gain 200 psi, 2 min 35 sec. for full recovery, 4-nitrogen bottles ave 1,800 psi. NOTE: Lou Grimaldi W/AOGCC waived witnessing of the test. 23:30 00:00 0.50 0 0 SURFA DRILL PULD P Installed wear bushing 03/03/2008 00:00 04:30 4.50 0 752 SURFA DRILL PULD P MU 8 3/4" BHA #2 and RIH to 752' MD, pressure test GEO SPAN to 3500 PSI and surface test tools (all ood 04:30 06:00 1.50 752 1,882 SURFA DRILL PULD P RIH from 752' to 1882' with 36 Jts of 5" DP from pipe shed and 2 ghost reamers. Filled pipe and sent test commands - 1st command failed, increased flow rate and resent test command - ood 06:00 07:15 1.25 1,882 3,020 SURFA DRILL PULD P RIH from 1882' to 3020' with 5" DP from i e shed 07:15 07:45 0.50 3,020 3,162 SURFA DRILL CIRC P Washed Down from 3020' to 3162' - to of collar. Ta ed cement 3140' 07:45 08:15 0.50 3,162 3,162 SURFA DRILL CIRC P Circulate B/U - 550 GPM @ 1500 psi, 60 RPM 08:15 09:15 1.00 3,162 3,162 SURFA CASIN DHEQ P PJSM -Blow down TD, R/U & test 9 5/8 "casing to 3500 PSI for 30 min. Test ood. 09:15 13:00 3.75 3,162 3,274 SURFA CEME~ DRLG P Drilled out plugs, float collar at 3,162', shoe track and shoe at 3,244', cleaned out to btm at 3,254' then drilled 20' of new hole to 3 274' MD/2,503' TVD. ADT .32 hrs 13:00 13:15 0.25 3,274 3,274 SURFA DRILL CIRC P Circ btm up for LOT, circ at 550 gpm, 1,400 psi, 40 rpm's. rot wt 125K, up wt 150K, do wt 110K 13:15 14:00 0.75 3,274 3,274 SURFA DRILL LOT P RU and erformed a LOT to 16.6 EMW, 910 psi at 2,489' TVD and 9.6 MW. 14:00 15:00 1.00 3,274 3,274 INTRM1 DRILL CIRC P Displaced hole over to new 9.6 ppg LSND mud then est. clean hole ECD at 10.2 ppg at 600 gpm, 1,200 psi and 90 r m's. E ~~~; 5 Rf 2t; r Time Logs Date From To Dur S. De th E. De th Ph e Code Subcode T COM 03/03/2008 15:00 00:00 9.00 3,274 4,030 INTRM1 DRILL DDRL P Drilled 8 3/4" hole with Geopilot from 3,274' to 4,030' MD/ 2840' TVD. (756') ADT 6.98 hrs, 17-20K wob, 60-100 rpm's, 600 gpm, 1,400 psi, off btm torque 7,500 ft-Ibs, on btm 8,500 ft-Ibs, rot wt 134K, up wt 135K, do wt 125K, 9.65 ppg MW, ave ECD 10.7 03/04/2008 00:00 12:00 12.00 4,030 5,210 INTRM1 DRILL DDRL P Drilled 8 3/4" hole with GP f/ 4,030' to 5210' MD - 1180' TVD ADT 8.58 hrs, -ECD - 10.98 ppg WOB 18/20 k RPM 140 GPM 650 @ 1970 psi String wt. PU 160 SO 125 Rot 140 Tor ue on/off btm. -11,500/9,500 ft/Ibs 12:00 00:00 12.00 5,210 6,726 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 5210' to 6726' MD - 4088' TVD ADT - 9.22 hrs ECD - 10.98 ppg WOB 20/23 k RPM 150 GPM 650 @ 2250 psi String wt. PU 188 SO 130 Rot 154 Torque on/off btm. -12,000/11,000 ft/Ibs 03/05/2008 00:00 12:00 12.00 6,726 8,130 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 6726' to 8130' MD - 4730' TVD ADT - 8.34 hrs ECD - 10.93 ppg WOB 20/23 k RPM 150 GPM 650 @ 2250 psi String wt. PU 220 SO 135 Rot 165 Torque on/off btm. - 17,500/16,000 ft/Ibs 12:00 20:30 8.50 8,130 9,203 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/GP f/ 8130' to 9203' MD - 5222' TVD ADT - 6.57 hrs ECD -11.02 ppg WOB - 20/23 k RPM 150 GPM 650 @ 2060 psi . String wt. PU 235 SO 140 Rot 173 for ue on/off btm. - 15,500/15,000 20:30 21:45 1.25 9,203 9,203 INTRM1 DRILL OTHR T Trouble shoot MWD -Tool wouldn't res and 21:45 22:30 0.75 9,203 9,203 INTRM1 DRILL CIRC T Circ btms up for trip out - 550 gpm @ 2100 si w/ 150 r m -Flow ck -static 22:30 00:00 1.50 9,203 8,252 INTRM1 DRILL TRIP T POOH f/ 9203' to 8252' -back reaming w/ 550 m 1500 si w/ 100 r m 03/06/2008 00:00 00:30 0.50 8,252 8,062 INTRM1 DRILL TRIP T POOH f/ 8252' - 8062' back reaming w/ 550 m 1500 si w/ 100 r m 00:30 02:00 1.50 8,062 7,111 INTRM1 DRILL TRIP T POOH on TT f/ 8,062' to 7,111', flow check -static. pump slug and blow down TD 02:00 05:00 3.00 7,111 3,210 INTRM1 DRILL TRIP T POOH on TT f/7111' to 3,210', flow check shoe -static. 05:00 08:45 3.75 3,210 0 INTRM1 DRILL TRIP T POOH on TT f/ 3,210' to 725' LD - Ghost reamers, POOH f/ 725' -Std back HWDP & NMFC's - LD FLT & HOC P~ye e: i 2 1 j i Time Logs Date From To Dur 5 D~th E. De th Phase Code Subcode T COM 03/06/2008 08:45 10:45 2.00 0 725 INTRM1 DRILL PULD T Found pulser damaged -Pull up & service GP & check bit -Change out pulser - MU HOC & float sub - RIH w/ NM flex DC's - HWDP & jars to 725' - Puise test MWD -Blow down TD 10:45 15:15 4.50 725 9,114 INTRM1 DRILL TRIP T RIH f/ 725' to 1887' -Picking up ghost reamers & continue RIH f/ 1887' to 9114' fillin i e eve 20 stds 15:15 16:00 0.75 9,114 9,203 INTRM1 DRILL REAM T Establish circ & wash down f/ 9114' to 9203' -Circ btms up @ 650 gpm @ 2490 si w/ 100 r m 16:00 00:00 8.00 9,203 10,161 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 9203' to 10,161' MD - 5659' TVD ADT - 5.57 hrs ECD - 10.87 ppg WOB 22!24 k RPM 150 GPM 650 @ 2260 psi String wt. PU 250 SO 147 Rot 182 Torque on/off btm. - 17,000/16,000 ft/Ibs 03/07/2008 00:00 12:00 12.00 10,161 11,588 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 10,161' to 11,588' MD - 6,317' TVD ADT - 8.65 hrs ECD - 11.11 ppg WOB 22/24 k RPM 150 GPM 650 @ 2520 psi String wt. PU 280 SO 145 Rot 195 Torque on/off btm. -19,500/11,588 ft/Ibs 12:00 13:00 1.00 11,588 11,688 INTRM1 DRILL DDRL P rilled 8 3/4" hole w/ GP f/ 11,588' to , 11,688' MD - 6,358' TVD. ADT - .58 hrs ECD - 11.11 ppg WOB 22/24 k RPM 150 GPM 650 @ 2520 psi String wt. PU 280 SO 145 Rot 195 Torque on/off btm. -19,500/11,588 ft/Ibs 13:00 00:00 11.00 11,688 10,261 INTRM1 DRILL CIRC T Lost hi hline ower to ri Went on rig power (4 gen sets) -Circ @ 420 gpm @ 1150 psi w/ 70 rpm -Torque 18,000 ft/Ibs -Began POOH w/ pump f/ 11,688' to 10,261' @ 4.8 bbls/min @ 450 psi w/ 20 rpm's - PU wt. 255 SO wt. 145 - Went to 2 gen set @ 1730 hrs. " Note Unable to drill ahead per air quality permit -Pulling to shoe with limited ower to et well in safe condition. Page 7 of 2Q .. Time Logs _ Date From To Dur 5. De th E. De th Phase Code Subcode T COM 03/08/2008 00:00 10:45 10.75 10,261 8,448 INTRM1 DRILL TRIP T POOH w/ pump f/ 10,261' to 8,448' @ 4.8 bbls/min @ 450 psi w! 20 rpm's - PU wt. 230 SO wt. 140 @ 9,019' - Hole takin 8-10 b h -Blow down top drive -monitor well, static in 13 minutes -Operating on 2 gen sets " Note Unable to drill ahead per air quality permit -Pulling to shoe with limited power to oet well in safe condition *Rig and pad electricians re aired dama ed hi hline load break a ri Rig electrician replaced damaged card in MCC. Note: Sent rig electrician to bed @ 0200 hrs.until 07:00 hrs -after working 20 hrs. 10:45 13:30 2.75 8,448 11,592 INTRM1 DRILL TRIP T RIH from 8448' to 11,592' -fill pipe every 20 stands -hole appears in good condition Ri on hi hline ower 1145 h ur 13:30 13:45 0.25 11,592 11,640 INTRM1 DRILL REAM T Precautionary ream from 11,592'to 11,640' - 600 m / 2480 si / 110 r m 13:45 14:45 1.00 11,640 11,640 INTRM1 DRILL CIRC T Lost hi hline ower-bring second Gen set on line -circulate and reciprocate pipe - 6 bpm / 650 psi - PUW 290K SOW 155K -Troubleshoot hi hline ower failure 14:45 17:15 2.50 11,640 10,922 INTRM1 DRILL TRIP T POOH w/ pump - 5 bpm / 520 psi from 11,640' to 10,922' -flow check well, static -blow down to drive 17:15 19:30 2.25 10,922 9,437 INTRM1 DRILL TRIP T POOH on TT f/ 10,922' to 9437' while trouble shootin electric roblem 19:30 20:15 0.75 9,437 9,495 INTRMI DRILL TRIP T Switched rig back onto highline power - RIH to 9495' -Load test w/ rig pumps @ 650 gpm w/ rotary @ 150 rpm's - OK -Blow down TD 20:15 00:00 3.75 9,495 7,306 INTRM1 DRILL TRIP T Attempt to RIH -Lost high line power again -rig electrician concurred that circuit breaker on location was wron one, but could work w/ some modification -POOH on TT f/ 9495' to 7306' - PU wt. 235 SO wt. 140 Note; Made discission to pull to 9 5/8" csg shoe & continue working on electrical problem -Tour pusher went to Deadhorse to pick up proper circuit breaker. Advised Drillin Su erintendent 03/09/2008 00:00 02:30 2.50 7,306 6,193 INTRM1 DRILL TRIP T POOH on TT f/ 7,306" to 6,193' - wi ed throw h ti ht s of 6,595' 02:30 03:30 1.00 6,193 6,193 INTRM1 DRILL OTHR P Time change to Daylight savings f~ag$ 8 cf 2(7 i Time Logs Date From To Dur S De th E. Depth Ph se Code Subco_ d T CO_M 03/09/2008 03:30 05:30 2.00 6,193 5,691 INTRM1 DRILL TRIP T Backream from 6,193' to 5,691' - 7 bpm / 510 psi / 30 rpm -tight spots @ 6193', 6002', 5828', 5793' 05:30 08:30 3.00 5,691 3,219 INTRM1 DRILL TRIP T POOH on TT f/ 5,691' to 3,219' -flow check well, static 08:30 12:15 3.75 3,219 3,219 INTRM1 RIGMN RGRP T Blow down top drive -Power down 600v buss -Replace #2 2000V Breaker -Rig on highline power @ 1200 hours * Monitor well on trip tank - no gain / no losss 12:15 13:15 1.00 3,219 3,219 INTRM1 RIGMN OTHR P PJSM -Slip and cut drilling line 13:15 13:45 0.50 3,219 3,692 INTRM1 DRILL TRIP T RIH f/ 3,219' to 3692' -load test breakers - 650 gpm / 1960 psi / 130 r m -blow down to drive 13:45 18:45 5.00 3,692 11,592 INTRM1 DRILL TRIP T RIH f/ 3,692' to 11,592' (filling pipe eve 20 stds 18:45 19:30 0.75 11,592 11,688 INTRM1 DRILL REAM T Precautionary wash & ream f/ 11,592' t - w/ 550 gpm @ 2040 psi w/ 140 rpm's -ECD- 11.37 ppg (took wt. 11,668" 19:30 00:00 4.50 11,688 12,063 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 11,68' to 12,063' MD 6533' TVD ADT - 2.8 hrs. ECD - 10.79 ppg WOB 18/22 k RPM 150 GPM 650 @ 2650 psi String wt. PU 250 SO 160 Rot 195 Torque on/off btm - 20,000/19,000 ft/Ibs Treated mud system for drilling HRZ & remainder of 8 3/4" hole w/ 750 bbls dilution containing 5% inhibycol XT, 5 ppb Soltex & Resinex, 5 ppb Drispac Plus SL & 2% Lotor . 03/10/2008 00:00 12:00 12.00 12,063 13,100 INTRM1 DRILL DDRL P Drilled 8 3/4" hole wl GP f/ 12,063' to 13,100' MD 6856' TVD ADT - 8.3 hrs. ECD - 11.04 ppg WOB 20/24 k RPM 150 GPM 650 @ 2870 psi String wt. PU 265 SO 155 Rot 200 Torque on/off btm - 21,000/19,500 ft/Ibs 12:00 18:45 6.75 13,100 13,706 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 13,100' to 13 706' M D 6944' ND ADT - 4.73 hrs ECD - 10.77 ppg WOB 10/18 k RPM 150 GPM 600 @ 2530 psi String wt. PU 265 SO 155 Rot 198 Torque onloff btm. - 22,000/20,000 ft/Ibs 18:45 21:30 2.75 13,706 13,377 INTRM1 DRILL CIRC P Circ 3 x btms up @ 600 gpm @ 2470 psi w/ 150 rpm's -after 1st. btms up - began standing back 1 std every 30 mins. f/ 13,706' to 13,377' Page 9 of 20 Time Logs Date From To Dur S De th E. De th Ph e Code Subcode T COM 03/10/2008 21:30 00:00 2.50 13,377 12,140 INTRM1 DRILL WPRT P Wiper trip f/ 13,377; to 12,140' (top of HRZ backreaming w/pump @ 550 gpms @ 2020 psi w/ 110 rpm's - No roblems 03/11/2008 00:00 01:00 1.00 12,140 13,556 INTRM1 DRILL TRIP P RIH from 12,140' to 13,556' - no roblems 01:00 02:30 1.50 13,556 13,706 INTRM1 DRILL CIRC P Precautionary wash and ream from 13,556' to 13,706' -Circulate and condition mud - 600 gpm / 2500 psi / 130 rpm / 16K ft/Ibs torque -flow check well, static -spot WBS and tube ills to bit 02:30 05:00 2.50 13,706 12,063 INTRM1 DRILL TRIP P Pump out spotting pills into open hole from 13,706' to 12,063' - 2.5 bpm / 320 si -flow check well, static 05:00 12:00 7.00 12,063 7,311 INTRM1 DRILL TRIP P POOH on TT from 12,063' to 7311' - wiped through tight spots @ 10,782' & 8,540' " Lost highline power @ 0445 -rig on 2 en sets 12:00 16:30 4.50 7,311 3,216 INTRM1 DRILL TRIP P Continue POOH on TT from 7,311' to 3,216' - Backreamed tight spot @ 6340', wiped through tight spot @ 5940' -Flow check well, static for 10 minutes 16:30 19:45 3.25 3,216 731 INTRM1 DRILL TRIP P POOH on TT from 3,216' to 731'. 19:45 22:30 2.75 731 0 INTRM1 DRILL PULD P Stood back HWDP. Down loaded LWD and laid down BHA. 22:30 00:00 1.50 0 0 INTRM1 WELCT BOPE P PJSM and chan ed to rams to 7". Installed test lu . 03/12/2008 00:00 01:00 1.00 0 0 INTRM1 WELCT ROPE P RU and test 7" pipe rams 250 / 3500 psi - LD test jnt. & plug -set thin wall wear bushin 01:00 02:30 1.50 0 0 INTRM1 CASIN RURD P RU to run 7" casing 02:30 02:45 0.25 0 0 INTRMI CASINC SFTY P Held Pre-job Safety and Opts meeting with crew 02:45 08:15 5.50 0 4,496 INTRM1 CASIN RNCS P Run 7" 26# L-80 BTCM csg as follows: Ray Oil Tools Float shoe - 1 jts csg -Halliburton Float collar - 2 jts csg. Halliburton shut off collar (first 4 joints made up w/ Baker Loc -Filled pipe & checked float) - 103 jts to 4496' (106 jts total) Ran centralizers on'ts. # 1-14 08:15 08:45 0.50 4,496 4,496 INTRM1 CASINC CIRC P Establish circulation -stage pumps up to 7.5 bpm -condition mud -FCP = 600 psi PUW 150K SOW 120K 08:45 13:45 5.00 4,496 8,478 INTRM1 CASINC RNCS P Run 7" 26# L-80 BTCM csg. from 4,496' to 8,478' 200 'ts total 13:45 14:45 1.00 8,478 8,478 INTRM1 CASINC CIRC P Establish circulation -stage pumps up to 7 bpm -condition mud -FCP = 590 psi PUW 245K SOW 135K Page 1Clof21~ a r Time Logs _ _ Date From To Dur S De th E De th Ph e Code Subcode T COM 03/12/2008 14:45 18:45 4.00 8,478 12,036 INTRM1 CASIN( RNCS P Run 7" 26# L-80 BTCM csg. from 8,478' to 12,036. 18:45 20:15 1.50 12,036 12,036 INTRM1 CASIN( CIRC P Establish circulation -stage pumps up to 5.5 bpm -condition mud - FCP = 580 psi PUW 295 K SOW 160 K. 20:15 22:30 2.25 12,036 13,694 INTRM1 CASINC RNCS P Run 7" 26# L-80 BTCM csg. from 12,036' to 13,694. Landed casin . 22:30 23:00 0.50 13,694 13,694 INTRMI CASIN( RURD P Laid down Franks tool and made up cement head. 23:00 00:00 1.00 13,694 13,694 INTRMI CASINC CIRC P Establish circulation -stage pumps up to 4.5 bpm -condition mud - CP = 520 psi PUW 325 K SOW 150 K. 03/13/2008 00:00 00:45 0.75 13,694 13,694 INTRM1 CEME CIRC P Reciprocate casing -condition mud for cementing FCR/P = 6 bpm @ 650 psi PUW 330K SOW 150K - PJSM for cementin 00:45 03:15 2.50 13,694 13,694 INTRM1 CEMEI~ DISP P Cement 7" casing as follows: Pumped 5 bbls CW-100 -Pressure test lines to 3800 psi -Pumped remaining 35 bbls CW-100 -Mix & pumped 35 bbls - 10.5 ppg MudPush -Dropped btm plug -pumped last five bbls of MudPush - Load top plug in cement head -Mixed & pumped 83 bbls (400 sxs) 15.8 ppg., tail slur (Class G w/ additives) - Dropped top plug w/ 20 bbls fresh water f! Dowell -Switched to rig pumps & displaced cmt w/ 480 bbls 9.9 ppg mud -Displaced @ 7 bbls/min - 227 to 520 psi for first 470 bbls - slowed pumps to 4 bbls/min -psi for last 10 bbls of displacement Final displacement pressure 510 psi - Bumped plug w/ 1050 psi -Checked fl - - Reci rotated i e for first 250 bbls of dis lacement -pulled 75k over PUW and landed casing -had full circulation throughout job. -Bled off casing and loaded second stage closing plug in cement head. 03:15 03:30 0.25 13,694 7,164 INTRM1 CEME CIRC P Pressure up casing -opened Halliburton ES sta a collar to 71 4' with 3150 si -establish circulation and condition mud - 7 bpm / 320 si. Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T COM _ 03/13/2008 03:30 05:00 1.50 7,164 7,.164 INTRM1 CEME~ DISP P Cement 7" casino 2nd staae as Pumped 5 bbls CW-100 - Pressure test lines to 3700 psi - Pumped remaining 20 bbls CW-100 - Mix & pumped 25 bbls - 10.5 ppg MudPush -Mixed & pumped 41 bbls 195 sxs 15.8 tail slur Class G w/ additives) -Dropped closing plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cmt w/ 234.7 bbls 9.9 ppg mud - Displaced @ 7 bbls/min - 162 to 348 psi for first 225 bbls -slowed pumps to 4 bbls/min -psi for last 10 bbls of displacement -Final displacement pressure 210 psi -Bumped plua w/ 2460 si I -Checked floats OK - CIP 04 hrs.- full circulation throw hout 'ob. 05:00 06:15 1.25 7,164 0 INTRM1 CEME~ RURD P RD cement head and casing elevators - LD landing joint and pull thin wall wear bushin . 06:15 07:00 0.75 0 0 INTRM1 CASIN DHEO P Install and test FMC packoff to 5000 si for 10 minutes. 07:00 08:00 1.00 0 0 INTRM1 CASIN RURD P Chan a to i e rams to 3 1/2" x 6" VBR's - LD casing bails - PU drilling bails and 5" elevators -clear e ui ment from ri floor. 08:00 09:00 1.00 0 0 INTRM1 WELCT BOPE P Set test plug with 4" test joint -test top rams 250 / 3500 psi - LD test joint & plug -install wear bushing in wellhead. 09:00 23:15 14.25 0 0 INTRM1 DRILL PULD P Lay down 5"drill pipe in mousehole. 23:15 00:00 0.75 0 0 INTRM1 DRILL PULD P Changed dies in Iron Roughneck and icked u cleanout BHA. 03/14/2008 00:00 00:30 0.50 0 288 INTRM1 DRILL TRIP P Pick up 4" hwdp and RIH from 104' to 288' 00:30 08:00 7.50 288 7,035 INTRM1 DRILL TRIP P RIH picking up 4"drill pipe from 288' to 7035' 08:00 08:45 0.75 7,035 7,035 INTRM1 CASIN DHEO P RU and test casing to 3500 psi for 10 minutes - RD, blow down lines 08:45 11:30 2.75 7,035 7,320 INTRM1 CEME~ OTHR P Wash and ream from 7035' - 6 bpm / 890 psi / 80-100 rpm -cleaned out cement from 7090' -drilled out stage collar and cenent below collar to 7195' - RIH f/ 7195' to 7320 - no pumps, no rota 11:30 12:00 0.50 7,320 7,035 INTRM1 DRILL TRIP P Blow down top drive -set back 3 stands in derrick to 7,035' 12:00 14:45 2.75 7,035 9,222 INTRM1 DRILL TRIP P RIH picking up 4"drill pipe from 7035' to 9,222' 69 'ts 14:45 16:00 1.25 9,222 10,938 INTRM1 DRILL TRIP P RIH with stands in derrick from 9,222' to 10,938' 16:00 16:30 0.50 10,938 10,938 INTRM1 DRILL OTHR P Measure drill pipe in shed Pa~,~: 9~ ~f 2d j Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/14/2008 16:30 19:00 2.50 10,938 13,418 INTRM1 DRILL TRIP P Continue to RIH picking up 4"drill pipe from 10,938' to 13,418'. 19:00 20:15 1.25 13,418 13,514 INTRM1 CEME~ COCF P Washed from 13,418' to 13,444' Tagged stringer. Cleaned out cement strin ers from 13,444' to 13,514'. 20:15 21:15 1.00 13,514 13,514 INTRM1 CASIN DHEO P Ri ed u and tested casin 3500 si for 30 min. OK. Ri ed down lines. 21:15 00:00 2.75 13,514 13,514 INTRM1 RIGMN' RGRP T Worked on Highline power module. 03/15/2008 00:00 03:45 3.75 13,514 13,673 INTRM1 CEME~ DRLG P Drilled shoe track and cleaned out cement from 13,514' to 13,673'. 50 RPM, 5 BPM, 10 -15 K WOB. PP 1260 si. 03:45 05:15 1.50 13,673 13,673 INTRM1 CEME~ CIRC P CBU 5 BPM 1280 psi. 40 RPM. 05:15 06:45 1.50 13,673 12,655 INTRM1 CEME TRIP P Blew down top drive and POOH on TT from 13,673' to 12,655'. 06:45 17:30 10.75 12,655 12,655 INTRM1 RIGMN RGRP T Working on rig SCR system replaced transformer and card. 17:30 18:45 1.25 12,655 12,655 INTRM1 RIGMN SVRG P Slipped and cut Drilling Line. 18:45 00:00 5.25 12,655 3,136 INTRM1 CEME~ TRIP P Pumped dry job and POOH on TT from 12,655' to 3,136'. 03/16/2008 00:00 01:30 1.50 3,136 0 INTRM1 CEME~ TRIP P POOH f/ 3136' to 288' -standback hwdp - LD bit, bs & stab -standback flex collars 01:30 02:45 1.25 0 0 INTRM1 WELCT OTHR P Drain stack -Pull wear bushing -set test lu w/ 4" test 'oint 02:45 07:45 5.00 0 0 INTRM1 WELCT ROPE P Test BOPE -Annular reventor 250/2500 psi _ Tesat Pipe and blind rams, choke, kill, manifold and surface safety valves to 250/3500 psi - LD 4" test joint - Mu 3 1/2" test joint and test top VBR's 250/ 3500 psi -Pull test plug, blow down lines -Install wear bushing "'Chuck Scheve waived witnessing BOPE tests 07:45 10:00 2.25 0 119 INTRM1 DRILL PULD P MU BHA #5 -bit - GeoPilot -pony flex -stab - DM HOC - GR Res -Stab - PWD - TM HOC - Batsonic 10:00 11:00 1.00 119 119 INTRM1 DRILL OTHR P Initialize tool string 11:00 11:30 0.50 119 405 INTRM1 DRILL PULD P Continue to MU BHA: PU FS & IBS - RIHwith Flex collars - XO -hwdp and 'ars to 405' 11:30 12:00 0.50 405 405 INTRM1 DRILL OTHR P Shallow test tools -Pulse test good - Down link, ood 12:00 16:00 4.00 405 5,544 INTRM1 DRILL TRIP P RIH picking up 4"drill pipe from 405' to 5,544' 162 'ts. 16:00 17:15 1.25 5,544 8,016 INTRM1 DRILL TRIP P RIH with stands from 5,544' to 8,016'. 17:15 18:15 1.00 8,016 8,016 INTRMI DRILL CIRC T Filled pipe. LWD not responding. Trouble shoot LWD. 18:15 21:15 3.00 8,016 408 INTRM1 DRILL TRIP T POOH on TT to 408'. -~®®® ~~ Page 13 of 2~ • Time Logs Date From To Dur 5 De th E. De th Ph se Code Subcode T COM 03/16/2008 21:15 00:00 .2.75 408 32 INTRM1 DRILL PULD T Stood back Flex Collars. Checked tools Short in system unable to pinpoint problem. Changing out LWD tools. 03/17/2008 00:00 02:15 2.25 32 126 INTRM1 DRILL PULD T Continue to MU BHA #6 - DM HOC - GR Res -Stab - PWD - TM HOC - Batsonic - FS & IBS -Initialize tools 02:15 02:30 0.25 126 315 INTRM1 DRILL TRIP T RIH with nmfc's - xo - 1 std hwdp to 315' 02:30 03:00 0.50 315 315 INTRM1 DRILL DHEO T Pulse test tools -down link to GeoPilot 03:00 06:30 3.50 315 8,016 INTRM1 DRILL TRIP T RIH from 315' to 8,016'- fill pipe every 20 stands 06:30 08:45 2.25 8,016 11,444 INTRM1 DRILL TRIP P RIH from 8,016' to 11,444' -fill pipe eve 20 stands 08:45 19:15 10.50 11,444 13,675 INTRM1 EVAL1Ib DLOG P Make Mad pass with Batsonic tool for cement evaluation log rom 4 to 13,573' - Bit de th= 13 675' 19:15 20:45 1.50 13,675 13,706 INTRM1 CEME~ DRLG P Broke circulation and cleaned out shoetrack and rathole to 13,706'. 20:45 21:30 0.75 13,706 13,726 INTRM1 DRILL DDRL P Drilled 20' of new hole from 13,706' to 13,726' ADT .32 hrs. 21:30 22:45 1.25 13,726 13,726 INTRM1 DRILL CIRC P CBU 218 gpm 90 rpm 1840 psi. 22:45 23:15 0.50 13,726 13,726 INTRM1 DRILL FIT P Ri ed u and erformed FITt 12.5 PP EMW. Ri ed down. 23:15 00:00 0.75 13,726 13,726 INTRM1 DRILL CIRC P Displaced 9 PPG FloPro to bit 216 m 90 r m 2100 si. 03/18/2008 00:00 12:00 12.00 13,726 14,657 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 13,726' to 14,647' MD 6934' TVD ADT - 8.3 hrs ECD - 10.94 ppg WOB 12/15 k RPM 130 GPM 211 @ 1960 psi String wt. PU 187 SO 143 Rot 168 Torque on/off btm. - 10,000/8,000 ft/Ibs Changed mud to 9 PPG FloPro while drillin . Flowchecked well static. 12:00 00:00 12.00 14,657 15,531 PROD1 DRILL DDRL P Cont. to drill 6 1/8" hole from 14,657' to 15,531' MD/ 6,920' TVD (874') ADT 8.82 hrs, 10-14K wob, 130 rpm's , 50 spm, 211 gpm, 2,070 psi, off btm torque, 8,000 ft-Ibs, on btm 10,000 ft-Ibs, Rot wt 165K, up wt 187K, do wt 140K, Flo Pro MW 9.15 ppg, ave ECD 11.15 ppg with no losses. Centrifu a down 03/19/2008 00:00 12:00 12.00 15,531 16,294 PROD1 DRILL DDRL P Drilled 6 1/8" hole w/ GP f/ 15,531' to 16,294' MD 6294' TVD ADT - 8.61 hrs, 9.1 ppg MW, ECD - 11.31 ppg WOB 8/12 k RPM 110 GPM 210 @ 2240 psi String wt. PU 180 SO 135 Rot 160 Tor ue on/off btm. - 10,000/8,000 ft/Ibs Pace ~~1 of 2~ Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 03/19/2008 12:00 00:00 12.00 16,294 16,979 PROD1 DRILL DDRL P __ Cont. to drill 6 1/8" hole from 16,294' to 16,979' MD/ 6,919' TVD (685') ADT 8.67 hrs, 10-13K wob, 110 rpm's , 50 spm, 210 gpm, 2,380 psi, off btm torque, 8,000 ft-Ibs, on btm 10,500 ft-Ibs, Rot wt 160K, up wt 180K, do wt 130K, Flo Pro MW 9.1 ppg, ave ECD 11.4 Centrifu a down 03/20!2008 00:00 12:00 12.00 16,979 17,544 PROD1 DRILL DDRL P Cont. to drill 6 1/8" hole with Geopilot from 16,979' to 17,544' MD/ 6,922' TVD (565') ADT 8.85 hrs, 8-13K wob, 110 rpm's, 47 spm, 200 gpm, 2,230 psi, off btm torque, 9,000 ft-Ibs, on btm 11,500 ft-Ibs, Rot wt 164K, up wt 202K, do wt 135K, Flo Pro MW 9.0 ppg, ave ECD 11.35 ppg, ave 5-10 bph mud losses. 12:00 00:00 12.00 17,544 18,297 PROD1 DRILL DDRL P Cont. to drill 6 1/8" hole from 17,544' to 18,297' MD/ 6,909' TVD (753') ADT 9.51 hrs, 10-13K wob, 115 rpm's, 47 spm, 200 gpm, 2,340 psi, off btm torque, 10,000 ft-Ibs, on btm 12,500 ft-Ibs, Rot wt 164K, up wt 200K, do wt 125K, Flo Pro MW 9.1 ppg, ave ECD 11.45 ppg, ave 10-15 bph mud losses. Adding 275 bbls new Flo Pro mud to s stem eve 500' Centrifu a down 03/21/2008 00:00 12:00 12.00 18,297 18,994 PROD1 DRILL DDRL P Cont. to drill 6 1/8" hole with Geopilot from 18,297' to 18,994' MD/ 6,898' TVD (69T) ADT 9.57 hrs, 8-13K wob, 115 rpm's, 47 spm, 200 gpm, 2,410 psi, off btm torque, 10,000 ft-Ibs, on btm 12,000 ft-Ibs off, Rot wt 162 K, up wt 204 K, do wt 116 K, Flo Pro MW 9.1 ppg, ave ECD 11.5 ppg, ave 10-15 b h mud losses. Adding 275 bbls new Flo Pro mud to s stem eve 500'. 12:00 00:00 12.00 18,994 19,650 PROD1 DRILL DDRL P Cont. to drill 6 1/8" hole from 18,994' to 19,650' MD/ 6,892' TVD (656') ADT 9.28 hrs, 10-13K wob, 115 rpm's, 47 spm, 200 gpm, 2,500 psi, off btm torque, 10,000 ft-Ibs, on btm 12,500 ft-Ibs off, Rot wt 162 K, up wt 205 K, do wt 107 K, Flo Pro MW 9.0 ppg, ave ECD 11.65 ppg, ave 15-20 bph m Adding 275 bbls new Flo Pro mud to system every 500'. Centrifu a down 03/22/2008 00:00 12:00 12.00 19,650 20,212 PROD1 DRILL DDRL P Cont. to drill 6 1/8" hole from 19,650' to 20,212' MD/ 6,889' TVD (562') ADT 9.23 hrs, 12-13K wob, 113 rpm's, 47 spm, 200 gpm, 2,440 psi, off btm torque, 10,500 ft-Ibs, on btm 12,500 ft-Ibs off, Rot wt 162 K, up wt 207 K, do wt 70 K, 9.1 ppg MW, ave ECD 11.71 ppg, ave 18-22 bph mud losses. Adding 275 bbls new Flo Pro mud to s stem eve 500'. Eaage 1 ~ of 20 ~~ Time Logs Date From To Dur S. De th E De th Phase Code Subcode T COM 03/22/2008 12:00 00:00 12.00 20,212 20,930 PROD1 DRILL DDRL P Cont. to drill 6 1/8" hole from 20,212' to 20,930' MD/ 6,888' ND (718') ADT 9.61 hrs, 12-13K wob, 113 rpm's, 47 spm, 200 gpm, 2,370 psi, off btm torque, 11,500 ft-Ibs, on btm 13,500 ft-Ibs off, Rot wt 162 K, up wt 215 K, do wt 70 K (blk wt), 9.1 ppg MW, ave ECD 11.63 ppg, ave 18-22 bph mud losses. Adding 275 bbls new Flo Pro mud to system every 500'. (Centrifuge down 03/23/2008 00:00 01:00 1.00 20,930 20,965 PROD1 DRILL DDRL P Cont. to drill 6 1/8" hole from 20,930' to 20,965' MD/ 6,888' ND ADT .48 hrs, 12-13K wob, 113 rpm's, 47 spm, 200 gpm, 2,370 psi, off btm torque, 11,500 ft-Ibs, on btm 13,500 ft-Ibs off, Rot wt 162 K, up wt 215 K, do wt 70 K (blk wt), 9.1 ppg MW, ave ECD 11.63 ppg, ave 18-22 bph mud losses. Adding 275 bbls new Flo Pro mud to s stem eve 500'. Centrifu a down . 01:00 02:15 1.25 20,965 20,870 PROD1 RIGMN SVRG T Backreamed up to 20,870' and changed leaking swivel packing. Circulated with head pin while than in ackin . 02:15 13:00 10.75 20,870 21,228 PROD1 DRILL DDRL P Washed to 20,965'. Cont. to drill 6 1/8" hole from 20,965' to 21,228' MD/ 6,878' ND 263' T.D.- ADT 9.45 hrs, 12-13K wob, 113 rpm's, 47 spm, 200 gpm, 2,550 psi, off btm torque, 11,000 ft-Ibs, on btm 13,500 ft-Ibs off, Rot wt 162 K, up wt 218 K, do wt 70 K (blk wt) ECD 11.71 ppg, ave 22-23 bph mud losses. Adding 275 bbls new Flo Pro mud to system every 500'. Centrifu a down . 13:00 15:15 2.25 21,228 20,774 PROD1 DRILL CIRC P Circ btms up while POOH slow 5 stds from 21,228' to 20,774', Circ at 200 m, 2,520 si at 100 m's. 15:15 15:30 0.25 20,774 20,774 PROD1 DRILL OWFF P Monitored well-static. 15:30 00:00 8.50 20,774 15,530 PROD1 DRILL REAM P Backreamed out of hole from 20,774' to 15,530' w/no problems, BROOH at 4 bpm, 1,900 psi and 100 rpms. Rot wt 160K, up wt 195K, do wt 135K, hole taking over talc fill w/BROOH, 1st 5 stds out took 17 bbls, 14 bbls over talc. and the last 5 stds at 15,530' took 8 bbls, 5 bbls over talc fill. 03/24/2008 00:00. 03:30 3.50 15,530 13,626 PROD1 DRILL TRIP P Cont to backreamed out of hole from 15,530' to 13,626' w/no problems, (csg shoe @ 13,694') BROOH at 4 bpm, 1,900 si and 100 ms. ~" ~ Time Logs Date From To Dur 5 De th E De th Pha e Codg Subcode T COM 03/24/2008 03:30 06:45 3.25 13,626 11,725 PROD1 DRILL TRIP P Flow checked well static. Cont. POOH w/pump at 4 BPM 20 stands to 11,725'. Hole took 106 bbls over talc. fill w/BROOH and pumping out to 11,725'. 06:45 08:30 1.75 11,725 11,725 PROD1 DRILL CIRC P Pumped Hi Vis sweep and displaced well to 9.2 PPG brine. Circ at 200 gpm 1,800 si and 80 r m's. 08:30 16:15 7.75 11,725 408 PROD1 DRILL TRIP P Flow checked well static. Cont. POOH on TT from 11,725' to BHA #6 at 408'. Monitored well-static. 16:15 19:00 2.75 408 0 PROD1 DRILL PULD P Stood back HWDP & LD NMFDC's, downloaded MWD then fin LD BHA #6. Calc fill on trip out from 11,725' was 74 bbls, actual fill 85 bbls. Lost 2 bands on sonic tool due to wear and stab's were worn also. 19:00 19:15 0.25 0 0 COMPZ EVALV~ SFTY P Held PJSM with Schlumberger and crew on RU E-line and erforatin . 19:15 00:00 4.75 0 0 COMPZ EVALVI~ RURD P RU SLB E-line scheaves and shooting ni le with wireline BOP's, MU GR/CCL and 3 1/2" pert guns with rollers above and below guns. Note: Analyzed BAT sonic log and showed to have good bond from 13,565' - 13,540', 13,120' - 13,155', 12,800' - 11,900', 11,860' - 11,820' and 11,960' - 11,665'. Btm interval logged was 13,572' with top of good cmt at 11,665', the remaining was mostly fair to poor bond. Monitored well on trip tank and satic losses ave. 1 b h. 03/25/2008 00:00 02:30 2.50 0 0 COMPZ EVAL ELOG P RIH with 3 1/2" OD 6 SPF Perf guns on E-line to 12,900'. 02:30 03:45 1.25 COMPZ RPCO PERF P Correlated guns on depth with Sperry Suns GR log and perforated KUP sand _ from 12 950' to 12 970', 6 spf, 121 holes. Monitor well on TT and well static. 03:45 05:00 1.25 0 0 COMPZ EVALVb ELOG P POH W/E-line -all shots fired 05:00 06:30 1.50 0 0 COMPZ EVAL RURD P R/D - UD SLB equip & tools 06:30 07:00 0.50 0 193 COMPZ RPCOh RURD P M!U BHA # 7 -Bit, Scrapper, Bit sub, XO,w/ float HWDP & Jars 07:00 10:30 3.50 193 5,900 COMPZ RPCOh TRIP P RIH W/Bit and Scraper to 5,900' 10:30 12:15 1.75 5,900 5,900 COMPZ RIGMN SVRG P Cut & Slipped 120' of Drilling Line, Service To Drive 12:15 16:45 4.50 5,900 13,126 COMPZ RPCOh TRIP P Cont. to RIH to 13,126'. 16:45 18:30 1.75 13,126 13,126 COMPZ RPCOh CIRC P Pumped hi vis sweep and circ out of hole with clean 9.2 ppg brine, circ hole at 5 b mat 800 si. 18:30 18:45 0.25 13,126 13,126 COMPZ RPCOh OWFF P Monitored well-static Page 17 raf ZS3 Time Logs _ Date From To Dur S De th E. De th Ph se Code Subcode T COM 03/25/2008 18:45 00:00 5.25 13,126 6,470 COMPZ RPCOh TRIP P POOH 10 stds and hole was taking proper fill, pumped dry job, blew down top drive and cont POOH to 6,470'. Note: Prior to pert. well, static losses ave 1 bph, after pert. ave 2 bph losses, losses decreased during and after scra er run to less than 1/2 b h. 03/26/2008 00:00 02:30 2.50 6,470 193 COMPZ DRILL TRIP P Continue POOH on TT From 6'470 to 193' Flow Check -static 02:30 03:00 .0.50 193 0 COMPZ DRILL TRIP P S/B HWDP and Jars, LD Scrapper, bit-sub, and XO 03:00 03:15 0.25 0 0 COMPZ DRILL RURD P Pull Wear Bushing 03:15 03:45 0.50 0 0 COMPZ RPCOh RURD P R/U 3 1/2" tbg equipment 03:45 04:00 0.25 0 0 COMPZ RPCOh SFTY P PJSM on running 3 1!2" Tubbing 04:00 06:00 2.00 0 470 COMPZ RPCOh PULD P RIH W/3 1/2" Tubing as follows: WLEG, 1 Jt - 3 1/2" 9.3 #EUE-M Tbg XN Nipple, 1 Jt - 3 1/2" 9.3 #EUE-M Tbg, Baker Premier Packer, w/pups, 1 Jt - 3 1/2" 9.3 #EUE-M Tbg, 1 Jt - 3 ~.s~ _ 1/2" 9.3 #EUE-M Tbg, Baker CMD ~ ~ Sliding Sleave (closed) w/XO pups, 1 Jt - 3 1/2" 9.3 #IBT Tbg w/29' of Blast Ri~nc s, 1 Jt - 3 1/2" 9.3 #IBT 9.28' pup jt w/6' of Blast Rings, 9 Jts - 3 1/2" 9.3 # EUE-M Tbg. At this point it was determined we needed to relocate the slidin sleeve above the Blast Rin s. 06:00 09:00 3.00 470 470 COMPZ RPCO TRIP T POOH from 470' to the joint between the Sliding Sleave and the Premier Packer @ 119'. RIH from 119' with completion as follows: 1 Jt - 3 1/2" 9.3 #EUE-M Tbg, XO pups, 1 Jt - 3 1/2" 9.3 #IBT Tbg w/29' of Blast Rin s, 1 Jt - 3 1/2" 9.3 #IBT 9.28' pup ~t w/6' of Blast Rin sand 9 jts 3 1/2" tb to 470'. 09:00 21:15 12.25 470 10,896 COMPZ RPCOh PULD P Cont RIH with 9 jts - 3 1/2" 9.3 # EUE-M Tbg, 1 -10' pup Jt -3 1/2" 9.3 # EUE-M, Baker CMD Sliding Sleave closed w/xo pups, 1 Jt - 3 1/2" 9.3 # EUE-M Tbg, Camco MMGW Injector Mandrel w/pups, 1 Jt - 3 1/2" 9.3 # EUE-M Tbg, Baker Premier Packer w/pups, 1 Jt - 3 1!2" 9.3 #EUE-M Tbg, X Nipple, 1 Jt - 31/2" 9.3 # EUE-M Tbg, Camco KBMG GLM w/DCK-2 BEK-5 shear valve w/pups, & 67 Jts - 3 1/2" 9.3 #EUE-M Tbg, Camco KBMG GLM w/dummy valves and pups, 155 jts 31/2" tbg, Camco KBMG GLM w/dummy valves and pups then 155 jts 31/2" tbg RIH to 10, 896' Page 1$ eat 2€t • Time Logs Date From To Dur S. De th E. Depth Ph~~,e Code SUbcode T COM 03/26!2008 21:15 22:15 1.00 10,896 10,896 COMPZ RPCO RURD P MU Camco SSSV and RU control line and tested same to 5,000 si. 22:15 00:00 1.75 10,896 11,710 COMPZ RPCOti PULD P Cont. to RIH with 3 1/2" completion and control line to 11,710' 03/27/2008 00:00 02:30 2.50 11,710 13,018 COMPZ RPCO6 TRIP P Cont. to RIH with 3 1/2" completion and control line to From 11,710' to 13018 - 412 'oints 02:30 02:45 0.25 13,018 13,018 COMPZ RPCO RURD P RU to run 4 1/2" tubing 02:45 03:15 0.50 13,018 13,096 COMPZ RPCOh TRIP P RIH with 2 Jts of 4 1/2", 12.6# L-80 IBTM Tubin .from 13018' to 13096' 03:15 03:30 0.25 13,096 13,096 COMPZ RPCOh SFTY P PJSM with SLB on RU & Running E line. 03:30 08:00 4.50 13,096 13,096 COMPZ RPCOh PLT P RU SLB and run GR /CCL log to_ correlate blast rings with perfs. RD SLB 08:00 10:30 2.50 13,096 13,132 COMPZ RPCO TRIP P POOH and LD 2 Jts of 4 1/2", 12.6# L-80 IBTM Tubing, Space out with 1 - 4 1/2", 12.6# L-80 IBTM 9.80' Pup Jt, 1 - 4 1/2", 12.6# L-80 IBTM 9.79' Pup Jt, & 1 - 4 1 /2", 12.6# L-80 I BTM 3.76' Pup Jt, PU and RIH 2 Jts of 4 1/2", 12.6# L-80 IBTM Tubing. MU Hanger and & control line -test to 5000 psi - ood. Land tubin 13 132'. 10:30 12:00 1.50 13,132 13,132 COMPZ RPCOh DHEQ P C/O landing jts and Installed TWC and attem ted to test han er seal -failed 12:00 14:30 2.50 13,132 13,132 COMPZ RPCOh PULD T Pull TWC ,pull hanger to floor. change out hanger, MU and test control line to 5000 psi good. Land hanger 13,132'. 14:30 15:15 0.75 13,132 13,132 COMPZ RPCOh DHEQ T C/O landing jts and Installed TWC and tested hanger seals to 5,000 psi and ck'd ok. 15:15 15:45 0.50 13,132 13,132 COMPZ RPCOh RURD P RD tbg running equip. 15:45 17:15 1.50 13,132 13,132 COMPZ RPCO NUND P ND BOP's and changed over saver sub to 5" DP. 17:15 18:30 1.25 13,132 13,132 COMPZ RPCO NUND P NU FMC tree 18:30 19:30 1.00 13,132 13,132 COMPZ RPCOh DHEQ P RU and tested tree to 5,000 psi for 10 min, ulled TWC 19:30 20:00 0.50 13,132 13,132 COMPZ RPCO RURD P RU circ lines from manifold to well and held PJSM on circ inhibited brine and diesel. 20:00 00:00 4.00 13,132 13,132 COMPZ RPCO CIRC P Circ hole and displaced well over to 9.2 ppg inhibited brine, ave 3 bpm at 600 psi then followed with 157 bbls diesel for freeze protection, final rate 2.2 bpm at 1,100 psi, shut down with 720 si on the tb . Page 19 of ZQ , Time Logs _ Date From To Dur S. Depth E. De th Phase Code Subcode T COM 03/28/2008 00:00 02:45 2.75 13,132 13,132 COMPZ RPCO DHEQ P Shut in tree and annulus, RU lubricator and drop Ball & Rod packer setting toot. Retest lines to 5000 psi (good). Pressure tubing to 4800 psi to set ackers. Test tubin to 4500 si for 30 min (good). Bleed down to 2200 psi. pressure annulus to 3500 psi or 30 min while holding 2200 psi on tubing (good). Bleed down annulus to 1000 psi -observe valve shear, bleed annulus to zero, tubing @ 800 psi - shut in tree 02:45 03:30 0.75 13,132 13,132 COMPZ RPCOh RURD P Flushed lines and blew down same, Rd circ lines and manifold. 03:30 05:00 1.50 13,132 13,132 COMPZ RPCOti OTHR P RU FMC lubricator and installed BPV, RD lubricator and secured well, SITP 800 si, IA -0-, OA -0-. 05:00 00:00 19.00 13,132 13,132 COMPZ RPCOh PULD P RU mousehole and began LD DP out of the derrick, LD 2 stds HWDP and 198 stds 4" DP 26 stds remainin 03/29/2008 00:00 02:00 2.00 13,132 13,132 COMPZ RPCOh PULD P Fin LD 26 stds of 4" DP, cleared rig floor and unloaded pipe shed. (LD a total of 2 stds HWD & 224 stds of 4" DP) RELEASED RIG 02:00 hrs 3/29/08 to move to CD3-303 F'~ge 2i~ c~ 2~ ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-118 50-103-20570-00 Definitive Survey Report 07 April, 2008 ~~ ~.. ..... w.< ...~;~;,.~. k.~.a ,~~:, ; r:~.. ._ 3 ~~ "~ ~ Sperry Drilling Services • Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-118 Wellbore: CD3-118 Design: CD3-118 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: i ~."Jell CD3-118 CD3-118 Rig @ 49.53ft (Doyon 19) CD3-118 Rig @ 49.53ft (Doyon 19) True Minimum Curvature CPAI EDM Production - ~ Project Western North Slope, 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 CD3-118 I Well Position +N/-S 0.00 ft Northing: 6,003,797.68 ft Latitude: 70° 25' 9.537 N +E/-W 0.00 ft Easting: 388,032.53 ft Longitude: 150° 54' 43.710 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 12.80 ft Wellbore CD3-118 Magnetics Model Name Sample Date Decli nation Dip Angle Field Strength 8 GM 007 ~26 "008 225 80.75 57.587 Design CD3-118 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.73 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (tt) Itt) (`) 36.73 0 00 0.00 X08.11 Survey Program Date From To Survey (ft) (tt) Survey (Wellbore) Tool Name Description Start Date 81.00 266.00 CD3-118 Gyro (CD3-118) CB-GYRO-SS (:amera based gyro single shot 04/07/2008 301.44 21,184.19 CD3-118 MWD+SAG+IIFR+CA+MS (CD3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 04/07/2008 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (tt) (`) (') (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (it) Survey Tool Name .iuJo 0.00 0.00 3V..S -11.30 O.OU O.OU 6,003,797.6H , 388,032.53 f O.uO 0.00 UNvEFINED 81.00 0.35 188.82 81.00 31.47 -0.13 -0.02 6,003,797.54 388,032.51 0.79 -0.02 CB-GYRO-SS (1) 174.00 0.50 213.40 174.00 124.47 -0.75 -0.29 6,003,796.93 388,032.23 0.25 0.04 CB-GYRO-SS (1) ~ 266.00 0.47 228.48 265.99 216.46 -1.34 -0.79 6,003,796.35 388,031.72 0.14 0.34 CB-GYRO-SS (1) I 301.44 I 0.25 183.95 301.43 251.90 -1.51 -0.91 6,003,796.18 388,031.60 0.96 0.39 MWD+IFR-AK-CAZ-SC (2) ~ 394.20 1.09 279.66 394.19 344.66 -1.57 -1.79 6,003,796.14 388,030.72 1.23 1.21 MWD+IFR-AK-CAZSC (2) 486.63 3.29 279.32 486.54 437.01 -0.99 -5.27 6,003,796.77 388,027.24 2.38 4.70 MWD+IFR-AK-CAZ-SC (2) 579.04 5.34 279.74 578.69 529.16 0.17 -12.13 6,003,798.03 388,020.40 2.22 11.58 MWD+IFR-AK-CAZ-SC (2) 669.29 6.44 277.91 668.46 618.93 1.58 -21.28 6,003,799.57 388,011.28 1.24 20.72 MWD+IFR-AK-CAZ-SC (2) 760.37 7.97 275.61 758.82 709.29 2.90 -32.63 6,003,801.06 387,999.95 1.71 31.91 MWD+IFR-AK-CAZ-SC (2) 853.41 10.55 268.78 850.64 801.11 3.35 -47.56 6,003,801.74 387,985.02 3.01 46.25 MWD+IFR-AK-CAZ-SC (2) 948.66 14.80 268.61 943.55 894.02 2.86 -68.45 6,003,801.57 387,964.13 4.46 65.95 MWD+IFR-AK-CAZ-SC (2) 1,044.06 I 16.17 268.43 1,035.48 985.95 2.20 -93.91 6,003,801.29 387,938.67 1.44 89.95 MWD+IFR-AK-CAZ-SC (2) 4/7/2008 3:52:47PM Page 2 COMPASS 2003.16 Build 42F • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD3-118 Project: Western North Slope TVD Reference: CD3-118 Rig @ 49.53ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-118 Rig @ 49.53ft(Doyon 19) Well: CD3-118 North Reference: True Wellbore: CD3-118 Survey Calculation Method: Minimum Curvature Design: CD3-118 Aatabase: CPAI EDM Production Survey Map Map Vertical MD Inc Azl TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (tt) (ft) (ft) (ft) (tt) (ft) (°1100') (ft) Survey Tool Name 1,138.40 1.8.U4 "Ld8.Y4 1,12ti.1Z 1,078.55 1.44 -120.07 b,003,b00.52 387,912.50 0.15 194.57 friWG+l~rt-Ah-Gr~L-SC (2) 1,233.64 18.51 266.52 1,217.06 1,167.53 0.12 -148.32 6,003,800.02 387,884.24 2.65 141.01 MWD+IFR-AK-CAZ-SC (2) 1,328.68 22.09 261.11 1,306.19 1,256.66 -3.56 -181.05 6,003,796.84 387,851.46 4.25 170.97 MWD+IFR-AK-CAZ-SC (2) 1,421.86 25.56 259.13 1,391.42 1,341.89 -10.06 -218.11 6,003,790.89 387,814.31 3.82 204.18 MWD+IFR-AK-CAZ-SC (2) 1,517.04 29.55 255.23 1,475.79 1,426.26 -19.92 -260.99 6,003,781.68 387,771.29 4.60 241.87 MWD+IFR-AK-CAZ-SC (2) 1,612.09 32.98 254.20 1,557.02 1,507.49 -32.94 -308.56 6,003,769.37 387,723.53 3.65 283.03 MWD+IFR-AK-CAZ-SC (2) 1,707.32 36.93 254.62 1,635.06 1,585.53 -47.59 -361.11 6,003,755.51 387,670.78 4.16 328.42 MWD+IFR-AK-CAZ-SC (2) 1,802.88 41.28 256.36 1,709.20 1,659.67 X2.65 -419.45 6,003,741.33 387,612.22 4.69 379.19 MWD+IFR-AK-CAZ-SC (2) 1,898.04 44.86 256.69 1,778.70 1,729.17 -77.78 -082.64 6,003,727.15 387,548.82 3.77 434.54 MWD+IFR-AK-CAZ-SC (2) 1,993.12 46.68 256.00 1,845.02 1,795.49 -93.87 -548.83 6,003,712.06 387,482.40 1.98 492.46 MWD+IFR-AK-CAZ-SC (2) I 2,088.05 48.82 255.23 1,908.85 1,859.32 -111.33 -616.89 6,003,695.62 387,414.09 2.33 551.72 MWD+IFR-AK-CAZ-SC (2) 2,183.41 51.07 254.59 1,970.21 1,920.68 -130.34 -687.36 6,003,677.67 387,343.35 2.41 612.78 MWD+IFR-AK-CAZ-SC (2) 2,278.04 53.35 254.42 2,028.19 1,978.66 -150.32 -759.42 6,003,658.78 387,271.01 2.41 675.06 MWD+IFR-AK-CAZ-SC (2) 2,373.54 55.96 254.40 2,083.43 2,033.90 -171.25 -834.44 6,003,638.97 387,195.68 2.73 739.86 MWD+IFR-AK-CAZ-SC (2) 2,468.93 58.98 253.40 2,134.72 2,085.19 -193.56 -911.70 6,003,617.83 387,118.11 3.29 806.35 MWD+IFR-AK-CAZ-SC (2) 2,564.02 62.57 252.65 2,181.14 2,131.61 -217.80 -991.05 6,003,594.79 387,038.40 3.84 874.24 MWD+IFR-AK-CAZ-SC (2) 2,659.20 64.07 252.09 2,223.88 2,174.35 -243.56 -1,072.10 6,003,570.25 386,956.99 1.66 943.27 MWD+IFR-AK-CAZ-SC (2) I 2,754.48 63.80 252.35 2,265.74 2,216.21 -269.69 -1,153.60 6,003,545.34 386,875.11 0.37 1,012.61 MWD+IFR-AK-CAZ-SC (2) 2,849.87 64.27 252.83 2,307.51 2,257.98 -295.35 -1,235.44 6,003,520.91 386,792.91 0.67 1,082.41 MWD+IFR-AK-CAZ-SC (2) 2,944.57 64.08 253.25 2,348.76 2,29923 -320.22 -1,316.97 6,003,497.27 386,711.02 0.45 1,152.17 MWD+IFR-AK-CAZ-SC (2) 3,039.76 61.75 253.28 2,392.10 2,342.57 -344.62 -1,398.13 6,003,474.09 386,629.51 2.45 1,221.72 MWD+IFR-AK-CAZ-SC (2) i 3,134.97 61.63 253.17 2,437.25 2,387.72 -368.81 -1,478.38 6,003,451.11 386,548.91 0.16 1,290.48 MWD+IFR-AK-CAZ-SC (2) 3,203.94 61.68 253.63 2,470.00 2,420.47 -386.15 -1,536.55 6,003,434.65 386,490.49 0.59 1,340.38 MWD+IFR-AK-CAZ-SC (2) 3,279.83 61.56 253.90 2,506.07 2,456.54 -404.82 -1,600.66 6,003,416.94 386,426.12 0.35 1,395.50 MWD+IFR-AK-CAZ-SC (2) 3,375.33 62.69 255.28 2,550.72 2,501.19 -427.25 -1,682.04 6,003,395.74 386,344.41 1.74 1,465.88 MWD+IFR-AK-CAZ-SC (2) 3,470.62 63.85 255.51 2,593.58 2,544.05 -048.71 -1,764.40 6,003,375.52 386,261.75 1.24 1,537.48 MWD+IFR-AK-CAZ-SC (2) 3,563.76 64.54 255.55 2,634.13 2,584.60 -069.66 -1,845.59 6,003,355.79 386,180.26 0.74 1,608.14 MWD+IFR-AK-CAZ-SC (2) 3,660.53 64.42 255.16 2,675.82 2,626.29 -091.74 -1,930.08 6,003,334.98 386,095.46 0.38 1,681.58 MWD+IFR-AK-CAZ-SC (2) 3,755.94 64.15 254.95 2,717.22 2,667.69 -513.91 -2,013.13 6,003,314.07 386,012.09 0.35 1,753.63 MWD+IFR-AK-CAZ-SC (2) ~ 3,850.95 63.86 254.35 2,758.86 2,709.33 -536.51 -2,095.48 6,003,292.70 385,929.41 0.64 1,824.87 MWD+IFR-AK-CAZ-SC (2) 3,946.23 63.52 254.48 2,801.09 2,751.56 -559.46 -2,177.75 6,003,270.99 385,846.82 0.38 1,895.93 MWD+IFR-AK-CAZ-SC (2) 4,041.38 63.12 255.00 2,843.81 2,794.28 -581.84 -2,259.77 6,003,249.85 385,764.48 0.64 1,966.93 MWD+IFR-AK-CAZ-SC (2) 4,136.22 63.05 255.13 2,886.74 2,837.21 -603.63 -2,341.48 6,003,229.28 385,682.46 0.14 2,037.82 MWD+IFR-AK-CAZ-SC (2) 4,231.01 62.54 253.28 2,930.08 2,880.55 -626.57 -2,422.60 6,003,207.56 385,601.01 1.82 2,107.78 MWD+IFR-AK-CAZ-SC (2) 4 326 49 62 19 253 00 2 974.37 924.84 2 -651.11 -2 503.55 6 003 184.25 385,519.71 0.45 2,177.10 MWD+IFR-AK-CAZ-SC (2) , . . . , , , , , 4,421.61 62.06 252.35 3,018.84 2,969.31 -676.14 -2,583.82 6,003,160.42 385,439.08 0.62 2,245.60 MWD+IFR-AK-CAZ-SC (2) 4,517.08 61.98 253.10 3,063.63 3,014.10 -701.18 -2,664.33 6,003,136.59 385,358.21 0.70 2,314.34 MWD+IFR-AK-CAZ-SC (2) 4,612.29 61.77 253.01 3,108.51 3,058.98 -725.65 -2,744.65 6,003,113.33 385,277.54 0.24 2,383.07 MWD+IFR-AK-CAZ-SC (2) 4,707.39 61.65 252.82 3,153.59 3,104.06 -750.26 -2,824.69 6,003,089.93 385,197.14 0.22 2,451.50 MWD+IFR-AK-CAZ-SC (2) 4,802.69 61.92 252.91 3,198.64 3,149.11 -775.00 -2,904.94 6,003,066.40 385,116.54 0.30 2,520.09 MWD+IFR-AK-CAZ-SC (2) 4/7/2008 3:52:47PM Page 3 COMPASS 2003.16 Build 42F i ~ ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordi nate Reference : `fJell CD3-118 Project: Western North Slope TVD Referenc e: CD3-118 Rig @ 49.53ft (Doyon 19) Site: CD3 Fiord Pad MD Reference: CD3-118 Rig @ 49.53ft (Doyon 19) Well: CD3-118 North Reference: True Wellbore: CD3-118 Survey Calcul ation Method: Minimum Curvature Design: CD3-118 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azl ND NDSS +N/-S +E/-W Northing Easting DLS Section (ft) (') (~) (tt) (h) (ft) (ft) (ft) (it) ("l100') (h) Survey Tool Name 4,897.42 62.42 251.73 3,242.87 3,193.34 -800.44 -2,984.76 6,U03,u42.16 "385,U3d.J5 t.zt 2,586.03 MWD+IFR-AK-CAS-S~ t[f 4,993.78 62.73 251.77 3,287.25 3,237.72 -827.23 -3,065.98 6,003,016.60 384,954.75 0.32 2,656.91 MWD+IFR-AK-CAZ-SC (2) 5,088.88 62.56 251.79 3,330.95 3,281.42 -853.64 -3,146.22 6,002,991.40 384,874.13 0.18 2,724.96 MWD+IFR-AK-CAZ-SC (2) 5,183.59 63.06 251.75 3,374.23 3,324.70 -879.99 -3,226.23 6,002,966.25 384,793.74 0.53 2,792.81 MWD+IFR-AK-CAZSC (2) 5,278.92 62.71 251.45 3,417.67 3,368.14 -906.77 -3,306.75 6,002,940.68 384,712.84 0.46 2,861.01 MWD+IFR-AK-CAZ-SC (2) 5,374.23 I 62.50 251.21 3,461.53 3,412.00 -933.86 -3,386.91 6,002,914.80 384,632.28 0.31 2,928.79 MWD+IFR-AK-CAZ-SC (2) 5,469.26 62.35 252.35 3,505.52 3,455.99 -960.20 -3,466.92 6,002,889.67 384,551.89 1.07 2,996.65 MWD+IFR-AK-CAZ-SC (2) 5,563.82 62.20 252.37 3,549.51 3,499.98 -985.56 -3,546.69 6,002,865.50 384,471.76 0.16 3,064.58 MWD+IFR-AK-CAZ-SC (2) 5,659.26 62.79 252.45 3,593.59 3,544.06 -1,011.15 -3,627.39 6,002,841.13 384,390.70 0.62 3,133.32 MWD+IFR-AK-CAZ-SC (2) 5,754.13 62.91 252.36 3,636.88 3,587.35 -1,036.66 -3,707.85 6,002,816.83 384,309.86 0.15 3,201.87 MWD+IFR-AK-CAZ-SC (2) 5,849.33 62.56 253.05 3,680.49 3,630.96 -1,061.82 -3,788.65 6,002,792.89 384,228.71 0.74 3,270.84 MWD+IFR-AK-CAZ-SC (2) 5,944.62 62.30 253.64 3,724.60 3,675.07 -1,086.03 -3,869.57 6,002,769.90 384,147.43 0.61 3,340.23 MWD+IFR-AK-CAZ-SC (2) 6,039.85 62.29 253.20 3,768.87 3,719.34 -1,110.09 -3,950.38 6,002,747.05 384,066.28 0.41 3,409.55 MWD+IFR-AK-CAZ-SC (2) 6,135.01 62.62 253.77 3,812.88 3,763.35 -1,134.07 -4,031.27 6,002,724.29 383,985.05 0.63 3,478.98 MWD+IFR-AK-CAZ-SC (2) 6,229.67 63.26 253.98 3,855.94 3,806.41 -1,157.49 -4,112.25 6,002,702.10 383,903.73 0.70 3,548.67 MWD+IFR-AK-CAZ-SC (2) 6,323.25 63.46 254.15 3,897.90 3,848.37 -1,180.45 -4,192.68 6,002,680.34 383,822.97 0.27 3,617.98 MWD+IFR-AK-CAZ-SC (2) 6,419.39 62.72 254.42 3,941.41 3,891.88 -1,203.67 -4,275.21 6,002,658.36 383,740.11 0.81 3,689.20 MWD+IFR-AK-CAZ-SC (2) 6,515.22 62.92 253.26 3,985.19 3,935.66 -1,227.40 -4,357.09 6,002,635.87 383,657.90 1.10 3,759.64 MWD+IFR-AK-CAZ-SC (2) ~ 6,610.84 63.27 252.74 4,028.46 3,978.93 -1,252.33 -0,438.63 6,002,612.17 383,576.00 0.61 3,829.39 MWD+IFR-AK-CAZ-SC (2) ~ 6,706.39 I 62.44 252.44 4,072.05 4,022.52 -1,277.77 -0,519.76 6,002,587.95 383,494.50 0.91 3,898.59 MWD+IFR-AK-CAZ-SC (2) 6,799.15 62.17 251.95 4,115.16 4,065.63 -1,302.88 -0,597.96 6,002,564.01 383,415.94 0.55 3,965.11 MWD+IFR-AK-CAZ-SC (2) 6,894.90 62.48 253.61 4,159.64 4,110.11 -1,327.98 -0,678.95 6,002,540.13 383,334.59 1.57 4,034.29 MWD+IFR-AK-CAZ-SC (2) 6,989.69 62.22 254.58 4,203.63 4,154.10 -1,350.99 -4,759.70 6,002,518.34 383,253.51 0.95 4,103.88 MWD+IFR-AK-CAZ-SC (2) ~ 7,085.09 62.79 255.30 4,247.67 4,198.14 -1,372.98 -0,841.42 6,002,497.58 383,171.48 0.90 4,174.71 MWD+IFR-AK-CAZ-SC (2) 7,179.72 62.43 255.90 4,291.20 4,241.67 -1,393.87 -0,922.80 6,002,477.91 383,089.80 0.68 4,245.57 MWD+IFR-AK-CAZ-SC (2) 7,275.03 62.71 253.77 4,335.11 4,285.58 -1,416.00 -5,004.44 6,002,457.01 383,007.85 2.01 4,316.28 MWD+IFR-AK-CAZ-SC (2) 7,368.65 62.30 252.17 4,378.34 4,328.81 -1,440.32 -5,083.84 6,002,433.89 382,928.10 1.58 4,384.19 MWD+IFR-AK-CAZ-SC (2) 7,464.66 62.65 252.72 4,422.71 4,373.18 -1,466.00 -5,165.02 6,002,409.43 382,846.55 0.63 4,453.36 MWD+IFR-AK-CAZ-SC (2) 7,559.79 62.50 253.48 4,466.52 4,416.99 -1,490.55 -5,245.81 6,002,386.10 382,765.41 0.73 4,522.52 MWD+IFR-AK-CAZ-SC (2) 7,655.23 62.15 254.85 4,510.85 4,461.32 -1,513.61 -5,327.12 6,002,364.26 382,683.77 1.32 4,592.63 MWD+IFR-AK-CAZ-SC (2) I 7,750.15 62.37 255.43 4,555.03 4,505.50 -1,535.16 -5,408.32 6,002,343.94 382,602.26 0.59 4,663.11 MWD+IFR-AK-CAZ-SC (2) 7,845.20 62.36 254.80 4,599.12 4,549.59 -1,556.79 -5,489.70 6,002,323.53 382,520.57 0.59 4,733.74 MWD+IFR-AK-CAZ-SC (2) 7,940.77 62.37 254.16 4,643.45 4,593.92 -1,579.44 -5,571.28 6,002,302.10 382,438.67 0.59 4,804.23 MWD+IFR-AK-CAZ-SC (2) 8,035.54 62.70 253.54 4,687.16 4,637.63 -1,602.83 -5,652.05 6,002,279.93 382,357.56 0.68 4,873.73 MWD+IFR-AK-CAZ-SC (2) 8,130.90 62.71 253.39 4,730.89 4,681.36 -1,626.95 -5,733.29 6,002,257.03 382,275.98 0.14 4,943.44 MWD+IFR-AK-CAZ-SC (2) 8,226.04 62.87 253.13 4,774.39 4,724.86 -1,651.32 -5,814.31 6,002,233.88 382,194.60 0.30 5,012.88 MWD+IFR-AK-CAZ-SC (2) 8,321.39 62.87 252.75 4,817.87 4,768.34 -1,676.22 -5,895.44 6,002,210.21 382,113.12 0.35 5,082.24 MWD+IFR-AK-CAZ-SC (2) 8,416.18 62.70 252.63 4,861.22 4,811.69 -1,701.30 -5,975.92 6,002,186.34 382,032.28 0.21 5,150.94 MWD+IFR-AK-CAZ-SC (2) 8,511.47 62.65 253.94 4,904.97 4,855.44 -1,725.65 x,056.99 6,002,163.21 381,950.86 1.22 5,220.43 MWD+IFR-AK-CAZ-SC (2) 8,605.82 63.13 254.17 4,947.96 4,898.43 -1,748.72 -6,137.75 6,002,141.36 381,869.77 0.55 5;290.01 MWD+IFR-AK-CAZ-SC (2) 4/7/2008 3:52:47PM Page 4 COMPASS 2003.16 Build 42F • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-or dinate Reference: vVell CD3-118 Project Western North Slope TVD Refere nce: CD3-118 Rig @ 49.53ft (Doyon 19) Site: CD3 Fiord Pad MD Referen ce: CD3-118 Rig @ 49.53ft (Doyon 19) Well: CD3-118 North Reference: True Wellbore: CD3-118 Survey Calc ulation Method: Minimum Curvature Design: CD3-118 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azl TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (') (°) (ft) (ft) itt) (ft) (ft) (ft) ('1100') (ft) Survey Tool Name 8,700.84 0.64 254.17 4,ab l.~i 4,945.74 -1,~~1.~6 -,11y.11 ~,~OZ,118.57 387,788A7 Q52 5„560.17 MWD+IFIt-AK-CAZ-SC (1) 8,796.24 62.44 253.54 5,035.26 4,985.73 -1,795.33 -6,300.43 6,002,097.20 381,706.42 0.62 5,430.14 MWD+IFR-AK-CAZ-SC (2) 8,892.00 62.45 252.48 5,079.56 5,030.03 -1,820.74 -6,381.62 6,002,073.61 381,624.88 0.98 5,499.60 MWD+IFR-AK-CAZ-SC (2) 8,987.14 62.21 251.80 5,123.74 5,074.21 -1,845.98 -6,461.82 6,002,048.98 381,544.31 0.68 5,567.79 MWD+IFR-AK-CAZ-SC (2) 9,082.36 62.72 252.65 5,167.76 5,118.23 -1,871.75 -6,542.22 6,002,024.42 381,463.53 0.96 5,636.79 MWD+IFR-AK-CAZ-SC (2) 9,182.79 63.34 253.76 5,213.31 5,163.78 -1,897.61 x,627.97 6,001,999.85 381,377.48 1.16 ,5,709.60 MWD+IFR-AK-CAZ-SC (2) 9,277.88 62.49 252.65 5,256.61 5,207.08 -1,922.07 -6,708.96 6,001,976.61 381,296.08 1.37 5,779.03 MWD+IFR-AK-CAZ-SC (2) 9,373.57 62.85 252.51 5,300.54 5,251.01 -1,947.52 -6,790.07 6,001,952.38 381,214.60 0.40 5,848.21 MWD+IFR-AK-CAZ-SC (2) 9,468.84 62.42 251.82 5,344.33 5,294.80 -1,973.43 -6,870.61 6,001,927.68 381,133.69 0.79 5,916.70 MWD+IFR-AK-CAZ-SC (2) 9,563.86 62.72 251.10 5,388.10 5,338.57 -2,000.25 -6,950.57 6,001,902.07 381,053.34 0.74 5,984.36 MWD+IFR-AK-CAZ-SC (2) 9,658.93 62.64 253.04 5,431.74 5,382.21 -2,026.25 -7,030.92 6,001,877.28 380,972.61 1.81 6,052.66 MWD+IFR-AK-CAZ-SC (2) 9,753.23 63.19 254.30 5,474.68 5,425.15 -2,049.85 -7,117.49 6,001,854.89 380,891.70 1.32 6,121.89 MWD+IFR-AK-CAZ-SC (2) 9,849.29 63.61 254.36 5,517.69 5,468.16 -2,073.05 -7,194.19 6,001,832.93 380,808.67 0.44 6,793.29 MWD+IFR-AK-CAZ-SC (2) 9,944.59 63.41 253.43 5,560.20 5,510.67 -2,096.71 -7,276.14 6,001,810.51 380,726.39 0.90 6,263.82 MWD+IFR-AK-CAZ-SC (2) 10,039.38 62.78 254.25 5,603.09 5,553.56 -2,120.24 -7,357.33 6,001,788.20 380,644.86 1.02 6,333.67 MWD+IFR-AK-CAZ-SC (2) 10,134.66 62.70 254.07 5,646.73 5,597.20 -2,143.36 -7,438.81 6,001,766.31 380,563.05 0.19 6,403.92 MWD+IFR-AK-CAZ-SC (2) 10,229.75 62.38 254.01 5,690.58 5,641.05 -2,166.56 -7,519.93 6,001,744.33 380,487.59 0.34 6,473.82 MWD+IFR-AK-CAZ-SC (2) 10,325.20 62.01 253.64 5,735.11 5,685.58 -2,190.08 -7,601.02 6,001,722.03 380,400.17 0.52 6,543.57 MWD+IFR-AK-CAZ-SC (2) 10,420.43 62.31 252.98 5,779.58 5,730.05 -2,214.26 -7,681.68 6,001,699.06 380,319.16 0.69 6,612.72 MWD+IFR-AK-CAZ-SC (2) 10,575.25 62.90 253.07 5,823.21 5,773.68 -2,238.84 -7,762.20 6,001,675.70 380,238.29 0.63 6,681.61 MWD+IFR-AK-CAZ-SC (2) 10,607.70 63.39 254.93 5,864.97 5,815.44 -2,261.57 -7,841.48 6,001,654.16 380,158.69 1.87 6,749.89 MWD+IFR-AK-CAZ-SC (2) 10,705.49 62.92 255.49 5,909.13 5,859.60 -2,283.85 -7,925.84 6,001,633.16 380,074.01 0.70 6,823.15 MWD+IFR-AK-CAZ-SC (2) 10,800.62 62.72 254.89 5,952.59 5,903.06 -2,305.48 -8,007.65 6,001,612.76 379,991.89 0.60 6,894.18 MWD+IFR-AK-CAZ-SC (2) 10,895.49 61.88 254.11 5,996.69 5,947.16 -2,327.92 -8,088.59 6,001,591.53 379,910.63 1.15 6,964.14 MWD+IFR-AK-CAZ-SC (2) i 10,989.91 62.56 252.36 6,040.70 5,991.17 -2,352.02 -8,168.57 6,001,568.64 379,830.30 1.79 7,032.66 MWD+IFR-AK-CAZ-SC (2) 11,085.14 62.09 251.95 6,084.93 6,035.40 -2,377.86 -8,248.85 6,001,544.00 379,749.65 0.62 7,100.93 MWD+IFR-AK-CAZ-SC (2) 11,180.46 62.21 251.49 6,129.46 6,079.93 -2,404.30 -8,328.88 6,001,518.77 379,669.24 0.44 7,168.77 MWD+IFR-AK-CAZ-SC (2) 11,275.66 62.62 252.40 6,173.54 6,124.01 -2,430.45 -8,409.10 6,001,493.83 379,588.65 0.95 7,236.89 MWD+tFR-AK-CAZ-SC (2) 11,370.77 63.05 253.34 6,216.96 6,167.43 -2,455.37 -8,489.96 6,001,470.13 379,507.42 0.99 7,306.00 MWD+IFR-AK-CAZ-SC (2) 11,465.89 62.44 253.42 6,260.53 6,211.00 -2,479.56 -8,570.99 6,001,447.16 379,426.05 0.65 7,375.49 MWD+IFR-AK-CAZ-SC (2) I 11,561.09 62.99 257.34 6,304.18 6,254.65 -2,500.90 -8,652.84 6,001,427.05 379,343.90 3.70 7,446.65 MWD+IFR-AK-CAZ-SC (2) 17,655.22 63.49 260.69 6,346.57 6,297.04 -2,516.91 -8,735.33 6,001,412.28 379,261.18 3.22 7,520.08 MWD+IFR-AK-CAZ-SC (2) 11,751.29 63.27 261.02 6,389.62 6,340.09 -2,530.56 -8,820.12 6,001,399.91 379,176.20 0.38 7,596.43 MWD+IFR-AK-CAZ-SC (2) 11,846.55 64.37 261.96 6,431.65 6,382.12 -2,543.20 -8,904.67 6,001,388.53 379,091.48 1.46 7,672.85 MWD+IFR-AK-CAZ-SC (2) 11,941.70 64.97 265.62 6,472.37 6,422.84 -2,552.50 -8,990.15 6,007,380.52 379,005.88 3.53 7,751.21 MWD+IFR-AK-CAZ-SC (2) 12,036.74 65.53 269.53 6,512.17 6,462.64 -2,556.14 -9,076.36 6,001,378.17 378,919.64 3.78 7,832.01 MWD+IFR-AK-CAZ-SC (2) 12,131.84 65.93 273.14 6,551.27 6,501.74 -2,554.72 -9,163.01 6,001,381.49 378,833.03 3.49 7,915.00 MWD+IFR-AK-CAZ-SC (2) 12,226.66 66.80 277.02 6,589.29 6,539.76 -2,546.42 -9,249.51 6,001,390.49 378,746.66 3.86 7,999.61 MWD+IFR-AK-CAZ-SC (2) 12,322.21 67.82 281.34 6,626.17 6,576.64 -2,532.35 -9,336.51 6,001,405.86 378,659.89 4.31 8,086.67 MWD+IFR-AK-CAZ-SC (2) 12,417.45 68.73 285.97 6,661.44 6,611.91 -2,511.46 -9,422.45 6,001,428.04 378,574.28 4.62 8,174.85 MWD+IFR-AK-CAZ-SC (2) 4/7/2008 3:52:47PM Page 5 COMPASS 2003.16 Build 42F Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-118 Wellbore: CD3-118 Design: CD3-118 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: MD Inc Azi ND TVDSS +Nl-S ift) O (~) (ft) (n) (n) 12,51z.7Y 70.13 250.37 6,b94.b2 o,ti45s9 -Z,4b3.54 12,608.14 71.62 295.11 6,726.20 6,676.67 -2,448.78 12,703.28 72.67 298.41 6,755.38 6,705.85 -2,408.01 12,796.19 73.56 301.82 6,782.37 6,732.84 -2,363.41 12,889.33 74.66 305.96 6,807.88 6,758.35 -2,313.46 12,981.39 76.37 308.99 6,830.91 6,781.38 -2,259.23 13,073.76 78.90 311.01 6,850.69 6,801.16 -2,201.24 13,165.08 80.16 311.45 6,867.29 6,817.76 -2,142.05 13,258.13 80.35 312.34 6,883.04 6,833.51 -2,080.82 13,351.01 81.23 315.11 6,897.91 6,848.38 -2,017.45 13,445.44 80.78 319.94 6,912.68 6,863.15 -1,948.68 13,492.18 80.97 320.71 6,920.09 6,870.56 -1,913.16 13,538.51 82.96 322.78 6,926.57 6,877.04 -1,877.14 13,586.00 83.71 323.45 6,932.08 6,882.55 -1,839.41 13,631.93 83.77 324.67 6,937.09 6,887.56 -1,802.45 13,678.52 84.83 325.67 6,941.71 6,892.18 -1,764.40 13,775.97 87.89 328.29 6,947.90 6,898.37 -1,682.86 13,874.62 87.58 331.19 6,951.80 6,902.27 -1,597.73 13,969.53 87.95 332.42 6,955.50 6,905.97 -1,514.15 14,064.86 88.26 334.42 6,958.66 6,909.13 -1,428.95 14,159.95 91.47 336.05 6,958.88 6,909.35 -1,342.61 14,255.19 93.57 336.40 6,954.69 6,905.16 -1,255.55 14,349.86 93.70 337.93 6,948.69 6,899.16 -1,168.47 14,445.33 92.15 337.89 6,943.82 6,894.29 -1,080.13 14,540.43 92.52 337.24 6,939.94 6,890.41 -992.30 14,636.00 89.81 336.76 6,938.00 6,888.47 -904.36 14,731.52 90.85 337.04 6,937.45 6,887.92 -816.50 14,826.65 91.60 338.51 6,935.42 6,885.89 -728.46 14,922.12 90.79 337.98 6,933.43 6,883.90 X39.81 15,017.63 90.79 335.78 6,932.11 6,882.58 -551.98 15,112.98 91.66 333.24 6,930.07 6,880.54 -465.94 15,208.22 90.79 334.77 6,928.03 6,878.50 -380.36 15,303.77 91.72 336.22 6,925.94 6,876.41 -293.44 15,398.75 91.60 337.62 6,923.19 6,673.66 -206.10 15,494.42 91.66 338.71 6,920.47 6,870.94 -117.33 15,589.80 92.03 339.64 6,917.40 6,867.87 -28.23 15,685.13 93.51 336.76 6,912.79 6,863.26 60.17 15,780.45 89.93 332.92 6,909.93 6,860.40 146.37 15,630.62 86.82 334.02 6,910.47 6,860.94 191.26 15,875.86 91.97 334.88 6,910.16 6,860.63 232.07 Map +E/-W Northing (ft) (ft) -9,5ui.1o 5,OU1,457.12 -9,590.27 6,001,493.21 -9, 671.11 6, 001, 53 5.19 -9,748.00 6,001,580.94 -9,822.34 6,001,631.99 -9,893.06 6,001,687.27 -9,962.16 6,001,746.29 -10,029.69 6,001,806.47 -10,097.96 6,001,868.72 -10,164.20 6,001,933.07 -10,227.17 6,002,002.77 -10,256.63 6,002,038.72 -10,285.03 6,002,075.16 -10,313.34 6,002,113.31 -10,340.14 6,002,150.67 -10, 366.61 6, 002,189.11 -10,419.60 6,002,271.42 -10,469.26 6,002,357.28 -10,514.07 6,002,441.52 -10,556.70 6,002,527.34 -10,596.53 6,002,614.25 -10,634.88 6,002,701.88 -10,671.55 6,002,789.48 -10,707.40 6,002,878.35 -10,743.67 6,002,966.70 -10,781.00 6,003,055.19 -10,818.47 6,003,143.60 -10,854.45 6,003,232.16 -10,889.82 6,003,321.32 -10,927.32 6,003,409.69 -10,968.34 6,003,496.33 -11,010.07 6,003,582.52 -11,049.69 6,003,670.02 -11, 086.91 6, 003, 757.90 -11,122.48 6,003,847.18 -11,156.37 6,003,936.77 -11,191.72 6,004,025.68 -11,232.22 6,004,112.48 -11,254.63 6,004,157.69 -11,274.13 6,004,198.78 Well CD3-118 CD3-118 Rig @ 49.53ft (Doyon 19) CD3-118 Rig @ 49.53ft (Doyon 19) True Minimum Curvature CPAI EDM Production Map Vertical Fasting DLS Section (ft) (°1100') (ft) Survey Tool Name 378,490.00 4.57 8,264.u1 MWD+IFR-AK-GAZ-SC (2) 378,407.43 4.95 8,353.84 MWD+IFR-AK-CAZ-SC (2) 378,327.22 3.48 8,443.35 MWD+IFR-AK-CAZ-SC (2) 378,251.02 3.64 8,530.29 MWD+IFR-AK-CAZ-SC (2) 378,177.44 4.44 8,616.47 MWD+IFR-AK-CAZ-SC (2) 378,107.55 3.69 8,700.55 MWD+IFR-AK-CAZ-SC (2) 378,039.33 3.47 8,784.26 MWD+IFR-AK-CAZ-SC (2) 377,972.70 1.46 8,866.84 MWD+IFR-AK-CAZ-SC (2) 377,905.37 0.96 8,950.76 MWD+IFR-AK-CAZ-SC (2) 377,840.08 3.09 9,033.42 MWD+IFR-AK-CAZ-SC (2) 377,778.16 5.07 9,114.64 MWD+IFR-AK-CAZ-SC (2) 377,749.24 1.68 9,153.69 MWD+IFR-AK-CAZ-SC (2) 377,721.39 6.17 9,191.88 MWD+IFR-AK-CAZ-SC (2) 377,693.65 2.11 9,230.52 MWD+IFR-AK-CAZ-SC (2) 377,667.41 2.64 9,267.48 MWD+IFR-AK-CAZ-SC (2) 377,641.51 3.12 9,304.47 MWD+IFR-AK-CAZ-SC (2) 377,589.76 4.13 9,380.17 MWD+IFR-AK-CAZ-SC (2) 377,541.38 2.95 9,453.85 MWD+IFR-AK-CAZ-SC (2) 377,497.83 1.35 9,522.42 MWD+IFR-AK-CAZ-SC (2) 377,456.49 2.12 9,589.42 MWD+IFR-AK-CAZ-SC (2) 377,417.97 3.79 9,654.11 MWD+IFR-AK-CAZ-SC (2) 377,380.92 2.24 9,717.63 MWD+IFR-AK-CAZ-SC (2) 377,345.57 1.62 9,779.55 MWD+IFR-AK-CAZ-SC (2) 377,311.05 1.62 9,841.09 MWD+IFR-AK-CAZ-SC (2) 377,276.11 0.79 9,902.86 MWD+IFR-AK-CAZ-SC (2) 377,240.11 2.88 9,965.68 MWD+IFR-AK-CAZ-SC (2) 377,203.96 1.13 10,028.61 MWD+IFR-AK-CAZ-SC (2) 377,169.31 1.73 10,090.17 MWD+IFR-AK-CAZ-SC (2) 377,135.27 1.01 10,151.36 MWD+IFR-AK-CAZ-SC (2) 377,099.10 2.30 10,214.30 MWD+IFR-AK-CAZ-SC (2) 377,059.38 2.82 10,280.03 MWD+IFR-AK-CAZ-SC (2) 377,018.94 1.85 10,346.30 MWD+IFR-AK-CAZ-SC (2) 376,980.63 1.80 10,410.98 MWD+IFR-AK-CAZ-SC (2) 376,944.73 1.48 10,473.51 MWD+IFR-AK-CAZ-SC (2) 376,910.50 1.14 10,534.91 MWD+IFR-AK-CAZ-SC (2) 376,877.95 1.05 10,594.82 MWD+IFR-AK-CAZ-SC (2) 376,843.93 3.39 10,655.90 MWD+IFR-AK-CAZ-SC (2) 376,804.73 5.51 10,721.19 MWD+IFR-AK-CAZ-SC (2) 376,783.00 3.11 10,756.44 MWD+IFR-AK-CAZ-SC (2) 376,764.11 7.22 10,787.67 MWD+IFR-AK-CAZ-SC (2) 4/7/2008 3:52:47PM Page 6 COMPASS 2003.18 Build 42F ~ i ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-or dinate Re#erence: Well CD3-118 Project: Western North Slope ND Refere nce: CD3-118 Rig @ 49.53ft (Doyon 19) Sife: CD3 Fiord Pad MD Referen ce: CD3-118 Rig @ 49.53ft (Doyon 19) Well: CD3-118 North Reference: True Wellbore: CD3-118 Survey Calc ulation Method: Minimum Curvature Design: CD3-118 =,,,Datahase: CPAI EDM Production Survey Map Map Vertical MD Inc Azl ND NDSS +N/-S +E/-W Northing Easting DLS Section (ftJ (°) (°) In) (ft) (ft) (ft) (ft) (ft) ('/100') (ft) Survey Tool Name 15,916.99 51.9/ 336.Y3 6,9u8.4U 0,tt5b.tl7 270.00 -11,195.[0 6,004,245.61 370,743.07 2.64 10,822.23 MWD+IFR-AK-GAZ-SG (2) 15,971.40 90.67 338.78 6,907.38 6,857.85 319.60 -11,312.27 6,004,286.87 376,727.30 6.44 10,851.12 MWD+IFR-AK-CAZ-SC (2) i 16,020.74 89.06 337.82 6,907.50 6,657.97 365.44 -11,330.51 6,004,332.98 376,709.75 3:80 10,882.71 MWD+IFR-AK-CAZ-SC (2) 16,066.72 90.18 336.46 6,907.80 6,858.27 407.81 -11,348.37 6,004,375.60 376,692.53 3.83 10,912.86 MWD+IFR-AK-CAZ-SC (2) 16,161.94 90.11 336.04 6,907.56 6,858.03 494.96 -11,386.72 6,004,463.32 376,655.49 0.45 10,976.40 MWD+IFR-AK-CAZ-SC (2) 16,257.61 90.24 337.90 6,907.27 6,857.74 583.00 -11,424.14 6,004,551.90 376,679.39 1.95 11,039.34 MWD+IFR-AK-CAZ-SC (2) 16,352.97 90.18 338.21 6,906.92 6,857.39 671.45 -11,459.78 6,004,640.87 376,585.09 0.33 11,100.71 MWD+IFR-AK-CAZ-SC (2) 16,448.34 90.30 337.21 6,906.52 6,856.99 759.69 -11,495.95 6,004,729.64 376,550.25 1.06 11,162.52 MWD+IFR-AK-CAZ-SC (2) 16,543.28 88.45 335.95 6,907.56 6,858.03 846.80 -11,533.68 6,004,817.29 376,513.83 2.36 11,225.46 MWD+IFR-AK-CAZ-SC (2) 16,638.71 88.14 336.19 6,910.40 6,860.87 933.99 -11,572.38 6,004,905.04 376,476.46 0.41 11,289.34 MWD+IFR-AK-CAZ-SC (2) 16,734.59 89.13 336.36 6,912.68 6,863.15 1,021.74 -11,610.94 6,004,993.35 376,439.21 1.05 11,353.27 MWD+IFR-AK-CAZ-SC (2) 16,829.86 87.83 337.73 6,915.21 6,865.68 1,109.43 -11,648.08 6,005,081.59 376,403.39 1.98 11,415.84 MWD+IFR-AK-CAZ-SC (2) 16,924.80 88.76 336.40 6,918.03 6,868.50 1,196.82 -11,685.06 6,005,169.52 376,367.73 1.71 11,478.15 MWD+IFR-AK-CAZ-SC (2) 77,020.30 87.83 331.18 6,920.88 6,871.35 1,282.44 -11,727.21 6,005,255.74 376,326.88 5.55 11,544.82 MWD+IFR-AK-CAZ-SC (2) 17,073.35 89.50 331.27 6,922.71 6,872.58 1,328.92 -11,752.74 6,005,302.60 376,302.05 3.15 11,583.54 MWD+IFR-AK-CAZ-SC (2) I 17,115.38 91.53 333.02 6,921.73 6,872.20 1,366.08 -11,772.37 6,005,340.04 376,282.98 6.38 11,613.75 MWD+IFR-AK-CAZ-SC (2) 17,164.33 90.36 332.52 6,920.93 6,871.40 1,409.60 -11,794.76 6,005,383.89 376,261.24 2.60 11,648.56 MWD+IFR-AK-CAZ-SC (2) 17,210.70 90.79 333.36 6,920.46 6,870.93 1,450.89 -11,815.86 6,005,425.49 376,240.77 2.03 11,681.45 MWD+IFR-AK-CAZ-SC (2) 17,306.47 88.76 334.68 6,920.84 6,871.31 1,536.97 -71,857.81 6,005,512.19 376,200.12 2.53 11,748.06 MWD+IFR-AK-CAZ-SC (2) 17,401.67 89.50 335.20 6,922.28 6,872.75 1,623.20 -11,898.13 6,005,599.00 376,161.11 0.95 11,813.21 MWD+IFR-AK-CAZ-SC (2) 17,497.06 90.11 334.22 6,922.61 6,873.08 1,709.45 -11,938.88. 6,005,685.84 376,121.66 1.21 11,878.75 MWD+IFR-AK-CAZ-SC (2) 17,590.13 90.55 330.40 6,922.07 6,872.54 1,791.84 -11,982.12 6,005,768.87 376,079.66 4.13 11,945.46 MWD+IFR-AK-CAZ-SC (2) ~ 77,686.03 90.11 326.60 6,921.52 6,871.99 1,873.59 -12,032.21 6,005,851.35 376,030.80 3.99 12,018.49 MWD+IFR-AK-CAZ-SC (2) 17,782.99 90.98 325.24 6,920.60 6,871.07 1,953.89 -12,086.54 6,005,932.45 375,977.69 1.67 12,095.09 MWD+IFR-AK-CAZ-SC (2) 17,878.72 91.35 322.15 6,918.65 6,869.12 2,031.01 -12,143.20 6,006,010.41 375,922.20 3.25 12,172.92 MWD+IFR-AK-CAZ-SC (2) 17,974.43 90.85 320.89 6,916.81 6,867.28 2,105.92 -12,202.74 6,006,086.20 375,863.79 1.42 12,252.79 MWD+IFR-AK-CAZ-SC (2) 18,069.00 92.46 320.33 6,914.08 6,864.55 2,178.98 -12,262.73 6,006,160.14 375,804.91 1.80 12,332.52 MWD+IFR-AK-CAZ-SC (2) 18,164.32 91.41 316.14 6,910.86 6,861.33 2,250.02 -12,326.17 6,006,232.11 375,742.55 4.53 12,414.90 MWD+IFR-AK-CAZ-SC (2) ~ 18,259.79 90.24 315.55 6,909.49 6,859.96 2,318.50 -12,392.67 6,006,301.58 375,677.09 1.37 12,499.39 MWD+IFR-AK-CAZ-SC (2) 18,355.43 91.60 316.61 6,907.95 6,858.42 2,387.38 -12,459.00 6,006,371.44 375,611.81 1.80 12,583.85 MWD+IFR-AK-CAZ-SC (2) 18,450.74 91.97 317.87 6,904.98 6,855.45 2,457.32 -12,523.67 6,006,442.34 375,548.19 1.38 12,667.06 MWD+IFR-AK-CAZSC (2) I 18,546.11 I 91.16 319.39 6,902.38 6,852.85 2,528.87 -12,586.68 6,006,514.82 375,486.27 1.81 72,749.19 MWD+IFR-AK-CAZ-SC (2) 18,641.57 91.10 319.90 6,900.49 6,850.96 2,601.60 -12,648.48 6,006,588.46 375,425.58 0.54 12,830.53 MWD+IFR-AK-CAZ-SC (2) 18,737.19 90.86 319.79 6,898.86 6,849.33 2,674.67 -12,710.13 6,006,662.44 375,365.03 0.28 12,911.85 MWD+IFR-AK-CAZ-SC (2) 18,832.29 90.92 319.04 6,897.38 6,847.85 2,746.88 -12,771.99 6,006,735.57 375,304.27 0.79 12,993.09 MWD+IFR-AK-CAZ-SC (2) 18,927.96 89.62 318.79 6,896.93 6,847.40 2,818.99 -12,834.86 6,006,808.60 375,242.49 1.38 13,075.26 MWD+IFR-AK-CAZ-SC (2) 19,022.70 90.73 318.40 6,896.64 6,847.11 2,890.05 -12,897.52 6,006,880.59 375,180.91 1.24 13,156.91 MWD+IFR-AK-CAZ-SC (2) 19,118.44 89.87 317.91 6,896.14 6,846.61 2,961.37 -12,961.39 6,006,952.85 375,118.12 1.03 13,239.78 MWD+IFR-AK-CAZ-SC (2) 19,213.84 89.68 319.42 6,896.57 6,846.98 3,033.00 -13,024.39 6,007,025.41 375,056.21 1.60 13,321.93 MWD+IFR-AK-CAZ-SC (2) I 19,309.24 89.74 319.87 6,897.00 6,847.47 3,105.70 -13,086.17 6,007,099.02 374,995.53 0.48 13,403.25 MWD+IFR-AK-CAZ-SC (2) 4/7/2008 3:52:47PM Page 7 COMPASS 2003.16 Build 42F • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-118 Wellbore: CD3-118 Design: CD3-118 Survey MD Inc [n) l`) 19,404.19 y0.24 19,499.36 91.16 19,594.45 91.23 19,689.54 90.73 19,785.02 90.85 19, 880.16 89.81 19,975.39 90.30 20,072.25 90.30 ~ 20,167.44 90.24 20,261.64 90.30 20,357.00 89.62 20,452.43 89.93 20,547.53 89.44 20,642.81 89.81 20,735.52 89.87 20,833.36 90.79 20,928.35 92.03 21,023.60 91.72 21,118.67 90.79 21,184.19 92.64 • 21,228.00 92.64 Azl 319.65 320.09 319.98 320.54 320.08 317.58 317.46 318.90 319.54 320.55 319.55 318.58 318.62 319.43 320.14 320.87 322.04 321.34 319.40 321.08 321.08 TVD TVDSS (n) (n) 6,897.01 6,847.48 6,895.85 6,846.32 6,893.87 6,844.34 6,892.24 6,842.71 6,890.93 6,841.40 6,890.38 6,840.85 6,890.29 6,840.76 6,889.78 6,840.25 6,889.33 6,839.80 6,888.89 6,839.36 6,888.95 6,839.42 6,869.33 6,839.80 6,889.85 6,840.32 6,890.47 6,840.94 6,890.73 6,841.20 6,890.17 6,840.64 6,887.83 6,838.30 6,884.72 6,835.19 6,882.63 6,833.10 6,880.67 6,831.14 6,878.65 ( 6,829.12 +N/-S ln) 3,178.18 3,250.93 3,323.80 3,396.91 3,470.37 3,541.98 3,612.22 3,684.40 3,756.48 3,828.68 3,901.79 3,973.88 4,045.21 4,117.14 4,187.94 4,263.44 4,337.71 4,412.41 4,485.60 4,535.95 4,569.99 Local Co-ordinate Reference: Well C03-118 ND Reference: CD3-118 Rig @ 49.53ft (Doyon 19) MD Reference: CD3-118 Rig @ 49.53ft (Doyon 19) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production +E/-W (ft) -13,147.50 -13,208.84 -13,269.90 -13,330.68 -13,391.65 -13,454.28 -13,518.59 -13,583.17 -13,645.35 -13,705.84 -13,767.07 -13,829.59 -13,892.48 -13,954.96 -14,014.82 -14,077.04 -14,136.21 -14,195.23 -14,255.85 -14,297.73 -t 4,325.23 Map Map Vertical Northing Easting DLS Section (ft) (ft) (°1100') (tt) Survey Tool Name 6,uv7,172.41 374,935.30 0.58 13,484.07 MWD+{FR-AK-CAZ-SG (2) 6,007,246.07 374,875.07 1.07 13,564.99 MWD+IFR-AK-CAZ-SC (2) 6,007,319.84 374,815.11 0.14 13,645.68 MWD+IFR-AK-CAZ-SC (2) 6,007,393.84 374,755.43 0.79 13,726.18 MWD+IFR-AK-CAZ-SC (2) 6,007,468.21 374,695.58 0.50 13,806.97 MWD+IFR-AK-CAZ-SC (2) 6,007,540.74 374,634.04 2.85 13,888.75 MWD+IFR-AK-CAZ-SC (2) 6,007,611.93 374,570.79 0.53 13,971.71 MWD+IFR-AK-CAZ-SC (2) 6,007,685.06 374,507.31 1.49 14,055.53 MWD+IFR-AK-CAZ-SC (2) 6,007,758.06 374,446.23 0.68 14,137.03 MWD+IFR-AK-CAZ-SC (2) 6,007,831.16 374,386.83 1.07 14,216.97 MWD+IFR-AK-CAZ-SC (2) 6,007,905.17 374,326.71 1.27 14,297.89 MWD+IFR-AK-CAZ-SC (2) 6,007,978.18 374,265.28 1.07 14,379.73 MWD+IFR-AK-CAZ-SC (2) 6,008,050.44 374,203.47 0.52 14,461.68 MWD+IFR-AK-CAZ-SC (2) 6,008,123.30 374,142.08 0.93 14,543.42 MWD+IFR-AK-CAZ-SC (2) 6,008,194.98 374,083.30 0.77 14,622.32 MWD+IFR-AK-CAZ-SC (2) 6,008,271.40 374,022.22 1.20 14,704.94 MWD+IFR-AK-CAZ-SC (2) 6,008,346.54 373,964.17 1.79 14,784.26 MWD+IFR-AK-CAZ-SC (2) 6,008,422.11 373,906.29 0.80 14,863.57 MWD+IFR-AK-CAZ-SC (2) 6,008,496.20 373,846.78 2.26 14,943.95 MWD+IFR-AK-CAZ-SC (2) 6,008,547.16 373,805.66 3.81 14,999.40 MWD+IFR-AK-CAZ-SC (2) 6,008,581.61 373,778.68 . 0.00 15,036.12 PROJECTED to TD 4/7/2008 3:52:47PM Page 8 COMPASS 2003.16 Build 42F C D3-118 ao~--®~--~" Information ~~,~~~~ ~ 9 ~~ ~,~;~ ~~.~~ ~c~ ~ ~ rc~ ~ CD3-118 9 5/8" Surface Casing Detail Well: CD3-118 9 5/8" 40 f t-80 BTC-M Casin Date: 311/2008 Co11QCaPhillips Rig: Doyon 19 Alaska, Inc. Depth Jt Number Joints Well Equipment Description and Comments Page 1 Length Tops Top of Strin or Top of Flan e Doyon 19 RKB to Landing Ring 36.20 ' FMC Gen V Hanger 2.22 36.20 Jts 3 to 83 81 Jts 9-5/8" 40# L-80 BTC-M Csg 3123.97 38.42 HOWCO Float Collar 1.21 3162.39 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC-M Csg 78.07 3163.60 Ray Oil Tools "Silver Bullet" Float Shoe 2.20 3241.67 9 518" Shoe @ 3243.87 Casing shoe @ 3244' MD / 2489' TVD 3243.87 Hole TD @ 3,254' MD / 2,394' TVD 3243.87 3243.87 3243.87 TOTAL BOWSPRING CENTRALIZERS -46 3243.87 3243.87 1 per jt on Jt # 1 - # 13 (stop ring on Jt # 1 8~ 3) 3243.87 and aver collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 3243.87 33, 35, 37, 39, 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 3243.87 65, 67,69, 71,73, 75, 77, 79, 81 3243.87 3243.87 3243.87 3243.87 3243.87 3243.87 3243.87 • 3243.87 • 3243.87 3243.87 s 3243.87 3243.87 3243.87 3243.87 3243.87 3243.87 Use Best-o-Life 2000 pipe dope 3243.87 3243.87 MU torgue _ 8800 ft/Ibs 3243.87 Remarks: Up Wt 165 K Dn Wt 130 K Block Wt 70 K Supervisors: Mickey /Wilson /Dexter r~ >~ ~ Cement Detail Report ~, CD3-118 SurFace Casing Cement _ ~. __ _ __ - ___ _~ _ _ _ 'Cement Details 1 __, __. _ - Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 3/1/2008 00:00 CD3-118 Comment Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/ nut plug as marker, switched to Dowell and pumped 5 bbls water. Pressure tested lines to 4000 psi. Dropped btm plug and Pumped 50 bbls MudPush @ 10.5 ppg @ 400 psi @ 6 bbls/min -Mixed ~ pumped 404 bbls lead slurry (ASL) @ 10.7 ppg @ 7.6 bbls/min @ 400 psi (" Observed nut plu g marker @ shakers w/ 378 bbls lead pumped -pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg, @ 4.8 bpm at 380 psi. Dropped top plug w/ 20 bbls water f/ Dowell. Switched over to rig pumps & displaced cmt w/ 219.8 bbls 9.8 ppg water base mud. Displaced @ 7.0 bbls/m in for first 189.8 bbts then slowed to 3.5 bbls/min for last 30 bbls. Bumped plug w/ 1050 psi (pre bump pressure 560 psi.) Check float (held OK) CIP @ hrs. H ad full circulation throughout job w/ 110 bbls 10.7 ppg cmt returns to surface. Rec~roceted pipe while circ~teting & through cement job. 'Cement Stages e r?> Stage # <Stage Numb __ _ _ _ T _ _ _ Description Objective __ Btm Plug? Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Surface Casing Cement 0.0 3,244.0 Yes 110.0 Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 550.0 1,050.0 Yes No Depth tagged (ftKB) Tag M ethod Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment - -- ,Cement Fluids 8 Additives - Fluid __ - -- _ _ - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 0.0 2,744.0 489 ASL 4t#4a) Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.70 10.70 Additives Additive Type Concentration Conc Unit label Antifoam D043 %BWOC Additive Type Concentration Conc Unit label Freeze Suppressant D044 %BWOW Additive Type Concentration Conc Unit label Thixotropic D053 %BWOC Additive Type Concentration Conc Unit label Extender D079 %BWOC Additive Type Concentration Conc Unit label Extender D124 %BWOC Additive Type Concentration Conc Unit label Acelerator (Calcium Chloride) _._ _ S001 %BWOC _ !.Fluid Fluid Type ~ Fluid Description ' Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,744.0 3,244.0 234 G '~~~ 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 15.80 Additives Additive Type Concentration Conc Unit label Antifoam D046 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 %BWOC Additive Type Concentration Conc Unit label Accelerator S001 %BWOC Page 1/1 Report Printed: 3/17/2008 r~ Security Level: Development Daily Drilling Report CD3-118 Report Number: 6 Rig: DOYON 19 Report Date: 3/1/2008 AFE Type NetworWlD # ; Total AFE+Sup _ 10211431 9,369,999.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-118 Development FIORD NECHELIK 4.06 6.0 0.00 3,254.0 3,254.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 8,061.63 57,208.06 278,354.63 1,584,657.06 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/25/2008 2/26/2008 28.90 Last Casing String Next Casing OD (in) Neat Casing Set Depth (ftKB) Surface, 3,244.OftK6 Ops and Depth @ Morning Report 24hr Forecast PU & Standing back 5" DP Std back 5" DP, test BOP's, MU 8 3/4" BHA ~ RIH, test csg drill out & perform LOT Last 24hr Summary Cont. RIH w/ 9 5!8" i;< landed same @ 3,244' w/no problems, circ & cond hole & cemented same w/110 bbls of cmt back, ND riser & NU BOP stack, LD excess 4" DP out of the derrick , RU to PU 5" DP General Remarks Weather Head Count -36 deg, WC -63, Clear, Wind NE @ 12 mph 46.0 Don Mickey, Rig Supervisor Supervisor Rig Supervisor Title ' Peter Wilson, Rig Supervisor Rig Supervisor Randy Dexter, Rig Supervisor Rig Supervisor _ Time Lo~ _ _ ~, Star4 End Dur Time ~ Depth Start Depth End ? Time Time (hrs) Phase Op Code ~ OpSub-Code P-N-T Trbl Code Trbl Class (ftKB) _ __. - -- (ftKB) Operation ---- T- - -_.. - - - --- 00:00 02:15 2.25 SURFAC -... _ CASING RNCS P 1,627.0 3,244.0 Cont. to RIH with 41 jts 9-5/8" BTC-M csg, (83 total jts) MU FMC fluted Hgr and Landing joint, land csg hanger on landing ring with shoe at 3,244', & float collar @ 3162'. st wt up 190K do wt 130K 02:15 02:45 0.50 SURFAC CASING RURD P 3,244.0 3,244.0 LD Franks fill up tool and blow down top drive, MU Dowell cement head and lines. 02:45 05:15 2.50 SURFAC CEMENT CIRC P 3,244.0 3,244.0 Circ and condition mud for cementing, establish circulation at 2 bpm at 250 staging pump rate up to 7 bpm @ 330 psi. Held PJSM for csg cement job. St wt up 165K, do wt 130K, mud properties before /after: 10.1/9.85 ppg, 300/56 Vis, 23/20 PV, 70/19 YP, 05:15 05:30 0.25 SURFAC CEMENT SFTY P 3,244.0 3,244.0 PJSM for Cement job Latest BOP Test Data _ i Date ~ - -- Comment ! Page 1/3 Report Printed: 3/17/2008 >~ Security Level: Development Daily Drilling Report CD3-118 Report Number: 6 Rig: DOYON 19 Report Date: 3/1/2008 -- Time Lo Start Time End i Time ~ Dur {hrs) hase p Code pSub-Code 7(me P-N-T - T~hl Code rbl Class_ Depth Start (ftKB) -- Depth Endue (ftKB) ~ _ ____ - Operation 05:30 08:15 2.75 SURFAC CEMENT DISP P 3,244.0 3,244.0 Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/ nut plug as marker, switched to Dowell and pumped 5 bbls water. Pressure tested lines to 4000 psi. Dropped btm plug and Pumped 50 bbls MUD PUSH @ 10.5 ppg @ 400 psi @ 6 bbls/min -Mixed & pumped 404 bbls lead slurry (ASL) @ 10.7 ppg @ 7.6 bbls/min @ 400 psi (' Observed nut plug marker @ shakers w/ 378 bbls lead pumped -pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg, @ 4.8 bpm at 380 psi. Dropped top plug w/ 20 bbls water f/ Dowell. Switched over to rig pumps & displaced cmt w/ 219.8 bbls 9.8 ppg water base mud. Displaced @ 7.0 bbls/min for first 189.8 bbls then slowed to 3.5 bbls/min for last 30 bbls. Bumped plug w/ 1050 psi (pre bump pressure 560 psi) Check float (held OK) CIP @ 0800 hrs. Had full circulation throughout job w/ 110 bbls 10.7 ppg cmt returns to surface. Reciprocated pipe while circulating & through cement job until beginning of tail. 08:15 08:30 0.25 SURFAC CEMENT SFEQ P 3,244.0 3,244.0 RU and test 9 518" casing to 3,500 psi for 30 Min. lost 250 psi in 15 mins.- Bad sensor bleed off pressure 08:30 10:00 1.50 SURFAC CEMENT RURD P 3,244.0 3,244.0 RD cmt head & lines - LD landing jt and long bales. blow down mud lines, drain rises 10:00 15:15 5.25 SURFAC WELCTL NUND P 0.0 0.0 N/D Riser, ND surface adapter and NU csg head & tested same. NU BOP stack. 15:15 15:45 0.50 SURFAC DRILL RURD P 0.0 0.0 Installed elevator bales and installed mousehole. 15:45 17:00 1.25 SURFAC DRILL PULD P 0.0 0.0 Held PJSM and began to LD 4" DP out of the derrick from the mousehole. 17:00 17:30 0.50 SURFAC DRILL PULD P 0.0 0.0 PU Geospan and BHA equip. to the rig floor 17:30 23:00 5.50 SURFAC DRILL PULD P 0.0 0.0 Fin. LD excess 4" DP out of the derrick, LD a total of 59 stds. 23:00 00:00 1.00 SURFAC DRILL RURD P 0.0 0.0 C/O elevator bales and roughneck dies preparing to PU and std back 5" DP. Mud Check Data ~ ype _ -r--- - --- --- . _ _ ___ _ -- --T- °-- [- YP Calc Gel (t Os) GeI (10m) Gel {3om) ~ i HTHP Filt ~ensty Temp Solids, Corr '. ~ Depth (ftKB) ' Dens {Iblgaq Vis (slgt) PV Calc (cp) (Ibf1100ft') (Ibf/100ft~) {Ibf1100ft') (Ibfl100ft') MBT (Iblbbp j (mIJ30min) pH (°P) (%) Spud Mud 3,254.0 9.85 53 20.0 19.000 5.0 12.0 16.000 25.0 8.5 8.5 Spud Mud 3,254.0 10.10 300 23.0 70.000 60.0 88.0 102.000 27.5 9.0 9.0 ' Injection Fluid Fluid Source From Lease (bbl) Destination Note Cementing Fluids CD3-118 729.0 CD3-113 Cmt Contaminated Mud Diesel 43.0 CD3-113 Freeze Prot. Water 190.0 CD3-113 Flush Page 2/3 Report Printed: 3/17/2008 .itr ------~~ Security Level: Development Daily Drilling Report CD3-118 Report Number: 6 Rig: DOYON 19 Report Date: 3/112008 In~ection Fluid ~ --- U'd Source From Lease (bbl) - Dest(nation Note _ _ Water Based Mud CD3-118 !~ 1490 O~,CD3-113 ~ Drill Strings. BHA No. 1 - 8"Motor 4/5 - 5.3 stg / Bit Run No. 1 - 12 1/4in, Hughes Christensen , MXL-1, 51338 Depth In (ftKB) Depth Out (ftK6) TFA (incl Noz) (ins) Nozzles (/32") IADC Bit Dull 10 String Wt (10001bt) 114.0 3,254.0 0.75 16118/12/16 2-4-WT-A-E-1-NO-TD 44 Drill Strin g Components - _. ___ Jts Item Description - f OD Qn) ID Qn) _ Top Conn Sz (in) Top Thread Cum Len (ft) i Motor with Stabilizer 8 4.947 6 5/8 H 90 31.92 Float Sub 7 7/8 3.000 6 5/8 H 90 34.32 Stabilizer 8 2.875 6 5/8 H 90 41.05 XO Sub 8 3.250 6 5/8 Reg 43.47 MWD (DM) .7.99 3.000 6 5/8 Reg 52.33 MWD (HCIM) 7.98 1.920 6 5/8 Reg 61.47 MWD (TM) 8.02 3.250 6 5/8 H 90 70.32 UBHO 8 3.500 6 5/8 H 90 72.67 NMDC 7 1/2 2.813 6 5/8 H 90 103.65 NMDC 7 3/4 2.813 6 518 H 90 134.39 Drilling Jars -Mechanical 7 3/4 2.750 4 1 /2 IF 169.71 23 HUVDP 5 3.000 41/2 IF 874.50 1 Drill Pipe 5 4.276 4 1/2 IF 906.36 I Wellbores __ ____ Wellbore Name Wellbore API/UWI CD3-118 501032057000 _ _ Section ~ Slze {In) Act Top (ftKB) ~ Act Btm (ftK6) _ - Start Date End Date _ PROD1 6 1/8 COND1 36 36.0 114.0 2/6/2008 2/7/2008 SURFAC 12 1/4 114.0 3, 454.0 2/26!2008 2/29/2008 INTRM1 8 3/4 3,454.0 Cement _ Surface Casin Cement -Started 3/1/2008 Type Wellbore Cemented String Cement Evaluation Results casing CD3-118 Surface, 3,244.OftK6 Stg No. Description Top (ftK6) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) Surface Casing Cement 0.0 3,244.0 4 550.0 Fluid Class Amount (sacks) V (bbl} Density (Ib/gal) ~ Yield {ft'lsack) .Est Top (ftKB) Est Btm (ftKB) Lead Cement ASL 489 404.0 10.70 4.45 0.0 2,744.0 Tail Cement G 234 48.0 15.80 1.17 2,744.0 3,244.0 Page 3/3 Report Printed: 3/17/2008'. PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-118 Rig: Doyon 19 Date: Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: D. Mickey, R. Dexter, P. Wilson Pump used: #2 Mud Pump ~ strokes ~ 0.1000' Bbls/strk • 8.0~ Strk/min ~ Type of Test: openhoieTest LOT/Frr ~ Pumping down annulus and DP. ~ Casin Test Pressure In te ri Test Hole Size: s-3/4" ~ Casin Shoe De th Hole De th Pum in Shu t-in Pum in Shut-in RKB-CHF: 36.6 Ft 3,244 Ft-MD 2,489 Ft-TVD 3,274 Ft-MD 2,503 Ft-TVD Strks si Min si Strks si Min si Casing Size and De scription: 9-5/8" 4o#/Ft L-so BTC ~ 0 0 0 3500 0 0 0 Casin Test Pressure Int e rit Tes t 4 250 1 3500 1 0 0.25 800 Mud Weight: 9.6 ppg Mud Weight: 9.6 ppg 8 650 2 3500 2 20 0.5 560 Mud 10 min Gel: 10.0 Lb/100 Ft2 Mud 10 min Gel: 55.0 Lb/100 Ft2 12 950 3 3500 3 100 1 460 Test Pressure: 3 500 psi Rotating Weight: 135 Lbs 16 1200 4 3500 4 200 1.5 4 Rotating Weight: , 75 000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 20 1500 5 3500 5 300 2 4 Blocks/Top Drive Weight: , 75 000 Lbs Desired PIT EMW: 18.0 ppg 24 1900 6 3500 6 400 2.5 440 , Estimates for Test: 3.3 bbls Estimates for Test: 1087 si 1.2 bbls 28 2300 7 3500 7 500 3 440 ~ ~ 32 2700 8 3500 8 560 3.5 440 EMW =Leak-off Pressure + Mud Weight = 910 PIT 15 Second 36 3150 9 3500 9 640 4 440 + 9.6 0.052 x TVD 0.052 x 2489 ~ Shut-in Pressure, si 39 3500 10 3500 10 700 4.5 440 EMW at 3244 Ft-MD (2489 Ft-TVD) = 16.6 800 15 3500 11 780 5 440 Lost 25 s i durin g test held 20 3475 12 820 5 5 440 aooo p , . 993 f t % re est ssure 25 3475 13 860 6 440 o p . 3soo ~ ~~•~~+:~ ~~~~•-~~~ •---~ ~ , !, 30 3475 14 910 6.5 440 15 920 7 440 440 16 980 7.5 3000 17 1000 8 440 18 1010 8 5 440 . w 2soo ~ 19 1010 9 440 9 5 40 . X N 2000 w 0 a lsoo 1000 500 ~~- 0 5 5 1 0 1 5 2 0 2 5 30 0 ~~ 1 2 Barrels - 3 F F O 4 TEST 0 S hut-I O PI n tim T Poin e, M t inute s Vol PUm ume ed Vol Bled ume Back Volume PUm ed Volume Bled Back CASI NG TEST LEAK- F s s s s Comments: C Casing Detail Well: CD3-118 ConocoPhillips ~" Casinp Date: 03/12/08 .Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 33.95 FMC Gent/ Hanger 2.65 33.95 Jts 155 to 322 168 Jts 7" 26# L-80 BTCM Csg 7127.15 36.60 Halliburton HES Stage collar 2.47 7163.75 Jts 4 to 154 151 Jts 7" 26# L-80 BTCM Csg 6398.75 7166.22 Halliburton Shut-off baffle 1.05 13564.97 Jts 3 to 3 1 Jts 7" 26# L-80 BTCM Csg 43.29 13566.02 Halliburton Float Collar w/ By-pass baffel 1.02 13609.31 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 81.58 13610.33 Ray Oil Tools "Silver Bullet "Float Shoe 2.07 13691.91 7" Shoe @ 13693.98 8 3/4" hole @ 13706.00 8-3/4" Hole TD @13,706 ' MD / 6944' TVD 7 "Shoe @ 13,693.98 ' MD / 6943' TVD Total Centralizers: 78 Straight blade centralizer one per jt on jts # 1-14 Straight blade cent. one per jt on jts.# 155 to 179 Straight blade cent. one per jt. on joint #'s 245, 246, 247 Straight blade cent.one on every other jts. # 249 to 319 340 joints in shed -322 total jts. to run Last 18 jts. Out Use Run & Seal i e do e Average make up torque 8000 ft/Ibs Blocks wt. 75K UP WT. 340 K DN. WT. 147 K Supervisor: Burley /Hill Page 1 -~ ~. Cement Detail Report ' CD3-118 ..~ Intermediate Casing Cement Cement Details _ _ _ __ _ ,T ____ __ ___ Wellbore Name Description Cementing Start Date Cementing End Date Intermediate Casing Cement 3/13/2008 00:45 3/13/2008 04:46 CD3-118 Comment Cement 7" casing as follows: Pumped 5 bbls CW-100 -Pressure test lines to 3800 psi -Pumped remaining 35 bbls CW-100 -Mix & pumped 35 bbls - 10.5 ppg MudPush -Dropped btm plug -pumped last five bbls of MudPush -Load top plug in cement head -Mixed & pumped 83 bbls (400 sxs) 15.8 ppg tail slurry ( Class G w/ additives) -Dropped top plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cmt w/ 480 bbls 9.9 ppg mud -Displaced @ 7 bbls/min - 227 to 520 psi for first 470 bbls -slowed pumps to 4 bbls/min -psi for last 10 bbls of displacement Final displacement pressure 510 psi -Bumped plug w/ 1050 psi -Checked floats OK -CIP @ 0305 hrs.- Reciprocated pipe for first 250 bbls of displacement -pulled 75k over PUW and landed casing -had full circulation throughout job. -Bled off casing and loaded second stage closing plug in cement head. Cement 7" casing 2nd stage as follows: Pumped 5 bbls CW-100 -Pressure test lines to 3700 psi -Pumped remaining 20 bbls CW-100 -Mix & pumped 25 bbls - 10.5 ppg MudPush -Mixed & pumped 41 bbls (195 sxs) 15.8 ppg tail slurry (Class G w/ additives) -Dropped closing plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cmt w/ 234.7 bbls 9.9 ppg mud -Displaced @ 7 bbls/min - 162 to 348 psi for first 225 bbls -slowed pumps to 4 bbls/min -psi for last 10 bbls of displacement -Final displacement pressure 210 psi -Bumped plug w/ 2460 psi & held pressure for 3 minutes -Checked floats OK -CIP @ 0450 hrs.- full circulation throughout job. Cement Stages Stage # 1 ' Description Objective Top (ftKB) Bottom (ftKB) Fuli Return? Cmnt Rtrn (... Top Plug? Btm Pluy? Intermediate Casing 11,650.0 13,694.0 No Yes Yes Cement O (start) (bbl/min) O (end) (bbl/min) Q (avg) (bbl/min) P (Foal) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 6 550.0 1,050.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) ~ommen[ Cement 7" casing as follows: Pumped 5 bbls CW-100 -Pressure test lines to 3800 psi -Pumped remaining 35 bbls CW-100 -Mix & pumped 35 bbls - 10.5 ppg MudPush -Dropped btm plug -pumped last five bbls of MudPush -Load top plug in cement head -Mixed & pumped 83 bbls (400 sxs) 15.8 ppg tail slurry ( Class G w/ additives) -Dropped top plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cmt w! 480 bbls 9.9 ppg mud -Displaced @ 7 bbls/min - 227 to 520 psi for first 470 bbls -slowed pumps to 4 bbls/min -psi for last 10 bbls of displacement Final displacement pressure 510 psi -Bumped plug w/ 1050 psi -Checked floats OK -CIP @ 0305 hrs.- Reciprocated pipe for first 250 bbls of displacement -pulled 75k over PUW and landed casing -had full circulation throughout job. -Bled off casing and loaded second stage closing plug in cement head. Cement Fluids & Additives ' Fluid _ ~~'. ~ Fluid Type Fluid Description ~ Estimated Top (ftKB) Est Btm (ftKB) (Amount (sacks) (Class Volume Pumped (bbl) i Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Stage # 2 _ _ _ _ _ -- Description Objective lop (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? 6,096.0 7,165.0 No Yes No Q (start) (bbl/min) O (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 6 300.0 800.0 No No Depth tagged (ftKB) lag Method Depth Ptug Drilled Out To (ftKB) Drill Out Diameter (in) Cement 7" casing 2nd stage as follows: Pumped 5 bbls CW-100 -Pressure test lines to 3700 psi -Pumped remaining 20 bbls CW-100 -Mix & pumped 25 bbls - 10.5 ppg MudPush -Mixed i~ pumped 41 bbls (195 sxs) 15.8 ppg tail slurry (Class G w/ additives) -Dropped closing plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cmt w/ 234.7 bbls 9.9 ppg mud -Displaced @ 7 bbls/min - 162 to 348 psi for first 225 bbls -slowed pumps to 4 bbls/min -psi for last 10 bbls of displacement -Final displacement pressure 210 psi -Bumped plug w/ 2460 psi & held pressure for 3 minutes -Checked floats OK -CIP @ 0450 hrs.- full circulation throughout job. Cement Fluids 8 Additives Fluid _ _ _ _ - --- ---- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Primary Cement 11,650.0 13,694.0 400 G 83.0 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 ~ ~ 15.80 ~dditives Page 1/2 Report Printed: 3/17/2U08I i Cement Detail Report ., . . CD3-118 Intermediate Casing Cement Cement Fluids & Additives ' - - - -- - - _---- Fluid --_ _ _ _ _ ~ _ _ Fluid Type Fluid Description ' Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbq Primary Cement 6,096.0 7,165.0 195 G 41.0 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 15.80 Additives Additive Type Concentration Conc Unit label Page 2/2 Report Printed: 3/17/2008' Security Level: Development Daily Drilling Report CD3-118 Report Number: 17 Rig: DOYON 19 Report Date: 3/1212008 __ AFE Type - --T __ NetworkJlD # Tolal AFE+Sup 10211431 9,369,999.00 Wellbore Wetl Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftK6) Depth End (ftK6) CD3-118 Development FIORD NECHELIK 15.06 17.0 0.00 13,706.0 13,706.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,098.86 359,389.14 184,379.86 4,249,232.14 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/25/2008 2/26/2008 28.90 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 13,694.OftK6 Ops and Depth @ Morning Report 24hr Forecast Testing packoff. Cement casing and set packoff. Change rams to VBR and test. Lay down 5" DP from derrick. Last 24hr Summary Tested rams to 3500 psi. Rigged up and ran 322 Jts 7" casing to 13,694'. RU cement head and circulated to condition mud. General Remarks Weather Head Count Rig running on 2 generators 24 hrs. Clear Vis 10 miles. 50.0 _ -- _ - ~.i- -- -_. _ I ._Supervisor _._ _- Title _..-'. Dave Burley, Rig Supervisor - Rlg Supervisor Larry Hill, Rig Supervisor Rig Supervisor Time Log - -- Start lime __ ,I_-_ End Dur Time -. (hrs) Phase Op Code '. OpSub-Code Time P-N-T ~ Trbl Code _ _ Depth Start ' Trbl Clas~ (ftK6) Depth End (ftK6) Operation 00:00 01:00 1.00 INTRMI WELCTL BOPE P 0.0 0.0 RU and test 7" pipe rams 250 / 3500 psi - LD test jnt. & plug -set thin wall wear bushing 01:00 02:30 1.50 INTRMI CASING RURD P 0.0 0.0 RU to run 7" casing 02:30 02:45 0.25 INTRM1 CASING SFTY P 0.0 0.0 Held Pre-job Safety and Opts meeting with crew 02:45 08:15 5.50 INTRM1 CASING RNCS P 0.0 4,496.0 Run 7" 26# L-80 BTCM csg as follows: Ray Oil Tools Float shoe - 1 jts csg - Halliburton Float collar - 2 jts csg. Halliburton shut off collar (first 4 joints made up w/ Baker Loc -Filled pipe & checked float) - 103 jts to 4496' (106 jts total) Ran centralizers on jts. # 1-14 08:15 08:45 0.50 INTRM1 CASING CIRC P 4,496.0 4,496.0 Establish circulation -stage pumps up to 7.5 bpm -condition mud -FCP = 600 psi PUW 150K SOW 120K 08:45 13:45 5.00 INTRMI CASING RNCS P 4,496.0 8,478.0 Run 7" 26# L-80 BTCM csg. from 4,496' to 8,478' (200 jts total) 13:45 14:45 1.00 INTRM1 CASING CIRC P 8,478.0 8,478.0 Establish circulation -stage pumps up to 7 bpm -condition mud -FCP = 590 psi PUW 245K SOW 135K 14:45 18:45 4.00 INTRMI CASING RNCS P 8,478.0 12,036.0 Run 7" 26# L-80 BTCM csg. from 8,478' to 12,036. 18:45 20:15 1.50 INTRM1 CASING CIRC P 12,036.0 12,036.0 Establish circulation -stage pumps up to 5.5 bpm -condition mud -FCP = 580 psi PUW 295 K SOW 160 K. 20:15 22:30 2.25 INTRM1 CASING RNCS P 12,036.0 13,694.0 Run 7" 26# L-80 BTCM csg. from 12,036' to 13,694. Landed casing. 22:30 23:00 0.50 INTRM1 CASING RURD P 13,694.0 13,694.0 Laid down Franks tool and made up cement head. 23:00 00:00 1.00 INTRMI CASING CIRC P 13,694.0 13,694.0 Establish circulation -stage pumps up to 4.5 bpm -condition mud - CP = 520 psi PUW 325 K SOW 150 K. Latest BOP Test Data _ r -- _ _-- --- - - Date Comment 3/2/2008 Tested BOPE to 250/3 500 si Annular 250/2 500 si Lou Grimaldi W/AOGCC waived witnessin of test. Page 1/2 Report Printed: 3!17/2008 •~, .~ Security Level: Development Daily Drilling Report CD3-118 Report Number: 17 Rig: DOYON 19 Report Date: 3/12/2008 Mud Check Data ~' Type 'Depth (ftKB)_Dens (IWgal) Vis (slgt)' PV Calc (cp) (bfP/100ft) (bfll(OOft,) (bi/1(OOft') i (Gbf/100ft) ! MBT (Iblbbl) (mL 30mint) pH - DensttF' emp it Soli {s, Col LSND w/ 13,706.0 10.00 41 10.0 21.000 10.0 _ _ _ _ 13.0 14.000 7.0 _ 7.7 9.3 9.5 Inhibycol - - - - _ iln~ection Fluid - - - Fluid Source - --- - - ! From Lease (bbl) Destination Note Wellbores Wellbore Name Wellbore API/UWI CD3-118 501032057000 Section Size (in) -____ - -- --- Act Top (ftK6) Act Btm (ftKB) Start Date f End Date PROD1 61/8 COND1 36 36.0 114.0 2/6/2008 2/7/2008 SURFAC 12 1/4 114.0 3,454.0 2/26/2008 2/29/2008 INTRM1 8 3/4 3,454.0 Page 2/2 Report Printed: 3/17/2008 r~ r~ - Security Level: Development Daily Drilling Report CD3-118 .:,,,. Report Number: 18 Rig: - DOYON 19 Report Date: 3/13/2008 ----- AFE Type ' Network/ID 1t Total AFE+Sup - _ _ 10211431 9,369,999.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftK8) Depth End (ftK6) CD3-118 Development FIORD NECHELIK 16.06 18.0 0.00 13,706.0 13,706.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 6,196.68 365,585.82 692,329.68 4,941,561.82 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 2/25/2008 2/26/2008 28.90 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 13,694.OftKB Ops and Depth @ Morning Report 24hr Forecast RIH with Cleanout BHA picking up singles. RIH and clean out shoetrack. POOH. Last 24hr Summary Cemented 7" casing with 2 stage cement job. Set and tested packoff. Changed top rams to VBR and tested. Layed down 5" DP from derrick. PU cleanout BHA. General Remarks Weather Head Count Ross Hill due at rig today to instal l new Highline power card. Rig running on 2 generators 24 Clear Vis 10 miles. 47.0 hrs. -----_.- - ---_-- -_--_-- i __-_.-_ - .Title - --- Supervisor ~ --. _ Dave Burley, Rig Supervisor _ _ _ _ __ Rig Supervisor Larry Hill, Rig Supervisor Rig Supervisor ~~,TimeLog_ -- ~ _ _ Start End ~ Dur Depth End i Time ~ I Depth Start ( Time Time `r {hrs) Phase Op Code OpSub-Code P-N-T Trbl Code I Trbl Class. i (ftK6) ~ (RKB) i Operation '~. 00:00 00:45 0.75 INTRMI CEMENT CIRC P 13,694.0 13,694.0 Reciprocate casing -condition mud for cementing FCR/P = 6 bpm @ 650 psi PUW 330K SOW 150K - PJSM for cementing 00:45 03:15 2.50 INTRM1 CEMENT DISP P 13,694.0 13,694.0 Cement 7" casing as follows: Pumped 5 bbls CW-100 -Pressure test lines to 3800 psi -Pumped remaining 35 bbls CW-100 -Mix & pumped 35 bbls - 10.5 ppg MudPush -Dropped btm plug - pumped last five bbls of MudPush -Load top plug in cement head -Mixed & pumped 83 bbls (400 sxs) 15.8 ppg tail slurry (Class G w/ additives) -Dropped top plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cmt w/ 480 bbls 9.9 ppg mud -Displaced @ 7 bbls/min - 227 to 520 psi for first 470 bbls -slowed pumps to 4 bbls/min -psi for last 10 bbls of displacement Final displacement pressure 510 psi -Bumped plug w/ 1050 psi -Checked floats OK - CIP @ 0305 hrs.- Reciprocated pipe for first 250 bbls of displacement -pulled 75k over PUW and landed casing -had full circulation throughout job. -Bled off casing and loaded second stage closing plug in cement head. 03:15 03:30 0.25 INTRMI CEMENT CIRC P 13,694.0 7,164.0 Pressure up casing -opened Halliburton ES stage collar (top @ 7164') with 3150 psi -establish circulation and condition mud - 7 bpm / 320 psi. Latest BOP Test Data __ - Date - - - -- Comment 3/2/2008 Tested BOPE to 25013 500 si, Annular 250/2 500 si Lou Grimaldi W/AOGCC waived witnessin of test. Page 1/3 Report Printed: 3/17/2008 ~~ ---~----~ Security Level: Development Daily Drilling Report CD3-118 Report Number: 18 R ~~ Rig: DOYON 19 Report Date: 3/13/2008 Time Lo - _ Start 1 Time ~ `End Time Dur (hrs) Phase ___ Time O Code I P-N-T ~ OpSub-Code p T Trbl Code Trbl Class- Depth Start ftKB C ) Depth End ftK6 ( ) Operation 03:30 05:00 1.50 INTRM1 _ CEMENT DISP P 7,164.0 7,164.0 Cement 7" casing 2nd stage as follows: Pumped 5 bbls CW-100 -Pressure test lines to 3700 psi -Pumped remaining 20 bbls CW-100 -Mix & pumped 25 bbls - 10.5 ppg MudPush -Mixed & pumped 41 bbls (195 sxs) 15.8 ppg tail slurry (Class G w/ additives) -Dropped closing plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cmt w/ 234.7 bbls 9.9 ppg mud -Displaced @ 7 bbls/min - 162 to 348 psi for first 225 bbls -slowed pumps to 4 bbls/min -psi for last 10 bbls of displacement -Final displacement pressure 210 psi -Bumped plug w/ 2460 psi & held pressure for 3 minutes -Checked floats OK - CIP @ 0450 hrs.- full circulation throughout job. 05:00 06:15 1.25 INTRM1 CEMENT RURD P 7,164.0 0.0 RD cement head and casing elevators - LD landing joint and pull thin wall wear bushing. 06:15 07:00 0.75 INTRMI CASING DHEQ P 0.0 0.0 Install and test FMC packoff to 5000 psi for 10 minutes. 07:00 08:00 1.00 INTRM1 CASING RURD P 0.0 0.0 Change top pipe rams to 3 1/2" x 6" VBR's - LD casing bails - PU drilling bails and 5" elevators -clear equipment from rig floor. 08:00 09:00 1.00 INTRMI WELCTL BOPE P 0.0 0.0 Set test plug with 4" test joint -test top rams 250 / 3500 psi - LD test joint & plug - install wear bushing in wellhead. 09:00 23:15 14.25 INTRMI DRILL PULD P 0.0 0.0 Lay down 5" drill pipe in mousehole. 23:15 00:00 0.75 INTRM1 DRILL PULD P 0.0 0.0 Changed dies in Iron Roughneck and picked up cleanout BHA. --- Mud Check Data _ --- _ _ - - f YP Calc Gel (10s) Gel (10m) .Type- Depth(ftKB) DensQb/gal)°Vis(slgt)~PVCaIc(cp) (Ibf/100ft') (tbf/~00(t~) (Ibfl'IWft~ GeI (30m) OOfl') BTQblbbl) _ HTHP Felt (mU30min~ ___ i pH _ Density Temp (F). Solids, Corr. ~ (/) LSND w/ 13,706.0 9.80 33 9.0 16.000 8.0 10.0 11.000 6.6 7.9' 9.3 9.0 Inhibycol LSND w/ 13,706.0 9.80 34 10.0 18.000 9.0 11.0 0.0 0.0 0.0 100.0 Inhibycol __ _ - ---- In'ection Fluid __ ~- _ _ _ _ _ Eluid Source From Lease (bbt) Destination j Note Diesel CD3-118 60.0 CD3-118 Diesel CD3-118 5.0 CD3-113 Other CD3-118 175.0 CD3-113 Water CD3-118 300.0 CD3-118 Water CD3-118 150.0 CD3-113 Water Based Mud CD3-118 1700.0 CD3-113 Water Based Mud CD3-118 10.0 CD3-118 Wellbores _,___ _ _ _ Wellbore Name Wellbore API/UWI CD3-118 501032057000 - Sectiori Size (in) - - Act Top!(ftKBJ ---- - Aci Btm (ftKB) Start Date ~ i End Date _ PROD1 6 1/8 COND1 36 36.0 114.0 2/6/2008 2/7/2008 SURFAC 12 1/4 114.0 3,454.0 2/26/2008 2/29/2008 Page 2/3 Report Printed: 3/17/2008 ,.~ ~~ Security Level: Development Daily Drilling Report CD3-118 Report Number: 18 Rig: DOYON 19 Report Date: 3/13/2008 - -- _! Section _ ~-:. Slze {in) INTRM1 8 3/4'I - _ Act Top (ftKB) ~ Act Btm (ftK6) 3 454.0' Start Date End Date Cement ~ Intermediate Casin Cement -Started 3/13/2008 Type Wellbore Cemented String Cement Evaluation Results casing CD3-118 Intermediate, 13,694.OftKB Stg No. Description Top (ftKB) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) 1 Intermediate Casing Cement 11,650.0 13,694.0 4 550.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) __ 2 __ __ - -- 6,096.0 7,165.0 4 300.0 - Fluid - Class Amount sacks V bbl ~~ ~ Densit IbJ al Primary Cement G 400 83.0 15.80 - -- Yleld ft'lsack 1.17 - - -- - Est To ftKB Est Btm ftKB 11,650.0 13,694.0 Primary Cement G 195 41.0 15.80 1.17 6,096.0 7,165.0 Page 3/3 Report Printed: 3/17/2008 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-118 Rig: Doyon 19 Date: 3/13/2008 Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: D. Burley / L. Hill Pump used: Cement Unit ~ Strokes ~ 0.1000 13bis/Strk ~ Bbl/min ~.8li ~ i Type Of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test Pressure In te rit Test Hole Size: USE PICK LIST ~ Casin Shoe De th Hole De th Pum in Shu t-in Pum in Shut-in RKB-CHF: 34.0 Ft 3,244 Ft-MD 2,489 Ft-TVD 6,096 Ft-MD 3,795 Ft-TVD Strks si Min si Strks si Min si Casina Size and Description: 9-5/s" 40#/Ft L-80 BTC ~ 0 0 0 0 465 Chan es for Annula r Ade ua c Test Pressure Int e rit Tes t 1 5 70 0.25 450 uter casing shoe test results in comments Mud Weight: 9.9 ppg 2 10 197 0.5 440 Description references outer casing string. Inner casing OD: 7.0 In. 3 15 303 1 434 ize is that drilled below outer casing. 4 20 354 1.5 4 timated TOC for Hole Depth 5 25 399 2 41 . Enter inner casing OD at right Desired PIT EMW: 15.0 ppg 6 30 450 2.5 414 Estimates for Test: 660 si -0.1 bbls 7 35 487 3 409 ~ ~ 8 40 530 3.5 409 EMW =Leak-off Pressure + Mud Weight = 757 PIT 15 Second 9 45 574 4 409 + 9.9 0.052 x TVD 0.052 x 2489 Shut-in Pressure, si 10 50 616 4.5 404 EMW at 3244 Ft-MD (2489 Ft-TVD} = 15.7 !~ 450 15 55 654 5 404 20 60 687 5.5 404 looo ~( ~ 25 65 722 6 404 30 70 757 6.5 399 75 687 7 399 80 641 7.5 399 85 621 8 394 90 621 8.5 394 w ...` 95 621 9 394 ~ 100 621 9.5 39 ~ sao 105 621 10 ~ 110 a 0 0 2 5 30 0 2 4 Barrel 6 s ( 8 1 0~ 1 2 0 5 10 1 Shut-In tim i O PIT P 5 2 e, M t inute s Vol PUm ume ed Vol Bled ume Back Vo PU lume m ed Volume Bled Back ~~CA SING TEST LEAK-OFF TE ST o n S S S S Comments: 9 5/8" Surface casing LOT = 16 6 ppg EMW WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Tom Maunder 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-118 April 15, 2008 AK-MW-5700035 CD3-118: 2" x 5" MD BAT CEMENT Logs: 50-103-20570-00 1 Color Logs PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 z ~~ ,~1~, ~;~ /~; %~ ;;J';? Date: Signed: c~~l-Q~5 Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConowPhillips Alaska FIELD /UNIT !PAD: Alipne DATE: 03/27/08 OPERATOR REP: D. Mickey AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test • Packer Depth Pretest Initial 15 Min. 30 Min. Well CD3-118 Type Inj. ND 6,589' Tubing 2,500 2,500 2,500 2,500 Interval P.T.D. 208-025 Type test P Test psi 3500 Casing 3,617 3,521 3,491 P/F P Notes: Top packer OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waist G =Gas I =Industrial Waistewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT CD3-118.x15 • Maunder, Thomas E (DC)A) From: Galiunas, Elizabeth C [Elizabet#t.C.Galiunas@conocophillips.com] Sent: Monday, February 25, 2008 11:07 AM To: Davies, Stephen F (DOA}; Maunder, Thomas E (DOA} Cc: Woods, Nina Subject: Much Thanks Tom/Steve, Page 1 of 1 ~~s-~2-s Thanks far processing the CD3-118 permit so quickly. We really appreciate it. Thanks again, Liz Galiunas Drilling Engineer Alpine Drilling beam ConocoPhillips Alaska AT®1704 Office: (907)~265~G247 Cell: (907)r441r4871 2/25!2008 aw 3 ALA-SSA OIL Al~TID GA$ COI~TSERYATIOI~T COMI~II5SIOI~T Chip Alvord WNS Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Fiord Oil Pool, CD3-118 ConocoPhillips Alaska, Inc. Permit No: 208-025 Surface Location: 3978' FNL, 1010' FEL, SEC. 5, T12N, R5E Bottomhole Location: 4534' FNL, 2290' FEL, SEC. 35, T13N, R4E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). Sincerely, -~. ~_---- Daniel T. Seamount, Jr. Chair DATED this ~j day of February, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 19, 2008 COI'1000P'~'11~1 S p ~~~ ~/ ~D Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-118 Dear Sir or Madam: ~~~~ ~. ~ 2A0~ Ai'sk, Oil ~ fills ~r~s. CGlnmisslAn ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the CD3 (Fiord) pad. The-inteanded spud date for this well is February 22, 2008. ConocoPhillips also r~uests this permi# to be expiated since the plan is the move to this welt in 4 days. The short notice is to due to the asset's desire to perform tuts on the Kuparuk reservoir (with the new well: CD3-316A) before going. to CD3-303. We apologize for this inconvenience. It is intended that doyon Rig 19 ktie used to drill the well. Cd3-118 will be a horizontal open hole injector in the Nechelik reservoir. The well will be pre-produced for 6-12 months. The time will depend on the reservoir pressure for the 2009 CD3 drilling season. It is planned to convert the well from production to injection within the next year. The well will therefore be completed with a surface controlled SSSV as a typical production well. The well will also have a bond log to ensure good cement before converting the well over to injection. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. There have been 11 surface holes drilled at CD3 and there has n_ot been a significant show of shallow gas or gas hydrates through the surface hole interval. 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. A proposed drilling program 3. A drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d)(2). 5. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. ~ ~ If you have any questions or require further information, please contact Liz Galiunas at 265- 6247, or Chip Alvord at 265-6120. Sincerely, Liz Galiu a Drilling Engineer Attachments cc: CD3-118 Well File /Sharon Allsup Drake Chip Alvord Nina Woods Liz Galiunas Jack Walker Lanston Chin ATO 1530 ATO 1570 ATO 1706 ATO 1704 ATO 1740 Kuukpik Corporation ~ REC~.IV~D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION F~~ ~, Q Z(]0~ PERMIT TO DRILL ~CaA stca pig ~ ~~~ Gong. Commission 20 AAC 25.005 Naal~arsne 1a. Type of Work: Drill Q • Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ^ Multiple Zone^ Single Zone Q _ . _ ._. 1c. Specify-ifwell igpropose or. Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: CD3-118 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 21450' " TVD: 6905' ~ 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 3978FNL, 1010FEL, Secs, T12N, R5E 7. Property Designation: ADL 380092, 025526, 3721 a5 Fiord Oil Pool Top of Productive Horizon: 317FNL, 1422FEL, Sec12, T12N, R4E 8. Land Use Permit: ALK 380077 13. Approximate Spud Date: 2/22/2008 • Total Depth: 4534FNL, 2290FEL, SeC35, T13N, R4E - 9. Acres in Property: 2560 14. Distance to Nearest Property:10,000' SE of CRU boundry 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388032.6 y- 6003797.8 Zone- 4 10. KB Elevation ~~ ~ ~ ftp5 ` Y (Height above GL): 3T RKB feet 15. Distance to Nearest ,dD z°~ -`~ .`,e343 Well within Pool: CD3-114 3386' 16. Deviated wells: Kickoff depth: 400 ft. Maximum Hole Angle: 91° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3100 psig Surface: 2445 psig 18. Casing Program fi Setting Depth Quantity of Cement Size Speci cations Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 114' pre-installed 12.25" 9-5/8" 40# L-80 BTC 3216 37 37 3253 2500 578 sx AS Lite3, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 13812 37 37 13849 6939 414sx 15.8G, 2nd stage 184 sx 15.8G 3.5" 9.3# L-80 EUE 9680 32 32 9712 6670 tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling Program^/ Time v. Depth Plot ^ Shallow Hazard Analysis /^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiunas Printed Name C. Alvord Title WNS Drilling Team Lead Signature ~ Phone Date ~ ~yor~j Commission Use Only Permit to Drill Number: ~~ °°(„~~lrS API Number: 7 50- !~}3'~~~ /~ `"L~ Permit Approval Date: ~° ~~ See cover letter 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: M.~T~ C~~c~~ !-~,V4~~~ pG~ Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No []~ Other: ~~VE~1c-~ ~ .\y~~a~~~ H2S measures: Yes ^ No []• Directional svy req'd: Yes [v]im No ^ 3SOa QS\'e-.\+~~w~.~~~~tGS~, v~~t r^`t,,~l~ ~On\nC~.C~SJ~ W/ ~~O ~C~ , ,,,~ .:"~ ~ APPROVED BY THE COMMISSION DATE. .~ ~ ,COMMISSIONER ___ Form 10-401 Revised 12/2005 2 it in Du licate ICJ CD3-118 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casin Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin 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 tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations _ >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densi cement slurries 8-3/4" Hole / 7" 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' TVD 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 6-1/8" Hole 1 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 Fiord Nechelik : CD3-118 Procedure 1) Move on Doyon 19, dewater cellar as needed. 2) Rig up riser. 3) Drill 12-%" hole to the surface casing point as per the directional plan. (Directional/MWD). 4) Run and cement 9-5/8" surface casing. 5) Install and test BOPE to 3500 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 8-3/4" drilling BHA. 9) Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 10) Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11) BOPS test to 3500 psi. 12) Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 13) Displace well to Flo-Pro drilling fluid. 14) Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 15) Circulate the hole clean and pull out of hole. 16) Run completion: 3-%, 9.3#, L-80 tubing with SSSV, gas lift mandrels, packer, landing nipple and wireline entry guide. 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. oRicwa~ ~~ Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-108 is the closest existing well. Ellipse to ellipse separation is 5.0 @ 500' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. 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 Pumping Operations: Incidental fluids developed from drilling operations on well CD3-118 will be injected into a permitted annulus on CD3 pad or the class 2 disposal well on CD1 pad. The CD3-118surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Nechelik reservoir, potential Kuparuk reservoir and the Qannik reservoir. There. will be 500' of cement fill above the top of the Kuparuk reservoir along with 500' above and below the Qannik reservoir per regulations. Upon completion of CD3-118 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (1;?.0 ppg) " (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) " (0.052)'` (2500') + 1,500 psi = 3060 psi Pore Pressure = 1,113 psi Therefore Differential = 3060 - 1113 = 1928 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2.992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint - 12 %4" Intermediate hole to 7" casing point - 8 '/z" Production Hole Section - 6 1 /8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 API Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5-9.0 9.0-10.0 9.0-9.5 KCL 6 Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 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. ORIGINAL TOC @ +/- 6099' MD / 3805' ND f'. H ES cementing ~' tool +/- 7119' MD / 4273' TVD ~~ TOC Calculated @ +/- 11650' MD / 6351' ND (300' MD above packer) CD3-118 Completion Schematic 16" Conductor to 114' 2119' MD 4-1 /2" Camco SSSV: TRMAXX-5E w/ X profile (2.812") 3'/z" 9.3 ppf EUE-M tubing run with Jet Lube Run'n'Seal pipe dope 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing @ 3253' MD / 2500' TVD cemented to surface nnik interval top +/- 6599' MD / 4034' ND Sperry CD3-118wp02 Updated 2/15/2008 Completion: MD ND Inclination Tubing Hanger 32' 32' 0 degrees 4-'/z' 12.6 #/ft IBT-Mod Tubing (2 jts) 4-'/2" x 3-Yi' crossover 3-'/2' 9.3 #/ft EUE Tubing 1. Camco TRMAXX-5E SSSV (2.812") 2228' 2000' 51 3 '/~' 9.3 #/ft EUE Tubing 2. Camco KBMG GLM (2.867" ID) w/dummy 7395' 4400' 62 3-'/" 9.3 #/ft EUE Tubing 3. Camco KBMG GLM (2.867" ID) w/ SOV 11850' 6440' 64 3 '/z' 9.3 #/ft EUE Tubing 2 jts 4. Baker Premier Packer 11950' 6483' 65 3 '/2' tubing 1 joint 5. HES XN 2.813" (2.75" NoGo) at 65° 12000' 6504' 65 3-1/2" 10' pup joint 6. WEG 13699' 6937' 87 Top Kuparuk C at 12945' MD / 6826' TVD ~~< Top Nechelik at 13661' MD / 6934' TVD 7" 26 ppf L-80 BTC Mod Casing @ 13849' / 6939' ND @ 90° Well TD at 21450' M D / 6905' ND ORIGINAL CD3-118 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 3253 / 2500 14.5 1131 1635 7" 13849 / 6939 16.0 3139 2434 N/A 21450 / 6905 16.0 3124 ' N/A NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1131 - (0.1 x 2500') = 881 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1] x 2500 = 1635 psi OR ASP =FPP - (0.1 x D) = 3139 - (0.1 x 6939') = 2445 psi Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3124 - (0.1 x 6905') = 2434 psi ORIGINAL Cementing Program: 9 5/8" Surface Casing run to 3253' MD / 2500' TVD. Cement from 3253' MD to 2753' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2753' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1633' MD). Lead slurry: (2753'-1633') X 0.3132 ft3/ft X 1.5 (50% excess) = 526 ft3 below permafrost 1633' X 0.3132 ft3/ft X 4 (300% excess) = 2046 ft3 above permafrost Total volume = 526+ 2046 = 2572 ft3 => 578 Sx @ 4.45 ft /sk System: 578 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% BWOW1 D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 13849' MD / 6939' TVD: Cemented in two stages Cement from 13849' MD to 11650' MD (300' MD above the packer & minimum 500' MD above top of Kuparuk reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. First Stage: Lead: (13849' -11650') X 0.1503 ft3/ft X 1.4 (40% excess) = 462.7 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 462.7 + 17.2 = 479.9 ft3 => 414 Sx @ 1.16 ft3/sk System: 414 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a stage tool set 500' below the Qannik (K2) interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (7119' - 6099') X 0.1503 ft3/ft X 1.4 (40% excess) = 214.6 ft3 annular vol. Total Volume = 214.6 ft3 => 184 Sk @ 1.17 ft3/sk System: 184 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ORIGINAL ' By Weight Of mix Water, all other additives are BWOCement ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Plan: CD3-118 Plan: CD3-118 Plan: CD3-118wp03 Standard Proposal Report 15 February, 2008 Sp+~rt•y ©r•iilin~ services ORIGINAL E : ISCNSA SpnM rav.LylirMaNath Western North Slo ~,r Error S ce: Elliptical Cmic Cot~tt~F'hilli~ "'~`"i'~"~"'°~ R"'~~° CD3 Fiord Pad °°~m° N°rd,,~i~,~m'~ CD3 118w 03 MaprwSic Model: BGGM211D7 _ Pian: CD3-118 Ground level: 12.80 Plan: CD3-118 R((8: Plan: CD3-118 @ 49.10ft (Doyon 19 (36.3+12.t2)J Northing/ASP Y: 6003544.88 CD3-118wp03 EastinglASP X: 15280fi4.44 ~~ ~~~ ~~ 5000 G0~ "Open Hole D3-118wp01 Toe .-. C °0 2500 N CD3-118wp02 T2 t O Z ~9 ~ 1/4" `. . er- ~- O ~ 7" x 8-3/4" CD3-118wp01 Heel ', -2500 -15000 -12500 -10000 -7500 -5000 -2500 0 West(-)/East(+) (2500 ft/in) 0 0 ~ 10 ~~.. 2 O ~ ~ 2500 h~ 9 5/8" x 12 1 /4" - _- _ ~_._ ~ C-30- _........._.___......._ Q C-20 N D _.. _. U K 2 Base "~ ~ Q i 5000 a ~ `Albian 97------_._.__..._._-__ --...----.....__-----__......____-___..__.__ ~ Albian 96 0 ,;;:;: ~ - - - ; J" x 8 `-~' /4 ,:. v 1 /8" Open o c Top Nechelil~~ ~~ tn° a, CD3-118wp01 Heel CD3-11>~rp02 T2 CD3-118wp 7500 0 2500 5000 7500 10000 12500 15000 ConocoPhillips w _ . Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan: CD3-118 Company: ConocoPhillips(Alaska) Inc. -WNS TVD Reference: Plan: CD3-118 @ 49.10ft (Doyon 19 (36.3+12.8) :.Project: Western North Slope ' MD Reference: Plan: CD3-118 @ 49.10ft (Doyon 19 (36.3+12.8) Site: CD3 Fiord Pad North Reference: True WeII: Plan: CD3-118 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-118 Design: CD3-118wp03 __ - - Targets Target Name i - hitlmiss target Dip A ngle Dip Dir:':`' TVD +N!-S +E!-W Northing Eastiny -Shape (° ) (°) {ft) (ft) lft) (ft) Ift) CD3-118wp01 Heel 0.00 0.00 6,939.10 -1,612.88 -10,462.34 6,002,089.77 1,517,579.90 - plan hits target - Circle (radius 1,320.00) CD3-118wp02 T2 0.00 0.00 6,894.10 2,136.43 -12,234.03 6,005,865.00 1,515,865.00 - plan hits target - Circle (radius 1,320.00) CD3-118wp01 Toe 0.00 0.00 6,904.10 4,737.59 -14,488.92 6,008,499.58 1,513,649.70 - plan hits target -Circle (radius 1,320.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter.. Diameter (ftl lft) Name (") (") 3,253.84 2,500.00 9 5/8" x 12 1/4" 9-5/8 12-1 /4 13,848.91 6,939.10 7" x 8- 3/4" 7 8-3/4 21,450.01 6,904.10 6 1/8" Open Hole 6-1 /8 6-1/8 Formations Measured Verticat Vertical DIP Depth Depth Depth SS Dip Direction {ft) (ft) ft Name Lithology (°) (~) 12,770.72 6,780.00 LCU 0.00 12,621.10 6,735.00 Top Kuparuk D 0.00 6,714.47 4,087.00 K-2 Basal 0.00 12,372.06 6,650.00 Base HRZ 0.00 6,125.71 3,817.00 K-3 0.00 13,227.77 6,885.00 Top Nechelik 0.00 12,493.68 6,693.00 K-1 0.00 6,439.71 3,961.00 K-3 Basal 0.00 9,490.39 5,360.00 Albian 97 0.00 6,492.05 3,985.00 K-2 0.00 12,770.72 6,780.00 Top Nuiqsut 0.00 3,101.19 2,430.00 C-30 0.00 12,760.21 6,777.00 Top Kuparuk C 0.00 12,112.88 6,550.00 Top HRZ 0.00 12,961.29 6,830.00 Base Nuiqsut 0.00 3,929.83 2,810.00 C-20 0.00 10,406.25 5,780.00 Albian 96 0.00 ;.:~. . Plan Annotations Measured Vertica! Local C oordinates Depth Depth +N/.g +E/-W (ft) (ft) {ft) (ft) Comment, 395.70 355.70 0.00 0.00 KOP; 2.5 DLS 2/15/2008 4:13:04PM ~ ~ Page 9 COMPASS 2003.16 Build 42F ORIGINAL Operator: ConocoPhilllps(Alaska) Inc. -WNS Grid Correction: -0:86 - Job No: #N/A Feld: Western North Slope Magnetic Declination: 22.48 AFE No: #N/A Welk CD3.718wp03 Plan Dip: 80.75 API No: #N/A Rig: #N/A Dogleg per: 100 ft North Relerenee: TRUE Surface Location Original VS Plane: ..::288.17...... Parent Well: Plan: CD3.11B X: 388032.53 ft Vlsw VS Plane: 288.11 RKB Height: 49.10ft Y: 6003797.68 ~ Il Meas. Incl. TRUE Subsea RK8 Local ASP or Grid Dogleg Original ~ic. Taol Build Turn Course Drilled Depth (ft) Angle (deg) Azi. (deg) TVD (ft) TVD (fit) N(+)/S(-J (ffj E(+)/W(-) (tt) NI+)/S(-) Laf. (Y) E(+)/W(-) Dep. (X) Severity (°/l OD ft) VS (288°) (R) j2i. ;v4j Face (deg) (°/100 ft) (°/100 ft) Lengfh (ft) Distance (h) 0 Comments 36.30 O.Cr~ 0.00 '. -12.80 35.3(- 0.^0 0.00 603797.68 - 388032.53 0.00 0:00 100.00 0.00 0.00 50.90 100.00 0.00 0.00 6003797.68 388032.53 0.01 0.00 = #DIV(0! 0.00 0.00 63.70 63.70 CB-GYRO-SS (1) 200.00 0.00 0.00 1,SD9G 2fl0.00 0.00 0.00 6D03%97.68 388032.53 D.OI 0.00 #DIV/01 0.00 0.00 100.00 163.70 300.00 0.00 0.00 25090 300.00 0.00 0.00 6;)03797.68 388032.53 0.01 0.00 #DIV%01 0.00 0.00 100.00 263.70 399.70 0.00 0.00 ,35D.fA 39$.70 0.00 0.00 6i)0;?797.fi8 388032.53 0.01 0.00 #OIV/0! 0.00 0.00 99.70 363.40 KOP; 2.5 DLS 400.00 0.01 270.00 350.9E 400.00 0.00 0.00 600?%97.68 388032.53 4.29 0.00 ~« #DEYJO? 3.33 90000.00 0.30 363.70 500.00 2.51 270.00 4,`,(:.87 49997 0.00 •2.20 60:3747.71 388030.33 2.50 2.09 ~ 3 2.50 0.00 100.00 463.70 600.00 5.01 270.00 550.64 544.74 0.00 -8.76 6f~3797.81 388023.77 2.50 8.32 1# 0 2.50 0.00 100.00 563.70 700.00 7.51 270.00 650.04 649.14 0.00 -19.66 6G03797A7 388012.87 2.50 18.69 ~` 0 2.50 0.00 100.00 663.70 800.00 10.01 270.00 748.87 797.97 0.00 -34.89 6003798.20 387947.65 2.50 33.16 s; 0 2.50 0.00 100.00 763.70 899.70 12.50 270.00 846.64 895.74 0.00 -54.35 60D3798.49 387478.19 2.50 51.65 +` 0 2.50 0.00 99.70 863.40 900.00 12.51 269.99 846.93 896.03 0.00 -54.41 6DG3?98.49 387978.72 4.35 51.71 .ri -40 3.33 -3.33 0.30 863.70 MWD+IFR-AK-CAZ-SC (2) 1000.00 15.37 266.28 943.98 9$3.DB -0.86 -78.47 6003797.99 387454.05 2.99 74.32 ?`- -79 2.86 -3.71 100.00 963.70 1100.00 18.28 263.73 1039.64 1088.79 -3.44 •107.29 600379.5.95 387925.20 3.00 100.91 -15 '2.91 -2.55 100.00 1063.70 1200.00 21.22 261.86 1133.80 7182.90 -7.71 -140.80 6DD3792.08 387891,63 3.01 131.43 -73 2.94 -1.87 100.00 1163.70 1300.00 24.16 260.42 12.'1.6.05 7275.75 -13.68 •178.91 603786.68 387853.44 2.99 165.79 -77 2.94 -1.44 100.00 1263.70 1400.00 27.12 259.29 1316.19 7365.29 -21.32 -221.49 603779.68 387810.74 3.00 203.89 -10 2.96 •1.13 100.00 1363.70 1500.00 30.09 258.36 1x03.98 7453.08 -30.62 -268.45 600377LD9 387763.65 3.00 245.63 -4 2.97 -0.93 100.00 1463.70 1600.00 33.06 257.58 1489,17 1538.27 -41.55 -319.65 5003','6093 387712.29 3.00 290.90 •8 2.97 -0.78 100.00 1563.70 1700.00 36.04 256.92 i;>71.52 1620.62 -54.07 -374.96 603%4').24 387656.80 3.00 339.57 -7 2.98 -0.66 100.00 1663.70 1800.00 39.02 256.34 1f,5O.81 7649.41 -68.17 •434.21 603%36:D3 387597.3-0 3.00 397.51 -7 2.98 -0.58 100.00 1763.70 7900.00 42.00 255.84 171.6.83 1775.93 $3.79 -497.26 60372.1.36 387534.07 3.00 446.58 i« -6 2.98 -0.50 100.00 1863.70 2000.00 44.99 255.39 1%99.37 7848.47 -100.90 •563.92 6003705.26 387467.16 3.01 504.62 r# -b 2.99 -0.45 100.00 1963.70 2100.00 47.97 254.99 1868.22 1477.32 -119.43 -634.01 6003687.77 387396.80 2.99 565.48 r'. •6 2.98 -0.40 100.00 2063.70 2200.00 50.96 254.62 1933.21 7982.31 -139.36 -707.35 600366895 387323.17 3.00 628.99 ~ •5 2.99 -0.37 100.00 2163.70 2300.00 53.95 254.28 1994.14 2043.24 -1 6.62 -783.72 6D03648.84 387246.49 3.00 694.97 ~° -5 2.99 -0.34 100.00 2263.70 2400.00 56.93 253.97 2D`i0.86 2044.46 -183.14 -86292 6D03627.;i1 387166.95 2.99 763.25 ?`- -5 2.98 •0.31 100.00 2363.70 2500.00 59.92 253.67 2103.22 2152.32 -206.88 -944.73 60D36Dti.G0 387084.80 3.00 833.62 af• -5 2.99 -0.30 100.00 2463.70 2592.97 62.70 253.42 2147.84 279694 -229.99 •1022.94 fit)D3583.D7 387006.25 3.00 900.78 ?' -5 2.99 -0.27 92.97 2556.67 2600.00 62.70 253.42 2151.07 2200.77 -231.77 -1028.93 6003581.38 387000.24 0.12 905.91 ?t 90 0.00 0.00 7.03 2563.70 2700.00 62.70 253.42 2196.93 2246.03 -257.13 -1114.10 bM3557.3G 386914.70 0.01 978.98 90 0.00 0.00 100.00 2663.70 2800.00 62.70 253.42 2242.80 2241.40 -282.48 -1199.26 GD03533.23 386824.16 0.01 1052.05 AO 0.00 0.00 100.00 2763.70 2900.00 62.70 253.42 2288.66 2337.76 -307.84 -1284.43 603509.15 386743.62 0.01 1725.11 ~.' AO 0.00 0.00 100.00 2863.70 3000.00 62.70 253.42 2334.53 2363.63 -333.20 •1369.60 600348598 386658.09 0.01 1198.18 90 0.00 0.00 100.00 2963.70 3100.00 62.70 253.42 238Q39 2429.49 -358.55 •1454.76 60034619D 386572.55 0.01 1271.24 40 D.00 0.00 100.00 3063.70 3101.19 62.70 253.42 238D.94 2430.04 -358.86 -1455.78 6.^,0346.71 386577.53 0.68 1272.11 40 0.00 0.00 1.19 3064.89 C~0 3200.00 62.70 253.42 2x26.26 2475.36 -383.91 -1539.93 6003436.92 386487.07 QO1 1344.31 90 0.00 0.00 98.81 3163.70 3253.84 62.70 253.42 La.S(L95 2500.05 -397.56 •1585.7$ 6D034'Y,3.96 386-040.96 0.02 1383.65 90 0.00 0.00 53.84 3217.54 9 5/8" x 12' 1 /4" 3300.00 62.70 253.42 ?_x72.12 2521.22 -409.27 -1625.70 6003412.8.5 386-047.47 0.02 7417.38 N 90 0.00 0.00 46.16 3263.70 3400.00 62.70 253.42 2517.99 2567.0$ -434.62 •1710.26 60Z988.i7 386315.93 0.01 1490.44 z,~ 40 0.00 0.00 100.00 3363.70 3500.00 62.70 253.42 2563.85 2612.45 -459.98 -1795.43 600336470 386230.40 0.01 1563.51 ?:' 90 0.00 0.00 100.00 3463.70 3600.00 62.70 253.42 2609.72 2558.82 -485.34 -1880.60 603340,62 386144.86 0.01 1636.57 id 90 0.00 0.00 100.00 3563.70 3700.00 62.70 253.42 2655.58 2704.68 -510.70 -1965.77 6D03316.54 386059.32 0.01 7709.64 ~ 90 0.00 0.00 100.00 3663.70 3800.00 62.70 253.42 2'01.45 2750.55 -536.05 -2050.93 6t)U3292.47 385473.78 0.01 1782.70 of 90 0.00 0.00 100.00 3763.70 3900.00 62.70 253.42 27x7.31 2796.41 -561.41 -2136.10 6063268.39 385888.24 0.01 1855.77 90 0.00 0.00 100.00 3863.70 3929.83 62.70 253.42 276.99 2810.09 -568.97 -2161.51 6D03261.21 385862.73 0.03 1877.57 ?' 90 0.00 0.00 29.83 3893.53 C-20 ORIGINAL Meas. Inch TRUE Subsea RK8 Lor-al ASP or Grid Dogleg Original 'ie lool Build turn Course Drilled Depth (ft) Angle (deg) Azl. (deg) TYD (i'!) 1VD {9t) N(+)/5(-) (ft) E(+)/W(•] (ft) N(+)/S(-) Lai. (Y) E{+)/W(-) Dep. (X) Severity (°/700 ft) VS (288°) (H] 4,~. Face (deg) (°/100 fi) (°/100 fF) Length (ft) Dislance (H) 0 Comments 4000.00 62.70 253.42 4?793.18 2842.28 -586.77 -2221.27 600324x.32 385802.70 0.01 1928.84 #r 40 0.00 0.00 70.17 3963.70 4100.00 62.70 253.42 2839.04 2888.14 -612.12 -2306.43 Gv^03220.24 385717.17 0.01 2001.90 r,', 90 0.00 0.00 100.00 4063.70 4200.00 62.70 253.42 2854.41 2934Ai -637.48 -2391.60 6003196.)6 385631.63 0.01 2074.97 ?` 90 0.00 0.00 100.00 4163.70 4300.00 62.70 253.42 2930,7-7 2974.87 -662.84 •2476.77 6003172.09 385546.09 0.01 2148.03 r' 90 0.00 0.00 100.00 4263.70 4400.00 62.70 253.42 2976.64 3625.74 -688.20 -2561.94 !x'J03148.p1 385460.55 0.01 2221.10 ~~ 90 0.00 0.00 100.00 4363.70 4500.00 62.70 253.42 3022.60 3071.60 -713.55 -2647.10 6003123.94 385375.01 0.01 2294.17 ~?` 40 0.00 0.00 100.00 4463.70 4600.00 62.70 253.42 3068.37 3177.47 -738.91 -2732.27 600:3094,86 385284.48 0.01 2367.23 ~?' 90 0.00 0.00 100.00 4563.70 4700.00 62.70 253.42 3114.23 3163.33 -764.27 •2817.44 GD03D75.79 385203.94 0.01 2440.30 :~ 90 0.00 0.00 100.00 4663.70 4800.00 62.70 253.42 3160.10 3209.20 -789.62 -2902.60 6003051.71 385118.40 0.01 2513.36 90 0.00 0.00 100.00 4763.70 4900.00 62.70 253.42 3205.96 3255.06 -814.98 -2987.77 GD03027.6"s 385032.86 0.01 2586.43 40 0.00 0.00 100.00 4863.70 5000.00 62.70 253.42 3251.53 3300.43 $40.34 -3072.94 6003003.56 384947.32 0.01 2659.50 40 0.00 0.00 100.00 4963.70 5100.00 62.70 253.42 32'i'1.69 3346.74 -865.69 -3158.10 6002979.48 384861.79 0.01 2732.56 40 0.00 0.00 100.00 5063.70 5200.00 62.70 253.42 3343.56 3342.66 $91.05 •3243.27 600245:1.4; 384776.25 0.01 2805.63 90 0.00 0.00 100.00 5163.70 5300.00 62.70 253.42 3389.42 3438.52 -916.41 •3328.44 bD02931:',:9 3$4690.71 0.01 2$78.69 r 90 0.00 0.00 100.00 5263.70 5400.00 62.70 253.42 3435.29 3484.34 -941.77 -3413.61 6002907 2;~ 364605.17 0.01 2951.76 rr 40 0.00 0.00 100.00 5363.70 5500.00 62.70 253.42 3481.15 3530.25 -967.12 -3498.77 6002883.18 384514.63 0.01 3024.83 # 90 0.00 0.00 100.00 5463.70 5600.00 62.70 253.42 3527.0^.. 3576.12 -992.48 •3583.94 6002859.10 384434.10 0.01 3097.89 i- 90 0.00 0.00 100.00 5563.70 5700.00 62.70 253.42 3572.88 3621.98 -1017.84 -3669.11 6002535.03 384348.56 0.01 3170.96 t: 90 0.00 0.00 100.00 5663.70 5800.00 62.70 253.42 3618.75 3467.85 -1043.19 -3754.27 6002810.95 384263.02 0.01 3244.02 ~ 90 0.00 0.00 100.00 5763.70 5900.00 62.70 253.42 3664.61 3713.71 -1068.55 •3839.44 60021'56.87 384177.48 0.01 3317.09 ?t 90 0.00 0.00 100.00 5863.70 6000.00 62.70 253.42 371D.48 3754.58 -1093.91 -3924.61 6002762.80 384091.94 0.01 3390.16 .i'• 90 0.00 0.00 100.00 5963.70 6100.00 62.70 253.42 3756.34 3805.44 -1119.26 -4009.78 6DDI?38.72 384004.41 0.01 3463.22 90 0.00 0.00 100.00 6063.70 6125.71 62.70 253.42 3768.13 3877.23 -1125.78 -4031.67 6D02732..'.i3 383984.41 0.03 3482.01 40 0.00 0.00 25.71 6089.41 K-3 6200.00 62.70 253.42 380221 3851.31 -1144.62 -4094.94 600271~i.65 383420.67 0.01 3536.29 40 0.00 0.00 74.29 6143.70 6300.00 62.70 253.42 3£148.07 3897.77 -1169.98 -4180.11 6002690.57 383835.33 0.01 3609.35 40 0.00 0.00 100.00 6263.70 6400.00 62.70 253.42 3893A4 3443.04 -1195.34 -4265.28 6002666.50 383749.79 0.01 3682.42 90 0.00 0.00 100.00 6363.70 6439.71 62.70 253.42 3412.15 3961.25 -1205.41 -4299.10 5002^656 ~3 383715.82 0.02 3711.43 40 0.00 0.00 39.71 6403.41 K-3 Basal 6492.05 62.70 253.42 3936.15 3485.25 -1218.68 -4343.67 6002644.33 983477.05 0.02 3749.68 90 0.00 0.00 52.34 6455.75 K-2 6500.00 62.70 253.42 3939.8D 3988.40 -1220.69 -4350.44 6002642.42 363464.25 0.10 3755.49 90 0.00 0.00 7.95 6463.70 6600.00 62.70 253.42 398.5.67 4034.77 -1246.05 -4435.61 6002618.34 983578.72 0.01 3828.55 40 0.00 0.00 100.00 6563.70 6700.00 62.70 253.42 4D31.53 4080.63 -1271.41 -4520.78 frD02594.27 383493.18 0.01 3901.62 90 0.00 0.00 100.00 6663.70 4714.47 62.70 253.42 4038.17 4087.27 -1275.08 •4533.10 600?590.78 383480.80 0.06 3912.19 40 0.00 0.00 14.47 6678.17 K-2 Basal 4800.00 62.70 253.42 4077.4D 4726.50 -1296.76 -4605.94 6002570.19 363407.64 0.01 3974.68 90 0.00 0.00 85.53 6743.70 6900.00 62.70 253.42 4123.26 4172.34 -1322.12 -4691.11 6D02546.12 383322.10 0.01 4047.75 40 0.00 0.00 100.00 6863.70 7000.00 62.70 253.42 4169.13 4218.23 -1347.48 -4776.28 6002522.04 383236.56 0.01 4120.82 ~ 90 0.00 0.00 100.00 6963.70 7100.00 62.70 253.42 4214.49 4244.04 -1372.84 -4861.45 bD024'37.96 383151.03 0.01 4193.88 ?` 40 O.OD 0.00 100.00 7063.70 7200.00 62.70 253.42 42.60.Y,6 4304.95 -1398.19 -4946.61 6002473.89 383065.49 0.01 4266.95 ?t 90 0.00 0.00 100.00 7163.70 7300.00 62.70 253.42 •4306.72 4355.82 -1423.55 -5031.78 60024A9,S1 382479.95 D.O1 4340.01 b± 40 0.00 0.00 100.00 7263.70 7400.00 62.70 253.42 435254 4401.64 -1448.91 -5116.95 6002425.74 382694.41 0.01 4413.08 ?' 40 0.00 0.00 100.00 7363.70 7500.00 62.70 253.42 4398.x5 4447.55 -1474.26 •5202.11 GM?.401.66 382806.67 0.01 4486.15 4' AO 0.00 0.00 100.00 7463.70 7600.00 62.70 253.42 4444.32 4443.42 -1499.62 -5287.28 G~237758 382723.34 0.01 4559.21 90 0.00 0.00 100.00 7563.70 7700.00 62.70 253.42 449D.1S 4534.28 -1524.98 •5372.45 6D02353.5i 382637.80 0.01 4632.28 90 0.00 0.00 100.00 7663.70 7800.00 62.70 253.42 4536.05 4585.15 -1550.33 -5457.62 6^02324.43 382552.24 0.01 4705.34 90 0.00 .0.00 100.00 7763.70 7900.00 62.70 253.42 4581.91 4631.03 -1575.69 -5542.78 602305.36 382466.72 0.01 4778.41 90 0.00 0.00 100.00 7863.70 8000.00 62.70 253.42 4627.78 4674.86 -1601.05 -5627.95 6002281.28 382361.18 0.01 4851.48 90 0.00 0.00 100.00 7963.70 8100.00 62.70 253.42 4673.64 4722.74 -1626.41 •5713.12 6002257'21 362245.64 0.01 4924.54 rr` 40 0.00 0.00 100.00 8063.70 8200.00 62.70 253.42 4719.50 4768.60 -1651.76 -5798.28 6002233.13 362210.11 001 4997.61 40 0.00 0.00 100.00 8163.70 8300.00 62.70 253.42 4;65.37 4614.47 -1677.12 -5883.45 6002209.05 382124.57 0.01 5070.67 # 90 0.00 0.00 100.00 8263.70 8400.00 62.70 253.42 48}1.23 4660.33 -1702.48 -5968.62 6002184.98 382039.03 0.01 5743.74 r1 4fl 0.00 -0.00 100.00 8363.70 8500.00 62.70 253.42 4857.10 4906.20 -1727.83 -6053.78 6002160.90 381953.49 0.01 5216.61 4fl 0.00 0.00 100.00 8463.70 8600.00 62.70 253.42 4`10296 4452.04 -I 753.19 -613&.95 6002136.83 381867.95 0.01 5289.87 rt 90 0.00 0.00 100.00 8563.70 8700.00 62.70 253.42 4948.83 4997.43 -1778.55 -6224.12 bOD2112.;'S 381782.42 0.01 5362.94 r 90 0.00 0.00 100.00 8663.70 8800.00 62.70 253.42 4994.69 5043.79 -1803.90 -6309.29 6(1172088.67 381696.86 0.01 5436.00 4 90 0.00 0.00 100.00 8763.70 8900.00 62.70 253.42 :r.)4D.SG 5084.66 -1829.26 -6394.45 6(i01D64.60 361611.34 0.01 5509.07 3f 90 0.00 0.00 100.00 8863.70 ORIGINAL Meas. Incl. TRUE Subsea RK6 Local ASP or Grid Dogleg Original 'e Foal Build Tarn Course Drilled Depth (h) Angle (deg) Azi. (deg) 3VD (fq TVD (tt} N(+J/Si-) (ff) E(+)/W(.) (tt) f1(+}/S{-) LaY. IY) E{+)/W(-) Dep. (X) Severity (°/100 ft) VS (288°) (H) i".(: {rIl Pace {deg) (°/100 ft} (°/100 ff) Length (fl) Distance (ft) Comments 9000.00 62.70 253.42 5086.4;? 5135.52 -1854.62 -6479.62 6002040.52 381525.80 0.01 5582.14 i•,` 90 0.00 0.00 100.00 8963.70 9100.00 62.70 253.42 513229 5181.39 -1879.98 -6564.79 GC02016.45 381440.26 0.01 5655.20 ~ 40 0.00 0.00 100.00 9063.70 9200.00 62.70 253.42 5178.15 5227.25 -1905.33 •6649.95 bv^01992.37 381354.73 0.01 5728.27 # 90 0.00 0.00 100.00 9163.70 9300.00 62.70 253.42 5224.02 5273.72 -1930.69 -6735.12 6D01968.29 381269.19 0.01 5801.33 $' 40 0.00 0.00 100.00 9263.70 9400.00 62.70 253.42 5269.$8 5318.98 -1956.05 -6820.29 60D1944.22 381183.65 0.01 5874.40 ~?' 40 0.00 0.00 100.00 9363.70 9490.39 62.70 253.42 5311.,4 5340.44 -1978.97 -6897.27 6061922.46 381106.33 0.01 5940.44 ~ 90 0.00 0.00 90.39 9454.09 Albion 97 9500.00 62.70 253.42 5315J:i 5364.85 -1981.40 -6905.45 60019?.0.14 381098.11 .0.08 5947.46 # 90 0.00 0.00 9.61 9463.70 9600.00 62.70 253.42 5361.61 5414.73 -2006.76 -6990.62 6D0189G.07 381012.57 0.01 6020.53 90 0.00 0.00 100.00 9563.70 9700.00 62.70 253.42 _5407.n8 5456.,8 -2032.12 -7075.79 600187199 380427.04 0.01 6093.60 90 0.00 0.00 100.00 9663.70 9800.00 62.70 253.42 5453.34 5502.44 -2057.48 -7160.96 600184792 380841.50 0.01 6166.66 k~ 40 0.00 0.00 100.00 9763.70 9900.00 62.70 253.42 549221 5548.31 -2082.83 -7246.12 6001823.84 380755.96 0.01 6239.73 H 40 0.00 0.00 100.00 9863.70 10000.00 62.70 253.42 5545.07 5544.77 -2108.19 -7331.29 6001799.75 380670.42 0.01 6312.79 40 0.00 0.00 100.00 9963.70 10100.00 62.70 253.42 5;90.94 5640,04 -2133.55 -7416.46 60017'/;i.G9 3805BA.88 0.01 6385.86 90 0.00 0.00 100.00 10063.70 ' 10200.00 62.70 253.42 SE,Cs6.80 5685.90 -2158.90 -7501.62 6001'51.61 380499.35 0.01 6458.93 rr 40 0.00 0.00 100.00 10163.70 10300.00 62.70 253.42 5682.67 5731.77 -2184.26 -7586.79 6001T1.7S~9 380473.87 0.01 6537.99 rr` 90 0.00 0.00 100.00 10263.70 10400.00 62.70 253.42 5728.53 5777.63 -2209.62 -7671.96 6001703.45 380328.27 0.01 6605.06 z 90 0.00 0.00 100.00 10363.70 10406.25 62.70 253.42 5731.40 5780.50 -221 1.20 •7677.28 6001701 AG 380322.92 0.13 6609.63 *'- 90 0.00 0.00 6.25 10369.95 Albion 96 10500.00 62.70 253.42 5774.40 5823.50 -2234.97 -7757.13 6001679.38 380242.73 0.01 6678.12 # 90 0.00 0.00 93.75 10463.70 10600.00 62.70 253.42 5820.26 5869.36 -2260.33 -7842.29 60016.55.31 380157.19 0.01 6751.19 ?° 40 0.00 0.00 100.00 10563.70 10700.00 62.70 253.42 5866.13 5415.23 -2285.69 -7927.46 bDu1631.23 380071.66 0.01 6824.26 4 90 0.00 0.00 100.00 10663.70 10800.00 62.70 253.42 5911.94 5961.09 -2311.05 •8012.63 6,1607.16 379986.72 0.01 6897.32 s+ 90 0.00 0.00 100.00 10763.70 70900.00 62.70 253.42 .5957.86 6006.96 -2336.40 •8097.79 6DOl:i$3.08 379900.5$ 0.01 6970.39 90 0.00 0.00 100.00 10863.70 11000.00 62.70 253.42 6003.72 6052.$2 -2361.76 -8182.96 6001559.010 379815.04 0.01 7043.45 90 0.00 0.00 100.00 10963.70 11100.00 62.70 253.42 6049.59 6098.69 -2387.12 -8268.13 G00153A93 379729.50 0.01 7116.52 90 0.00 0.00 100.00 11063.70 11200.00 62.70 253.42 6095.4.5 6144.55 -2412.47 -8353.29 GDO15i0.85 379643.97 0.01 7189.59 90 0.00 0.00 100.00 11163.70 17300.00 62.70 253.42 6141.32 6140.42 -2437.83 -8438.46 N`0148bJ8 379558.43 0.01 7262.65 44 0.00 0.00 100.00 71263.70 11400.00 62.70 253.42 6187.18 6236.2$ -2463.19 •8523.63 60014G2J0 379472.89 0.01 7335.72 40 0.00 0.00 100.00 11363.70 17500.00 62.70 253.42 6233.O:i 4282,15 -2488.54 -8608.80 6001438.63 3793$7.35 0.01 7408.78 90 0.00 0.00 100.00 71463.70 11542.17 62.70 253.42 6252,,?9 6301.49 -2499.24 -8644.71 6001428.47 379351.28 0.02 7439.60 90 0.00 0.00 42.17 11505.87 11600.00 62.89 255.68 6278.83 6327.43 -2512.94 -8694.28 6001475.52 379303.51 3A9 7482.45 85 0.33 3.91 57.83 11563.70 13700.00 63.30 259.58 6324.10 6373.20 -2532.03 -8787.36 6001397.73 379214.15 3.50 7559.29 84 0.41 3.90 100.00 11663.70 11800.00 63.82 263.45 6368.64 6477.74 -2545.23 -8869.90 bD01385.86 379125.43 3.50 7639.33 i# 82 0.52 3.87 100.00 11763.70 11900.00 64.44 267.28 6412.28 6461.38 -2552.49 -8959.56 bfj01379.9j 379035.66 3.50 7722.30 # 81 0.62 3.83 100.00 11863.70 12000.00 65.16 271.06 6454.87 6503.97 -2553.79 -9050.01 600138C.Oi 378945.20 3.50 7807.86 # 79 0.72 3.78 100.00 11963.70 12100.00 65.97 274.80 6496.25 6545.35 -2549.13 -9140.91 6001386.03 378854.38 3.50 7895.71 i" 77 0.81 3.74 100.00 12063.70 12712.88 66.08 275.28 6501.48 6550.58 -2548.10 -9152.64 6v^^01367.24 378842.68 3.51 7907.17 .r 76 0.85 3.73 12.88 12076.58 Top HRZ 12200.00 66.87 278.49 6536.26 6585.36 -2538.52 -9231.93 fiLU1398.01 378763.54 3.50 7985.51 .~ 76 0.91 3.68 87.12 12163.70 12300.00 67.86 282.73 657476 6623.86 -2521.99 -9322.71 bD01415.90 378673A2 3.50 8076.93 74 0.99 3.64 100.00 12263.70 12372.06 68.62 284.72 6601.48 6&50.68 -2506.45 •9387.80 6001432.47 37860$.17 3.50 8143.63 73 7.05 ~ 3.59 72.06 12335.76 Base HRZ 12400.00 68.92 285.72 6611.60 6660.70 -2499.61 •9412.93 bD01439.b3 378583.14 3.50 8169.64 72 1.07 3.58 27.94 12363.70 12493.68 69.99 289.03 6644.48 6693.58 -2473.42 -9496.63 6001467.08 378449.85 3.50 8257.34 72 1.14 3.53 93.68 12457.38 K-1 12500.00 70.06 ~ 289.25 6646.64 4695.74 -2471.47 -9502.24 6001469.11 378444.26 3.46 8263.28 v 71 1.11 3.48 6.32 12463.70 12600.00 71.27 292.73 6679.76 6728.86 -2437.66 -9590.32 6001504.23 378406.71 3.50 8357.50 70 1.21 3.48 100.00 72563.70 12621.10 71.53 293.46 6686.49 6735.59 -2429.82 -9608.71 b;)OI;i12.35 378388.43 3.50 8377.42 70 1.23 3.46 21.10 12584.80 Top Kuparuk D 12700.00 72.54 296.16 6710.83 6754.93 -239A.33 -9676.83 6001544.85 378320.80 3.50 8451.95 64 1.28 3.42 78.90 12663.70 72760.21 73.34 298.20 67?8.49 6777.59 -2372.03 •9728.03 6001;171.92 378270.00 3.50 8506.79 +t bB 1.33 3.39 60.21 12723.91 Top Kuparuk C 12770.72 73.48 298.56 6731 ~9 6780.59 -2367.25 -9736.89 h001576.84 378261.21 3.54 8518.70 b8 1.33 3.43 10.51 12734.42 LCU -Top Nuigsui 12800.00. 73.87 299.54 6739.72 5788.82 -2353.60 •9767.45 600158285 378236.85 3.48 8546.29 id bB 1.33 3.35 29.28 72763.70 12900.00 75.26 302.88 G%65.34 6875.44 -2303.65 -9843.87 6001642.03 378155.19 3.51 8640.15 i# b7 1.39 3.34 100.00 12863.70 72961.29 76.13 304.90 6781.49 6830.59 -2270.54 -9893.17 6001575.88 378106.39 3.49 8697.30 ~?: 66 1.42 3.30 61.29 12924.99 Base Nuigsui 13000.00 76.69 306.77 6790.59 6839.89 -2248.67 -9923.79 6001698.21 378076.11 3.50 8733.20 ~ 86 1.45 3.28 38.71 12963.70 13100.00 78.16 309.43 581236 6867.46 -2188.85 •10000.89 6(X71 %59.18 377999.91 3.50 8825.07 ?^ 66 1.47 3.26 100.00 13063.70 13200.00 79.67 312.64 6.93L:i9 6880.64 -2124.43 •10074.90 6001824.70 377926.88 3.49 8915.44 ~ d5 1.51 3.21 100.00 13163.70 13227.77 80.09 313.53 6836.4'7 6$85.57 -2105.76 -10094.86 60018.93.67 377907.2q 3.50 $940.22 64 1.51 3.20 27.77 73191.47 Top Nechelik OL'f908L 8b'Zb 00'0 00'0 Db SE'lL£ZL 10'0 85'LLL5L£ 89'88t9UO9 94'46ZZ1• ZC90ZZ LL'4dB9 19'8489 BO'6lE £8'68 00'OOLBI Z1ZOdM811-£4~ LZ'LLbLI ZS'L 66'L- £1'0- 4d° x 90'/6//1 00'2 OL'L£B5L£ 06'l.tt90C>y B8'f£ZZl- 48'9£12 £4'4489 ££'54439 80'6 LE £8'68 ZS'LOOBL OL'£96LL 00'OOl DO'L- 01'0- £d• ~ L9'SBLZL OOZ £b `9f85L£ 4!'2119009 96'822//- SCI£1Z Ltr'trb84 16'5489 £Z'6LE VS'68 00'0008/ OL'f9BLt 00'OOl 66'L- 11'0- £b- is L6'OOLZL bb'l 4/'6685/£ EE'4£G9009 00'S9LZl- 0£'4802 22'4689 21'8489 fZ'lZ£ 46'68 00'006[1 OL'£9LLl 00'001 00'2• 01'0- £b- ifi 4!'81/21 OOZ 08'6565/£ SE'VSo5009 4[£0/21- 9Z'SLbt lZ'trb89 11'8489 LL'£Z£ SO'Ob 00'008// OC£99L1 00'001 00'2• Ol'0- £d- # 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(X) Severity ('/100 ff) VS (288°) ($) j2c (fl'j Fnce (deg) (°/10(1 fl) (°/100 N) Length (fib Distance (h) '^ Comments 18200.00 89.83 319.08 G84.5.?0 6895.00 2282.29 -12359.96 5006265.22 375708,22 0.01 12457.09 ~ 90 0.00 0.00 100.00 18163.70 18300.00 89.83 319.08 6846.20 6895.30 2357.85 -12425.46 6006341.76 375643.86 0.01 12542.84 ~ 40 0.00 0.00 100.00 18263.70 18400.00 89.83 319.08 6846.50 6895.60 2433.41 -12490.96 6006418.29 375579,50 0.01 72628.58 tr 90 0.00 0.00 100.00 78363.70 18500.00 89.83 319.08 d84G.79 6895.89 2508.97 -12556.46 fiLOb494.83 375515.14 0.01 72714.32 ~ 90 0.00 0.00 100.00 78463.70 18600.00 89.83 319.08 584?.09 6896.74 2584.53 •12621.96 60065?1 17 375450.78 0.01 12800.07 ~ 94 0.00 0.00 700.00 18563.70 18700.00 89.83 319.08 68n?.39 6896.44 2660.10 •12687.46 6005697.90 375386.43 0.01 72885.87 3t 9U 0.00 0.00 100.00 18663.70 18800.00 89.83 319.08 f.,f.±A?.68 6846.7$ 2735.66 -12752.96 6006%24.44 375322A7 0.01 12971.55 90 0.00 0.00 100.00 18763.70 18900.00 89.83 319.08 6847.98 6897.08 2811.22 -12818.46 6006800.98 375257.77 0.01 13057.30 '. 90 0.00 0.00 100.00 18863.70 19000.00 89.83 319.08 6848.28 6897.38 2886.78 •12883.96 GCOG877.51 375793.35 0.01 13143.04 90 0.00 0.00 100.00 18963.70 19700.00 89.83 319.08 6848.57 6847.67 2962.34 -12949.46 6006954.05 37512$.94 0.01 13228.78 40 0.00 0.00 100.00 19063.70 19200.00 89.83 319.08 6848.87 6847.97 3037.91 -13014.96 6007030.59 375064.63 0.01 73314.53' '?>' 40 0.00 0.00 100.00 19163.70 19300.00 89.83 319.08 6849.17 6848.27 3113.47 -13080.46 6007107.12 375000.27 0.01 13400.27' 90 0.00 0.00 100.00 19263.70 19400.00 89.83 319.08 h849.40 6898.56 3189.03 -13145.96 600718,3.66 374935.92 0.01 13486.01 90 0.00 0.00 100.00 19363.70 19500.00 89.83 319.08 6849.70 689$.$6 3264.59 -13211.46 500?200.20 374$71.56 0.01 13571.76 x? 90 0.00 0.00 100.00 19463.70 19600.00 89.83 319.08 68,56.06 6$49.16 3340.16 -13276.96 500?3:16.73 374807.20 0.01 13657.50 9p 0.00 0.00 100.00 19563.70 19700.00 89.83 319.08 6856.35 6894.45 3415.72 •13342.46 6007113.27 374742.84 0.01 13743.24 St 90 0.00 0.00 100.00 19663.70 19800.00 89.83 319.08 6850.65 6899.75 3491.28 -13407.46 (s^A7489.81 374678.48 0.01 13828.99 # 90 0.00 0.00 100.00 19763.70 19900.00 89.83 319.08 685D.95 6400.05 3566.84 -13473.46 bU07506.34 374614.12 0.01 73974.73 ?' 90 0.00 0.00 100.00 19863.70 20000.00 89.83 319.08 685L24 6400.34 3642.40 •13538.96 6007542.88 374549.76 0.01 14000.47 r 90 0.00 0.00 100.00 19963.70 20100.00 89.83 319.08 6851.54 6900.64 3717.97 -13604.46 60OT%19.42 374485.40 0.01 14086.22 ?P 40 0.00 0.00 100.00 20063.70 20200.00 89.83 319.08 6851.84 6400.44 3793.53 •13669.96 6007:%95.96 374421.05 0.01 14171.96 ~ 90 0.00 0.00 100.00 20163.70 20300.00 89.83 319.08 6852.13 6901.23 3869.09 -13735.46 6{;0787249 374356.69 0.01 14257.70 4' 90 0.00 0.00 100.00 20263.70 20400.00 89.83 319.08 6852A3 6401.53 3944.65 -13800.96 6007949.03 374292.33 0.01 14343.45 90 0.00 0.00 100.00 20363.70 20500.00 89.83 319.08 6852.73 6901.83 4020.21 -13866.46 6008025.57 374227.97 0.01 14429.19 90 0.00 0.00 100.00 20463.70 20600.00 89.83 319.08 5853.02 6902.12 4095.78 -13931.96 4108102.10 374763.61 0.01 14514.93 AO 0.00 0.00 100.00 20563.70 20700.00 89.83 319.08 6853.32 6902.42 4171.34 -13997.46 6008178.64 374049.25 0.01 14600.68 40 0.00 0.00 100.00 20663.70 20800.00 89.83 319.08 6853.62 6402.72 4246.90 •14062.96 6008255.18 374034.89 0.01 14686.42 90 0.00 0.00 100.00 20763.70 20900.00 89.83 319.08 6853.91 6903A7 4322.46 -14128.46 6008331.1'1 373970.54 0.01 14772.16 90 0.00 0.00 100.00 20863.70 27000.00 89.83 319.08 lu354.21 6403.31 4398.03 -14193.96 b00P,408.2:i 373906.18 0.01 14857.91 90 0.00 0.00 100.00 20963.70 21100.00 89.83 319.08 6854.51 6903.61 4473.59 -14259.46 6008484.79 373$41.82 0.01 14943.65 r+ 90 0.00 0.00 100.00 21063.70 27200.00 89.83 319.08 6854.80 6903.94 4549.15 -14324.96 51)08561:32 373777.46 0.01 15029.39 90 0.00 0.00 100.00 21163.70 21300.00 89.83 319.08 0855.10 6904.20 4624.71 -14390.46 6008637.86 373773.10 0.01 15115.14 :d 90 0.00 0.00 100.00 21263.70 21400.00 89.83 319.08 685.5.40 6404.50 4700.27 -14455.96 5108714.40 373648.74 0.01 15200.88 ?? 90 0.00 0.00 100.00 21363.70 21450.01 89.83 319.08 6855.55 6904.65 4738.06 -14488.72 5v08752.G7 373616.56 0.02 75243.76 r;' 40 0.00 0.00 50.01 21413.71 6 1 /8"Open Hole - CD3-118wp01 Toe ~, ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Plan: CD3-118 Plan: CD3-118 CD3-118wp03 ~rr~ ~ilir~ r Clearance Summary Anticollision Report 15 February, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Plan: CD3-118 -Plan: CD3-118 -CD3-118wp03 Well Coordinates: 6,003,544.88 N, 1,528,064.44E (70° 25' 08.37" N, 150° 54' 55.09" W) Datum Height: Plan: CD3-118 @ 49.10ft (Doyon 19 (36.3+12.8)) ', Scan Range: 0.00 to 21,450.01 ft. Measured Depth. Scan Radius is 2,341.37 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 .... ...: ~s.:~~~ ~I~~N IE^sp~c~rry Clrilt~ng ~eruice~ _~RIGIN Scan Method: Trav, Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based GLOBAL FILTER APPLIED: All welipaths within 200'+ 100/1000 of reference SURVEI' PROGI2A~1 :2008-02-15"I~OD:00:00 Validatcd:l'cs ~"crsion:8 U@ NOIth Depth Frum Depth To Sun~ey/Plan Tool )ft DO On 19 36.3+12.8 3030 999.70 CD3-118wp03 (Plan: CD3-118) CB-GYRO-SS ( y ( )) 999.70 21450.01 Cll3-118wp03 (Plan: CD3-118) ~1R'D+IFR-AK-CA~SC )ft (Doyon 19 (36.3+12.8)) 0 / 360 D3-115wp0 t ~' . : ~ ~~ 50 D3-11 60 D3-111 L1 - - - D3-111 ~';~.~, D3-11 a i - - - D3-11 <r • , ' s' r' ._ ~~. ~ ` D3-316AP'B _ _ _ D3-316 12d~ D3-31 -90 / 270 ~ I -180 / 180 SECTION DETAILS Sec NID Inc Azi TVD +N/-S +E/-W DLeg 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 ~ inn nn n nn n nn ann nn n nn n nn n nn ~36>..,..... 250 '(750 - 50 ~a0 z00 ~ 500 750 2500 750 1000 3a~~ 1000 1250 3500 .' 1z~~ 1500 acoo 1500 ` ~ .`"~ 1750 A500 ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD3-118 -CD3-118wp03 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Plan: CD3-118 -Plan: CD3-118 -CD3-118wp03 Scan Range: 0.00 to 21,450.01 ft. Measured Depth. Scan Radius is 2,341.37 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad • CD3-108 -CD3-108 -CD3-108 98.00 200.27 98.00 198.47 100.00 111.200 Centre Distance Pass -Major Risk CD3-108 -CD3-108 -CD3-108 272.98 201.87 272.98 196.83 275.00 39.985 Clearance Factor Pass -Major Risk CD3-109 -CD3-109 -CD3-109 199.49 179.66 199.49 175.52 200.00 43.387 Centre Distance Pass -Major Risk CD3-109 -CD3-109 -CD3-109 422.65 181.37 422.65 172.37 425.00 20.153 Clearance Factor Pass -Major Risk CD3-110 -CD3-110 -CD3-110 99.38 160.00 99.38 158.09 100.00 83.637 Centre Distance Pass -Major Risk CD3-110 -CD3-110 -CD3-110 324.37 161.53 324.37 154.78 325.00 23.939 Clearance Factor Pass -Major Risk CD3-111 -CD3-111 -CD3-111 446.93 135.96 446.93 126.46 450.00 14.307 Centre Distance Pass -Major Risk CD3-111 -CD3-111 -CD3-111 494.18 136.42 494.18 126.02 500.00 13.117 Clearance Factor Pass -Major Risk CD3-111 -CD3-111 L1 -CD3-111 L1 446.93 135.96 446.93 126.46 450.00 14.307 Centre Distance Pass -Major Risk CD3-111 -CD3-111 L1 -CD3-111 L1 494.18 136.42 494.18 126.02 500.00 13.117 Clearance Factor Pass -Major Risk CD3-112 -CD3-112 -CD3-112 494.91 115.69 494.91 105.71 500.00 11.601 Centre Distance Pass -Major Risk CD3-112 -CD3-112 -CD3-112 542.54 115.96 542.54 105.20 550.00 10.784 Clearance Factor Pass -Major Risk CD3-113 -CD3-113 -CD3-113 149.20 99.39 149.20 96,34 150.00 32.607 Centre Distance Pass -Major Risk CD3-113 -CD3-113 -CD3-113 447.11 100.65 447.11 91.12 450.00 10.562 Clearance Factor Pass -Major Risk CD3-113 -CD3-113 -CD3-113wp04 149.31 99.39 149.31 96.34 150.00 32.582 Centre Distance Pass -Major Risk CD3-113 -CD3-113 -CD3-113wp04 447.22 100.65 447.22 91.12 450.00 10.560 Clearance Factor Pass -Major Risk CD3-114 -CD3-114 -CD3-114 399.05 79.57 399.05 71.09 400.00 9.384 Centre Distance Pass -Major Risk CD3-114 -CD3-114 -CD3-114 447.44 80.02 447.44 70.48 450.00 8.390 Clearance Factor Pass -Major Risk CD3-307 -CD3-107 -CD3-107 36.30 220.15 36.30 219.24 36.10 241.399 Centre Distance Pass -Major Risk CD3-307 -CD3-107 -CD3-107 399.66 223.83 399.66 215.35 400.00 26.366 Clearance Factor Pass -Major Risk CD3-307 -CD3-307 -CD3-307 36.30 220.15 36.30 219.24 36.25 241.399 Centre Distance Pass -Major Risk CD3-307 -CD3-307 -CD3-307 399.51 223.83 399.51 215.34 400.00 26.376 Clearance Factor Pass -Major Risk CD3-307 -Plan: CD3-107A -CD3-107Awp01 36.30 220.15 36.30 219.24 36.10 241.399 Centre Distance Pass -Major Risk CD3-307 -Plan: CD3-107A -CD3-107Awp01 399.66 223.83 399.66 215.35 400.00 26.366 Clearance Factor Pass -Major Risk CD3-316 -CD3-316 -CD3-316 448.72 39.46 448.72 29.92 450.00 4.140 Centre Distance Pass -Major Risk CD3-316 -CD3-316 -CD3-316 497.85 39.68 497.85 29.22 500.00 3.795 Clearance Factor Pass -Major Risk CD3-316 -CD3-316A -CD3-316A 448.72 39.46 448.72 29.92 450.00 4.140 Centre Distance Pass -Major Risk CD3-316 -CD3-316A -CD3-316A 497.85 39.68 497.85 29.22 500.00 3.795 Clearance Factor Pass -Major Risk 15 February, 2008 - 16:00 Page 2 of 5 COMPASS ORIGINAL FiALLIBURTON ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD3-118 -CD3-118wp03 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Plan: CD3-118 -Plan: CD3-118 -CD3-118wp03 Scan Range: 0.00 to 21,450.01 ft. Measured Depth. Scan Radius is 2,341.37 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD3-316 -CD3-316AP61 -CD3-316APB1 448.72 39.46 448.72 29.92 450.00 4.140 Centre Distance Pass -Major Risk CD3-316 -CD3-316APB1 -CD3-316AP61 497.85 39.68 497.85 29.22 500.00 3.795 Clearance Factor Pass -Major Risk Plan: CD3-106 -Plan: CD3-106 -Plan: CD3-106 (wp01 200.50 239.95 200.50 235.85 200.00 58.517 Centre Distance Pass -Major Risk Plan: CD3-106 -Plan: CD3-106 -Plan: CD3-106 (wp01 250.49 240.58 250.49 235.39 250.00 46.392 Clearance Factor Pass -Major Risk Plan: CD3-115 -Plan: CD3-115 -CD3-115wp03 399.60 59.76 399.60 51.33 400.00 7.091 Centre Distance Pass -Major Risk Plan: CD3-115 -Plan: CD3-115 -CD3-115wp03 984.05 63.35 984.05 42.74 1,000.00 3.073 Clearance Factor Pass -Major Risk Plan: CD3-117 -Plan: CD3-117 -CD3-117wp02 523.65 18.58 523.65 7.46 525.00 1.670 Centre Distance Pass -Major Risk Plan: CD3-117 -Plan: CD3-117 -CD3-117wp02 622.73 19.75 622.73 6.49 625.00 1.489 Clearance Factor Pass -Major Risk CD4 Nanuq Pad Survev tool program From To Survey/Plan Survey Tool (ft) (ft) 36.30 999.70 CD3-118wp03 CB-GYRO-SS 999.70 21,450.01 CD3-118wp03 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 15 February, 2008 - 16:00 Page 3 of 5 COMPASS QB.L~I~LA~o~ ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD3-118 -CD3-118wp03 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: CD3-118 @ 49.10ft (Doyon 19 (36.3+12.8)). Northing and Easting are relative to Plan: CD3-118. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: -0.86 °. ~1Q O r- .~ C7 1~ Q (13 +~~ C t~ ,~ CL? LEGENL GD3-1Q13, CD3-1Q8, CD3-1Q8 '~d14 GD3-iQB, CD3-iQB, GD3-1Q0 1~+5 GD3-11Q, GD3.11Q, CD3-11Q V12 GD3-111, CD3-111 ,GD3-111 'VF CD3-111, CD3-111 L1, CD3-11 1 L1 V1 CD3-112, CD3-112, CD3-112 '4t3 CD3.113, GD3.113, CD3-113 41P1 CD3-113, CD3-113, CD3-113urpQ4 Vl1 CD3-114, CD3-114, CD3.114 tiP14 GD3-3Q7, CD3.1Q7, GD3-1Q7 1e7 CD3-3Q7, CD3-3Q7, CD3-3Q7 '~4 GD3-3Q7, Plan: CD3-1Q7A, CD3•iQ7t1waQ1 1/1 CD3-310, CD3.310, CD3-310 '+1Q CD3-'310, CD3-310W1, CD3-310A`.PJQ CD3-318, CD3-31014PB1 ,CD3.310APB1 V1'1 Plan: GD3-1Q0, Plan: CD3.1Q0, Plan: CD3.1Q0 ~w C Plan: CD3-115, Plan: CD3-115, GD3-115wpQ3 'V Plan: CD3-117, Plan: CD3-117, CD3.117wpQ2 1l8 Plan: CD4-3Q3, Plan: GD4-3Q3ST1, CD4-3Q3ST1 F GD3.118w pQ3 15 February, 2008 - 16:00 Page 4 of 5 COMPASS ~~i~~ ~~~~i 120(~~ 16~QiQ 2~i~(~Cl ~le~~ure~d depth ~~l~iC~O ftlin~ Kldte~~t~rorv ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Plan: CD3-118 -CD3-118wp03 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor 10. B. a. 0 u~ cv '~-~ 6 0 ~s o ~. `s w~ ~. 0 a :... ~ _ I i _ .._~ ~ .. ~, .__ _ I { _ .. _._ ~ ~ .- . _ ....~ .. . _____- , __._-._ ! , 5 I s, ~ •- ~ _ - r ....._ . _._..... , _---~ j __ - ..._. _ ~ . _..~. _ ._....~ ...-_ -.- ~-- ~, ,. Sti , i ,~ ~ • , __ ~ !~ I , _ i ~ I _ ~ i __ _-. ~ 1 _ - _ _..... -_- ---___.. - ~ .._ ~ , - ~ ~ _~^ H- i $ ~ ~ 0 ~ n --~_____ I ', { [ - '._...-. ~ ~ ~ __. . ~. -- _. .-...... I ~ _- __• i - ~ -~- ~ --_ ' --._.._..~... ~ -- - ~::.- - ~ _ ~ { I t -- - ....... I ~ _ _ _..._ - _ ~ ... i ~ ~____:_n_.. - I -. ~ ~ . _~_ -- ~ - ~- ......_ { 1 ._.-- - - - __j .._ ~ -"~M" -~~- "~' - '~' ~' • ~ ~ ~ + ~ -~ a.- ~~ Oa 0 1^50 a`6u 550 ~t000 ~7'aii 10500 1250 1i!]C10 I~FSD '175170 19~bQ X1000 h+f assured C~epth ~35QQ ~~n~ ~ LEIG ENQ GQ3-108, CQ3-IOB, GQ3.108 k./14 C03-108, GQ3.108, CQ3.100 4?5 C03-110, GQ3.110, CQ3.110 U"1~i CQ3-11 1, GQ3-111 , CQ3.111 11'T CQ3-i 1 1, CQ3.1 1 1 L1 , C Q3-1 1 1 L1 V1 CQ3.112, CQ3.11~, GQ3-112 CQ3-113, GQ3.113, CQ3-113 ~/8 GQ3-113, GQ3.113, CQ3-113wp04 1/0 GQ3-i i 4, CL3.114, CQ3.114'1/14 CQ3-307, CQ3.107, CQ3.107 t/i GQ3-307, GQ3-307, GQ3.307 V4 C03.307, Plan: CD3.107~, GQ3.107Awp01 V"1 CQ3-'310, CQ3.319, CQ3-318 1;+0 GQ3-318, CQ3.319~, GQ3-319Ay~0 GQ3.319, GQ3.319A:PB1 , GD3.319AP81 1r0 Plan: CQ3-109, Plan: CQ3-108, Plan: CQ3.108 ~wp011 • Plan: CD3-115, Plan: GQ3-115, GQ3.115wp03 L'4 Plan: GQ3-117, Plan: GQ3-117, CQ3.117wp0~ 119 Plan: CQ4-303, Plan: CQ4-3035T1, CQ4-303'STiwp08 CQ3-118wp03 15 February, 2008 - 16:00 Page 5 of 5 COMPASS Opsrolor. Fle Bf: w.a ay: sod.<. tooson Comments: ~+.~ Vt ~ eln++~" s Q D O U t 0 m 2 E m T N ConocoPhllgpa(AlOrkaJ In<. -WNS Warlarn Norlh Sbp. cD5-n ewpDS RN/A 15]8061.44 a 60035M.88 H Gdd Corteclbn: Ma9n.Mc 0.<Anaaon: Dip: Do0b8 Per Original VS Plane: Vlew VS Plane: POOL: CD3-118wp03 Plan: 13848" to 21450.01' MD CD3-114: 10826' to 18042' MD -O.Bd lob No: XN/A AA.48 AFE Na: RN/A 80.]5 API NO: NN/A AW n srd.m DvDJ a.l.r.no.: M..n Sen L.v.i 288.11 ° r.r.nr w.n; n.n:cD3-ne 288.11 RRB HaIOhY. 49.10 N Una Sphm: API Bored /FPS Sacllon (V5J Relaranca: Slol Plan View m m w m m m m ro m m ro w aD M o~~~ m a o o a o 0 0~ o N h ~ N 601DDDD ~I' 6009000 6008000 600700D 6006000 6005000 6004000 6003000 6002000 6001000 6000000 4000 5000 6000 7000 8000 0 0 0 ~ 0 0 0 0 0 0 0 0 0 0 0 o g o ~ o o g ~ S ~ g ~ g g °o ~ g g o S g S o 0 0 Vertical Section abng "View VS Plane' ,~ Closest in POOL i aosest Approach: Reference Well: CD3-118wp03 Plan Offset Well: CD3-114 Coords. - Coords. - ASP ASP -D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS iistance. Depth Angle TRUEAzi. TVD E(+)/W(-) (288.11°) Comments Depth Angle TRUEAzi. TVD E(+)/W(-) (288.11°) Comments POOL Min Distance POOL Min Distance (3386.06 ft) in POOL (3386.06 ft) in POOL (13848 - 21450.01 (13848 - 21450.01 MD) to CD3-118wp03 MD) to CD3-114 Plan (10826 - 18042 a3IIS.06 17825 90.02 322.72 6845.09 6005722 1515977 12138.65 (10826 - 18042 MD) 14878.01 90.34 322.79 6852 6007727 1518705 10277.94 MD) CD3-118wp03 PoolSummary.xls 2/15/2008 4:50 PM ~ ~ CD3-118wp03 Surface Location ~3 CPQI Coordinate Converter r~~~'_L~,c 'i Frtrm. __ - - T '~ C~~7riltY't ~"I~&L`~ ~tG,~.La~, ~aics=>~.a ~ C=~7tur~i ` t~~~f ~ Firgi..rt 7,;~J~~kd ~ I ~~ ~" IL..rr~,~e~'L~ng~ride ~LecimaiDegress ~ f` ~,rr„~c%~o~~aituda pr~rimalDegree~ ~~ F ~" UTM 2on~ r ____W~ j"` S~n:rh ~` LITt~i ~orfs: True ~ Sauth j f: a(e F9al,e -e~rtr ~ ,~ Ufli~s: uS~ft Sta~~~ F7aS~r ,,~~ne" q ~ I1raL`: ' uS-ft ~~ ~ Legal De-~:npt~on IfJ.kD2~ c~nEyl 'j ~rartiragCc~rdinate~ - - LegalDescription __ I ~~ 15~-~ 5'L164. ~d -~__ ~_ ~ Tov~~~ist~: 012 KJ f Range ~00~ E '1``. 600054.8$ -_.~., t 1 ri.1~.~n ll ~ ti. ~rr~c~ -_~ F~1L ~ j3979.D4?0 f=Et ~ 1010.6&0 '. Tran~(arm .__.._~~ CD3-118wp03 Intermediate Casing Point Ruh ~ ' He1~s ~3 CpAI Coor~fin~+te Converter ~ ' L-- ~. i ~~_~ ~r'rom. ~..... ~ .m_._ - To:- __'... _~_ _..~e~ .. __ - - C~~~?um: ~~D68 Region ~lasl~a ~ Daum: td~D27 ~ R3gx~n. alas{ta • ~- ~ Lyr,rude%L ~n,itude Decimal Degrees ~~~~~~ ~" Lat~udelLor~g!n_~dr Decimal Degrees f IJTt.4 gone: ~ ~' ~o~,,ii, ~ C` LtTM •~on~; True ~ youth J ~ ~ ~+ Stake PIar~F ~ or.e: 4 ~i I In~~~_ ;us ft ~~ r.yt~ Plane gone q ~ Units: us it .~ ~, ~! i '~ ~' LPG-~~ Dry rapt e~~~ ~rl~,D?7 arrk~l ~ { Starting Coordn,~~- -- -Legal Descriptir,~'~ --- ~ ~ _ 1--5'''1'a5?3.9n ~ T„ ~,,rnsh~. 012 ht ~ .Range: U~~ E ~~ ~ ~; ~4Ern~iar~ jj ~ c~hon ~12 - : l E ___._ FNL ~ 318.01217 FEL ~ 142.9879 ~' Transform Dui H_i _.;_ ...,~ _M .,;. $"~C u CD3-118wp03 TD: ~"~ CK'dE Coordinate Converter .~~' C : ~' j r ~ u: ^ _~_-- T ~ _ ..._ _____ j Da~u~n Idrs.GB~~ Re~~i_:r~ a~aka 'f Ci,;tun, t~lAD2~ ~1 `'"`n~_~n alaska -- ~~ La#~udePL~,ngitude Decimal C'sgrees ~ ~- Latitude~'Long~t'ade Decirtxal Degrees I) ,_. IJT~~~ ?rune: ~ ~`" ~out~r " ~ iTM ~=~~ie True ~ 5:~~,tf~, ~, ' f.' '.skate f'~dn? One; ~.,~ ~ Lit ai> ~~ft ~ ~ '~fJ~6 ~]tlE: .:4R@: ~ -.r ~1r"ut°_ ~u: =f ~-~ r: LF~aal Dessnption f1~,~D27 onl}~l ~taifirtgGtratdtttate: ~ f l>:rg~ICYesCtipki6n h: ~5i364~.7~i ~~..~ To~~vnship: 01~ ~Er~--~ Range- ~~d E ~+ '~: 660t~499.58 ---°~ ~ Meridian: U ~ ; t~~_,,, ~ w__~_. ~ ~ . __ _ F~JL ~ AS~,d. T 261 , : FEL ~229Q.~6~~+~ Tr~siorr~ ~~ _, Ouir ~ Help ~~~~~ ' 34/8/07 ~ AG ~ DB ~ C.A. ~ REVISED P(~I<P~7D41 ACS ~ 5 ~5/13/06~ CZ ~ DB ~ C~ UPDATED PER K06~35ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SECS, T 12 N, R 5 E, U.M. SEC. LINE 0 S EXIST WELL 'Y' `X` LAT.(N) LONG.{W) FSL F L GND PAD CD3-301 1. 1 7 1 150' 54' 45.411" 6 0' 7.3 13.5 CD3-302 6 003 616.72 1 528 376.38 70' 25' 09.124° 150' S4' 45.972" 1377' 700' 7.3 13.2 CD3-303 1 .7 150' 54' 46.547" 1 7 71 7.3 13.3 CD3-304 6 003 607.82 1 528 337.04 150` 54' 47.122" 1368' 739' 7.3 13.4 GD3-305 6 003 603.48 1 528 317.56 150' 54' 47.691" 1363' 758' 7.3 13.6 CD3-106 6 003 599.43 1 528 298.37 70' 25' 08.942" 150' S4' 48.252 1359' 77T 7.3 13.4 CD3-107 6 003 594.38 1 528 278.93 70' 25' 08.$90" 150' 54' 48.820 1354' 797' 7.3 13.2 CD3-108 6 003 589.85 1 528 259.61 70' 25' 08.842" 150' 54' 49.385 1349' 816' 7.3 13.1 CD3-109 6 003 585.27 1 528 239.85 70' 25 08.794 150` 54 49.962 1344 836 7.3 13.1 CD3-110 6 003 580.97 1 528 220.32 70' 25' 08.749" 150` 54' 50.533 1339` 855' 7.3 13.0 CD3-111 6 003 576.13 1 528 201.08 70' 25' 08.699" 150` 54' 51.095" 1334` 874' 7.3 12.9 CD3-112 6 003 572.43 1 528 181.20 70' 25' 08.660" 150' 54' 51.676 1330' 894' 7.3 13.1 CD3-113 6 003 567.62 1 528 161.38 70' 0 .6 150° 54 52.255 1 14 7.3 1 CD3-114 6 003 563.04 1 528 142.21 70' 25' 08.561" 150' 54' 52.815" 1320' 933' 7.3 CD3-115 6 003 558.57 1 528 122.60 70' 25' 08.515" 150' 54' 53.388" 1315' 953' 7.3 CD3-116 6 003 554.04 1 528 103.39 70' 25' 08.467" 150' 54 53.950 1311' 972' 7.3 CD3-117 6 003 549.51 1 528 083.99 7 .4 150' 54 54.516 1 9 1 7.3 CD3-X18 6 003 544,88 1 528 064.44 70' 25' 08.372" 150' S4' 55.086" 1 1 11' 7.3 CD3- 7.3 CD3- 7.3 CD3- 7.3 CD3- 7.3 CD3- 7.3 CD3- 7.3 ~~~ NOTES: 1. CODRDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2_ ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S:L ~.~ ALPINE MODULE:CD3~ UNIT: CD Con~coPhillips ALPINE PROJECT CD-3 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE N0. DRAWING NO: PART: REV: 15-03-03-1 A-2 3-17-05 CE-CD3-111 2 of 3 6 TRANSMITTAL LETTER CHECKLIST WELL NAME _ ~L.C ~ - ~l PTD# ~-'v ._ C.Z. ~ Development Service Explorato Strati ra h' ~ g Pic Test Non-Conventional Well FIELD: _C~w~~ r< 2w~~ 1 POOL: \.~ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is far a new wellbore segment of existing (If last two di its in well g API number permit No. ,API No. 50- - - 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), alt records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and AP[ 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 are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Well Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comaanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comnanv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: (/11/2008 WELL PERMIT CHECKLIST field & Pool COLVILLE RIVER, FIORD OIL -120120 !Nell Name: COLVILLE RIV F1ORD CD3-118 Program SER Well bore sag ^ PTD#; 2080250 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype S ER f PEND GeoArea 890 Unit 50360 OnlOff Shore ~ Annular Disposal ^ Administration 1 Permikfeeattaohed------------------------------------- -------- NA---- -----------------.-- ---------------------------------------------------- 2 _Lease numberappropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _(~o_ _ _ _ _ _ _ _ Addition made to 14.407: Surface in_AR13721Q5, top prod interval in ApL 425528,proa_interval _ _ _ _ . _ _ _ _ - 3 Uniquewellnameandnumber_______________________-__--_ ____-__Yes-__ ____alsoliesin_ADL-384Q92,andTpaies inADL389725______________-_._.___-________-___ 4 _WaillQCatedin_a_dafined_p9ol-----------------------------_ _______Yes___ ___CQI.VILLE-RIVER,FIQRpQl4•-12Q124,_govQrnfld_byCO569,----_.__---_------_.,__--_____- 5 Well located proper distance from drilling unitboundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - _ Conservation Order Ne. _589 ccntalns no spacing restrictions with respeetto drilling unit boundaries. _ _ _ _ _ _ _ . 6 Well located proper distance from Other wails. _ _ . _ _ _ . - _ _ . - _ _ - - _ _ _ _ _ Yes _ _ . _ Conservation Qrde[ No. 589 has nv int8rwall_spacingrastrictions_ __ _ _ _ _ _ _ _ _ _ _ _ - - _ _ . _ _ _ _ _ 7 Sufficient acreage available in drtUing unlt_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Conservation Order Ne._5Q9 has_no interwall_spacingre$trjclipns, tNelJbore will be-rocs than 5Q0' from _ _ _ _ _ _ _ 8 If deviated, is wellbare platincluded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ external property line where ownership or land9wnership-changes.- _ _ _ _ . _ _ 9 Oparatoronlyeffactedparq~---------------- ----- -- - - - -Yes--- -- - - ---- ---- ----- -- - ---- - - -- -- --- - 10 Operator bas_appropriatebondinforce - -- --- -- ---- ----- --Yes - -- -- - ------ - ---- - ---- ----~ --- - - - ~-- ----- 11 Permitcanbaissuedwlthautconservafionorder--------------~----- --------Yes--- ---,---------.---------------------------- - ------ -- - _-- Appr Date 12 Pe[mitcanbelasuedwiihctutadministralive_approval----------------- --------Yes--- -------------------------------------------------------------------_- SFD 2!2012008 13 Caaperm~beapprovedbefore15•day_wait----------------------- -- -----Yes--- --------------------------------.-------------,-----------------__ -- 14 !Nell located within area end sirataauthorized by_lnjection Qrder# (psrtlQ# in-comments)_(For- Yes _ . _ _ _ _ _ AtO.30, issued July 25, 2Q08- - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ---------- , 15 All wells:wilhkn 1(4_mile area_ot review ident[fied (For service well only)- - - -- - - - - - - - - -Yes _ _ _ _ _ - Nigliq-1A_is nearest weN, but It lies_at least 15Q0' away._ _ _ _ _ _ _ _ _ - - - - - - - - - , _ _ - - - - - - - _ - - - - - 16 Pre-produced ittjector; duratlan of preproduction less than 3 monihs_ (For service we4 only) _ _ Yes _ _ _ _ _ - tNlll_bepre-produced: for6 tc 12 moths, _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 _Konconven,gas-conformstoAS31,05,03QQ.1,A),O.~,A•p)-------------- --------NA---- ------------- ---------------------------------------------------------- Englneerfng 18 Conductor erring-Rrovided___________________________-__ __-___--Yes--- -__ -- ---------------------------------------------------------------- 19 SurfacecaeingprotactsallknownUSQWS_______________________ ________NA____ ____Noaquifers,_AIQ18A,conclusicn3._____-________---_--__,__--_----,-----_- -- 20 CMTvciadsquate_tor~rcuiateon_conductcr&surf-csg---------------- --------Yes--- --------------------------------------------------------------__ --- 21 CMTvoladequatetctie•inlongatripglossrrfcsg____________________ _________Ko____ _____-________-_____--_..-_---_----__----__-_ _-- ------------- 22 CMTwillcoverallknawnpr4duetlyabarizorts______________________ _______.Ho___ ____Open_hote_cempietionplanned,-_____________________--__.___-__--__-________ 23 Casing designs adequate forC,T,B_8~permafrost-----.----------- --------Yes-- ---------------------------------------------------------------- -- - 24 Adequate tankage_Qr reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Rig equipped with steel pits, No reserve p'lt planned._ All waste_to approved annuli. _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ 25 Ifa.ra-d[ili,has-a 10~t03f4rabandonmentbeenappr4ved-------------- --------NA---- -------------------------------------------.- -------------------------- 26 Adequata_vtallbore separatbn-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ Proximity analysis performed, Traveling cylinder path calculated, Gyros possible in surface, . - _ - - - _ - _ - - - 27 If_dlvetter_raquired, doss ft meek regutationa_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __NA_ _ _ _ _ _ _ _ piverter waiver recommended.. No issue in 11-prior surface_holes en pad, _ _ . - - _ - - - - - _ _ - - _ - _ _ - - Appr Date 28 Drilling fluid-program schematic &e4uip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - _ _ _ _ Maximum expected farmaticn pressure 8,7_EMW._ MW planned 9.4-9,3ppg._ _ . _ - - _ _ _ _ _ _ _ _ _ - TEM 212012008 29 6OPEs,_dotheymeetregulation-------- --- -- -- -- -- - - Yes--- ---- ---- -- ----- ---- ---- ------ --- -- ------ 30 BQP)r:press rating appropriate; test ko_fput psi in_commanis)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - _ _ _ _ MASP calculated at 2445psi, 3500_psi_SQP tesi_planned, _ - - - - - 31 Chcke_manifoldcompl~awlAPIRP-53W1ay84)-- -- ----------- - - -Yes--- ---- -- -- -- --- ------- -- --- - --- --- --- 32 VYorkwihcccurwithcutoperation~hutdowrr----- ------- - - - ----Yes--- -- -- -- ---- ------- -------- -- -- - - -- --- 33 Ispresonce-cfH2S gasRr~table----------------------------- ------- N°---- ----H2ShasnetbeenreportedatCp3._Righaasenso[s_andalarms,--------------------------- 34 _Mecbanlcalc9nditlon9fweltawithinAQRvarifisd(Forse[vicewellonfya______ ________Yes___ ___NGwsllswithin114mi1e.__-____-_____-______________-___-______-__.___ _ Geology 35 Permitcan be Issued w/o hydrogen_sulflde meass,res _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ Yes _ _ . . _ _ - Noneancountered in-previous walls irom_pad._ Rig has deckection syslems.and alarms, . _ - - _ _ - _ _ . _ _ _ - 36 Datapresented on potential 9verpressurezones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ - Expected resenolrpressure is 8.7_ppg;.prod_intervalwill be drilfedwith 9.4.9,3.PA9 mud.- _ _ _ _ _ _ _ _ _ _ - _ Appr Date 37 Seiamlc_ana~sis of shallow gas_zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ _ _ _ _ _ _ NA_ .. _ _ _ _ None encountered in-11_previous walls drilled tram this pad, SFD 212012406 8 eabed conditionsunreytifofisbore)-------- --- ------ - - - - ~- - - - _ _ _ _ _ _ - ------------------------- _ - -- ~-- -- -------- --- ---- ------ - --- --- ,39 Contactnamelphonetorweekly_p_rc9rassrepcrts[exploratcrycnlyj--------- ------- NA---- ------------------------------------------------------ Geologic Commissioner Dats: Engineering Date Public issione : Co 'o r ~~ ~~ pate ~ ~r~~ ^ O (~ Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. cd3-118.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 15 11:51:13 2008 Reel Header Service name .............LISTPE Date . ...................08/05/15 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/05/15 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Physical EOF comment Record TAPE HEADER Fiord MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 Mw0005700035 E. QUAM D. MICKEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD CD3-118 501032057000 ConocoPhillips Alaska, Inc. Sperry Drilling Services 15-MAY-08 MWD RUN 3 MWD RUN 5 Mw0005700035 Mw0005700035 J. BOBBITT J. BOBBITT D. BURLEY D. BURLEY 5 12N 5E 3978 1010 49.53 12.80 Page 1 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: cd3-118.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.750 9.625 3244.0 6.125 7.000 13694.0 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 - NO DATA ARE PRESENTED. 4. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), GEOPILOT ROTARY STEERABLE BHA (GP), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 4,5 ALSO INCLUDED BI-MODAL ACOUSTIC TOOL (BAT) FOR CEMENT EVALUATION ONLY. NO PROGRESS WAS MADE ON MWD RUN 4. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-3,5 REPRESENT WELL CD3-118 WITH API#: 50-103-20570-00. THIS WELL HAS A TOTAL DEPTH (TD) OF 21228'MD/6878'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 (SEDP). ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. Page 2 cd3-118.tapx File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPS RPM RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3217.0 3230.0 3230.0 3230.0 3230.0 3230.0 3254.5 STOP DEPTH 21171.5 21178.5 21178.5 21178.5 21178.5 21178.5 21228.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 2 3217.0 3 9203.0 5 13706.0 REMARKS: MERGED MAIN PASS. MERGE BASE 9203.0 13706.0 21228.0 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 DEPT FT 4 1 68 0 RPD MWD OHMM 4 1 68 4 RPM MWD OHMM 4 1 68 8 RPS MWD OHMM 4 1 68 12 RPX MWD OHMM 4 1 68 16 FET MWD HR 4 1 68 20 GR MWD API 4 1 68 24 Page 3 Channel 2 3 5 6 7 cd3-118.tapx ROP MWD FPH 4 1 68 28 8 First Last Name Service unit Min -Max Mean Nsam Reading Reading DEPT FT 3217 21228 12222.5 36023 3217 21228 RPD MWD OHMM 0.14 2000 13.9826 35898 3230 21178.5 RPM MWD OHMM 0.16 2000 12.2451 35898 3230 21178.5 RPS MWD OHMM 0.29 1650.86 9.8147 35898 3230 21178.5 RPX MWD OHMM 0.26 1650.82 9.05062 35897 3230 21178.5 FET MWD HR 0.24 174.77 1.47446 35898 3230 21178.5 GR MWD API 19.99 450.72 85.8759 35910 3217 21171.5 ROP MWD FPH 1.52 433.21 126.816 35948 3254.5 21228 First Reading For Entire File..........3217 Last Reading For Entire File...........21228 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File Ty[~e ................L0 Next Flle Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.001 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 32.17.0 9166.5 FET 3230.0 9152.5 RPx 3230.0 9152.5 RPS 3230.0 9152.5 RPM 3230.0 9152.5 RPD 3230.0 9152.5 ROP 3254.5 9203.0 LOG HEADER DATA DATE LOGGED: Page 4 05-MAR-OS SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 cd3-118.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~iny 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 1~ Insite 74.11 Memory 9203.0 3254.0 9203.0 61.6 64.5 TOOL NUMBER 119546 228269 8.750 3244.0 Fresh water Gel 9.70 40.0 9.2 300 .0 4.500 74.0 2.780 123.8 4.250 74.0 3.500 74.0 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 Page 5 ~ ~ cd3-118.tapx RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3217 9203 6210 11973 3217 9203 RPD MWD020 OHMM 0.14 2000 9.72178 11846 3230 9152.5 RPM MWD020 OHMM 0.16 2000 5.95321 11846 3230 9152.5 RP5 MWD020 OHMM 0.29 1308.03 5.48481 11846 3230 9152.5 RPX MWD020 OHMM 0.73 252.94 5.00989 11846 3230 9152.5 FET MWD020 HR 0.24 83.24 0.819486 11846 3230 9152.5 GR MWD020 API 39.01 188.75 114.034 11900 3217 9166.5 ROP MWD020 FPH 2.23 433.21 157.408 11898 3254.5 9203 First Reading For Entire File..........3217 Last Reading For Entire File...........9203 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSL2B.003 service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.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 FET 9153.0 13655.0 RP5 9153.0 13655.0 RPX 9153.0 13655.0 RPM 9153.0 13655.0 RPD 9153.0 13655.0 GR 9167.0 13668.5 ROP 9203.5 13706.0 Page 6 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: cd3-118.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ....... ..........0 Data Specification Block Type.....0 Log~iny 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 • 10-MAR-08 Insite 74.11 Memory 13706.0 9203.0 13706.0 61.9 84.8 TOOL NUMBER 119546 228269 8.750 3244.0 Fresh water Gel 9.70 40.0 9.1 400 6.6 2.900 70.0 1.520 140.0 2.000 70.0 3.200 70.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 7 ~ ~ cd3-118.tapx 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 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9153 13706 11429.5 9107 9153 13706 RPD MWD030 OHMM 2.93 43.16 7.23994 9005 9153 13655 RPM MWD030 OHMM 2.99 40.67 7.05206 9005 9153 13655 RPS MWD030 OHMM 2.52 42.28 6.45497 9005 9153 13655 RPX MWD030 OHMM 2.28 45.72 6.22473 9005 9153 13655 FET MWD030 HR 0.25 54.31 1.33396 9005 9153 13655 GR MWD030 API 30.55 450.72 122.316 9004 9167 13668.5 ROP MWD030 FPH 6 261.73 156.136 9006 9203.5 13706 First Reading For Entire File..........9153 Last Reading For Entire File...........13706 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......sTSL26.004 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 13655.5 21178.5 RPD 13655.5 21178.5 FET 13655.5 21178.5 RPS 13655.5 21178.5 RPX 13656.0 21178.5 Page 8 • • cd3-118.tapx GR 13669.0 21171.5 RoP 13706.5 21228.0 LOG HEADER DATA DATE LOGGED: 23-MAR-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 21228.0 TOP LOG INTERVAL (FT): 13706.0 BOTTOM LOG INTERVAL (FT): 21228.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.7 MAXIMUM ANGLE: 93.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 13694.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LO55 (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... .......... 0 Data specification Block Type..... 0 Logging Direction ................. DOwn Optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth units. .. .. ..... Datum Specification Block sub-type ...0 Page 9 Polymer 9.00 45.0 9.2 17000 4.5 .210 70.0 .090 169.0 .240 70.0 .270 70.0 cd3-118.tapx Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 RoP MwD050 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 13655.5 21228 17441.8 15146 13655.5 21228 RPD MWD050 OHMM 6.96 2000 21.3721 15047 13655.5 21178.5 RPM MWD050 OHMM 0.51 2000 20.3062 15047 13655.5 21178.5 RPS MWD050 OHMM 0.31 1650.86 15.2341 15047 13655.5 21178.5 RPX MWD050 OHMM 0.26 1650.82 13.9233 15046 13656 21178.5 FET MWD050 HR 0.36 174.77 2.07419 15047 13655.5 21178.5 GR MWD050 API 19.99 80.61 41.6815 15006 13669 21171.5 ROP MWD050 FPH 1.52 247.52 85.0691 15044 13706.5 21228 First Reading For Entire File..........13655.5 Last Reading For Entire File...........21228 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer service name .............LISTPE Date . ...................08/05/15 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/05/15 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comment5 .................5T5 LIS Writing Library. scientific Technical services scientific Technical services Page 10 Physical EOF Physical EOF End Of LIS File cd3-118.tapx Page 11
