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Home My WebLink About203-135CAUTION: 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 CD2-30 (PTD: 203-135) 30 day water injection monitor completion Date:Wednesday, December 3, 2025 12:38:27 PM Attachments:image001.png image002.png AnnComm Surveillance TIO for CD2-30.pdf From: WNS Wells Integrity Eng <WNSIntegrity@conocophillips.com> Sent: Wednesday, December 3, 2025 12:31 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Automation, AK Wells <akwellsautomation@conocophillips.com>; WNS Wells Integrity Eng <WNSIntegrity@conocophillips.com> Subject: RE: CRU CD2-30 (PTD: 203-135) 30 day water injection monitor completion Well Name: CD2-30 Facility: WNS PTD: 203-135 Well Type: WAG Injector AA Number (if applicable): Internal Waiver (Yes/No if applicable): No Type of Issue: Plan Forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): Chris- CRU CD2-30 (PTD #203-135) has completed the 30-day monitor on water injection. The IA showed pressure stabilization proving TxIA integrity while on water injection throughout the monitor period. CPAI intends to leave the well on water injection while the AA request is in process for continued water injection only due to known TxIA communication while on gas injection. Attached is a current 90-day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Office phone: (907) 265-6218 Cell phone: (907) 830-9777 From: Shulman, Mark Sent: Monday, November 3, 2025 10:17 AM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: CRU CD2-30 (PTD: 203-135) 30 day water injection monitor start (11/2/25) AOGCC Notification Chris, After reporting CRU CD2-30 (PTD 203-135) an TxIA AnnComm on gas during its 30-day gas monitor on 6/18/25. The plan forward was to get a 30-day water injection monitor to ensure the well has no AnnComm on water injection. The well was brought on water injection on 11/2/25 and CPAI plans to monitor the well for 30 days (until 12/3/25). The well passed a diagnostic MITIA to 3300 psi on 5/21/25. Attached is a 90-day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 It3.11I11 3000 N 2500 a v 2000 "y 1500 a` 1000 •11 A 300C U.11I1 w 200( i ° 150C a m y 100D m m Pressure Summary for CD2-30 ■NEEMENEniiiiiii�1111111■1■111■ ■INIMUMrA11L111illlll■■■■■■■■■■■■■ 1■■01'111'11■1■11111T1�1 IIIIIIIIII■II■1■ 1■111111111011 IIIIIII1I■III■11 I■IIIIIIIIIIIiii :�!� I■IIIIIIIIIIIIII IIIIIILII_I_IIIIII� ■11111111111111111�111��■■111111� ■■■�■■■■■■■■■■■■ I��1■■■�■III■ injectmn1 R n O rn 0 M N 0 M rl R n O rn 0 M N M M H M 0 M N In M rl R n 0 0 o H N N N N N o 0 o H N N N N N 1n o 0 0r� H N N N N m N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N Date 35 LL cn 30 10 50 — IA PRESSURE — OA PRESSURE — TUBING PRESSURE (PSI) — TEMPERATURE(DEGF) — DRY GAS (MSCFD) — MI GAS (MSCFD) — PRODUCED WATER(BPD) — SEAWATER (BPD) 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 CD2-30 (PTD: 203-135) 30 day water injection monitor start (11/2/25) AOGCC Notification Date:Monday, November 3, 2025 11:59:43 AM Attachments:image001.png AnnComm Surveillance TIO for CD2-30.pdf From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Monday, November 3, 2025 10:17 AM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: CRU CD2-30 (PTD: 203-135) 30 day water injection monitor start (11/2/25) AOGCC Notification Well Name: CD2-30 Facility: WNS PTD: 203-135 Well Type: WAG Injector AA Number (if applicable): Internal Waiver (Yes/No if applicable): No Type of Issue: Plan Forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): Chris, After reporting CRU CD2-30 (PTD 203-135) an TxIA AnnComm on gas during its 30-day gas monitor on 6/18/25. The plan forward was to get a 30-day water injection monitor to ensure the well has no AnnComm on water injection. The well was brought on water injection on 11/2/25 and CPAI plans to monitor the well for 30 days (until 12/3/25). The well passed a diagnostic MITIA to 3300 psi on 5/21/25. Attached is a 90-day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD2-30 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD2-30 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SBHP, Set A1 CD2-30 10/14/2023 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic 10.03/11/2019 jennalt NOTE: In order to facilitate diagnostics, the IA should be circulated to clean fluid. 12/6/2016 pproven NOTE: Troubled with TxIA communication, & recently has demonstrated an elevated sustained IA pressur 12/6/2016 pproven NOTE: TREE: FMC 4 1/16 5K TREE CAP CONNECTION: 7" OTIS 10/29/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 37.0 109.0 109.062.50 H-40 WELDED SURFACE 9 5/8 8.92 36.7 3,006.3 2,379.8 36.00 J-55 BTC PRODUCTION 7 6.28 34.6 11,481.1 7,304.5 26.00 L-80 BTCM OPEN HOLE 6 1/8 6.13 11,481.0 15,700.0 7,298.8 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.9 Set Depth… 10,838.2 Set Depth… 7,078.8 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 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) 32.9 32.9 0.10 HANGER 4.500 FMC Tubing Hanger FMC 3.958 2,795.8 2,258.7 54.47 NIPPLE 5.200 "X" Nipple 3.813" HES X 3.813 10,676.96,998.5 57.30 INJ 5.9854-1/2" x 1" Camco KBG-2 GLM w/DCK-2 SOV 2000 psi csg- tbg, H563 bxp Camco KBG-23.895 10,742.2 7,033.0 59.55 PACKER 5.940 Premium Baker Packer, 4-1/2" x 7" Baker Premier 3.850 10,810.9 7,066.3 62.26 NIPPLE 5.200 "X" Nipple 3.813" HES X 3.813 10,831.0 7,075.6 62.87 SEAL ASSY 4.500 7" x 4-1/2" non-sealing overshot - 6.56' Swallow Baker Poorboy 4.640 Top (ftKB) 10,832.6 Set Depth… 10,938.2 Set Depth… 7,122.3 String Max No… 4 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 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) 10,861.1 7,089.1 63.79 PACKER 5.970 4.5" X 7" BAKER S-3 PACKER w/ Millout ext. 5.97" OD x 3.875" ID BakerPremier 3.875 10,925.9 7,117.1 64.59 NIPPLE 5.200 4.5" "XN" NIPPLE HES XN 3.725 10,936.9 7,121.8 64.61 4 1/2" WLEG 5.000 4 1/2" WLEG 5" OD 3.875 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) 2,795.8 2,258.7 54.47 INJ VALVE 4.5" Injection Valve on 3.813" X-Lock Halliburt on MCX42816 78-2 10/14/2023 1.563 10,831.0 7,075.6 62.87 OVERSHOT TUBING CUT @ 10,830' RKB 1/20/2019 3.958 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) 10,676.9 6,998.5 57.30 1INJ DMY 1 2/17/2019Schlumb erger Camco DCK-2 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) 11,481.0 7,304.5 79.12 OPEN HOLE 6.125 6.125 CD2-30, 10/15/2023 9:15:59 AM Vertical schematic (actual) OPEN HOLE; 11,481.0-15,700.0 PRODUCTION; 34.6-11,481.1 FLOAT SHOE; 11,479.0- 11,481.1 FLOAT COLLAR; 11,391.5- 11,392.9 4 1/2" WLEG; 10,936.9 NIPPLE; 10,925.9 PACKER; 10,861.1 OVERSHOT; 10,831.0 NIPPLE; 10,810.9 PACKER; 10,742.2 INJ; 10,676.8 SURFACE; 36.7-3,006.3 FLOAT SHOE; 3,004.0-3,006.3 FLOAT COLLAR; 2,917.9- 2,919.3 INJ VALVE; 2,795.8 NIPPLE; 2,795.7 CONDUCTOR; 37.0-109.0 HANGER; 36.7-38.9 HANGER; 34.6-37.2 HANGER; 32.9 WNS INJ KB-Grd (ft) 43.91 RR Date 10/30/200 3 Other Elev… Elevation Hi t CD2-30 ... TD Act Btm (ftKB) 15,700.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032046500 Wellbore Status INJ Max Angle & MD Incl (°) 92.17 MD (ftKB) 12,258.37 WELLNAME WELLBORE Annotation Last WO: End Date 2/14/2019 H2S (ppm)DateComment SSSV: NIPPLE 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: AOGCC Notification CRU CD2-30 (PTD#203-135) Date:Friday, June 20, 2025 7:58:06 AM Attachments:image001.png AnnComm Surveillance TIO for CD2-30.pdf From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Wednesday, June 18, 2025 4:13 PM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: AOGCC Notification CRU CD2-30 (PTD#203-135) Well Name: CD2-30 Facility: WNS PTD: 203-135 Well Type: injector AA Number (if applicable): Internal Waiver (Yes/No if applicable): No Type of Issue: TxIA on gas Maximum Pressure (if applicable): Date of Occurrence (if applicable): 6/18/25 Chris, CRU CD2-30 (PTD#203-135) passed a diagnostic MITIA to 3,300 psi (5/21/25), but during the 30 day gas monitor, the well has demonstrated IA pressure build-up evidence to confirm that the injector in its current state has TxIA communication during MI injection. CPAI intends to WAG the well to water as soon as operationally possible for a 30-day monitor to confirm if the well has integrity during water injection. If the well passes the 30-day water monitor, CPAI intends to submit an application for Administrative Approval for WAG injection. A well schematic and 90-day TIO is attached. Please let us know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD2-30 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD2-30 2025-05-10 2450 1500 -950 IA CD2-30 2025-05-20 2180 1060 -1120 IA CD2-30 2025-05-21 1623 1000 -623 IA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD2-30 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SBHP, Set A1 CD2-30 10/14/2023 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic 10.03/11/2019 jennalt NOTE: In order to facilitate diagnostics, the IA should be circulated to clean fluid. 12/6/2016 pproven NOTE: Troubled with TxIA communication, & recently has demonstrated an elevated sustained IA pressur 12/6/2016 pproven NOTE: TREE: FMC 4 1/16 5K TREE CAP CONNECTION: 7" OTIS 10/29/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 37.0 109.0 109.062.50 H-40 WELDED SURFACE 9 5/8 8.92 36.7 3,006.3 2,379.8 36.00 J-55 BTC PRODUCTION 7 6.28 34.6 11,481.1 7,304.5 26.00 L-80 BTCM OPEN HOLE 6 1/8 6.13 11,481.0 15,700.0 7,298.8 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.9 Set Depth… 10,838.2 Set Depth… 7,078.8 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 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) 32.9 32.9 0.10 HANGER 4.500 FMC Tubing Hanger FMC 3.958 2,795.8 2,258.7 54.47 NIPPLE 5.200 "X" Nipple 3.813" HES X 3.813 10,676.96,998.5 57.30 INJ 5.9854-1/2" x 1" Camco KBG-2 GLM w/DCK-2 SOV 2000 psi csg- tbg, H563 bxp Camco KBG-23.895 10,742.2 7,033.0 59.55 PACKER 5.940 Premium Baker Packer, 4-1/2" x 7" Baker Premier 3.850 10,810.9 7,066.3 62.26 NIPPLE 5.200 "X" Nipple 3.813" HES X 3.813 10,831.0 7,075.6 62.87 SEAL ASSY 4.500 7" x 4-1/2" non-sealing overshot - 6.56' Swallow Baker Poorboy 4.640 Top (ftKB) 10,832.6 Set Depth… 10,938.2 Set Depth… 7,122.3 String Max No… 4 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 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) 10,861.1 7,089.1 63.79 PACKER 5.970 4.5" X 7" BAKER S-3 PACKER w/ Millout ext. 5.97" OD x 3.875" ID BakerPremier 3.875 10,925.9 7,117.1 64.59 NIPPLE 5.200 4.5" "XN" NIPPLE HES XN 3.725 10,936.9 7,121.8 64.61 4 1/2" WLEG 5.000 4 1/2" WLEG 5" OD 3.875 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) 2,795.8 2,258.7 54.47 INJ VALVE 4.5" Injection Valve on 3.813" X-Lock Halliburt on MCX42816 78-2 10/14/2023 1.563 10,831.0 7,075.6 62.87 OVERSHOT TUBING CUT @ 10,830' RKB 1/20/2019 3.958 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) 10,676.9 6,998.5 57.30 1INJ DMY 1 2/17/2019Schlumb erger Camco DCK-2 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) 11,481.0 7,304.5 79.12 OPEN HOLE 6.125 6.125 CD2-30, 10/15/2023 9:15:59 AM Vertical schematic (actual) OPEN HOLE; 11,481.0-15,700.0 PRODUCTION; 34.6-11,481.1 FLOAT SHOE; 11,479.0- 11,481.1 FLOAT COLLAR; 11,391.5- 11,392.9 4 1/2" WLEG; 10,936.9 NIPPLE; 10,925.9 PACKER; 10,861.1 OVERSHOT; 10,831.0 NIPPLE; 10,810.9 PACKER; 10,742.2 INJ; 10,676.8 SURFACE; 36.7-3,006.3 FLOAT SHOE; 3,004.0-3,006.3 FLOAT COLLAR; 2,917.9- 2,919.3 INJ VALVE; 2,795.8 NIPPLE; 2,795.7 CONDUCTOR; 37.0-109.0 HANGER; 36.7-38.9 HANGER; 34.6-37.2 HANGER; 32.9 WNS INJ KB-Grd (ft) 43.91 RR Date 10/30/200 3 Other Elev… Elevation Hi t CD2-30 ... TD Act Btm (ftKB) 15,700.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032046500 Wellbore Status INJ Max Angle & MD Incl (°) 92.17 MD (ftKB) 12,258.37 WELLNAME WELLBORE Annotation Last WO: End Date 2/14/2019 H2S (ppm)DateComment SSSV: NIPPLE 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 CD2-30 (PTD 203-135) AOGCC Notification Date:Tuesday, May 20, 2025 10:09:13 AM Attachments:image001.png From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Tuesday, May 20, 2025 9:43 AM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD2-30 (PTD 203-135) AOGCC Notification Well Name: CD2-30 Facility: WNS PTD: 203-135 Well Type: Inj AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): No Type of Issue: Plan forward Maximum Pressure (if applicable): N/A Date of Occurrence (if applicable): Chris, A point of clarity of on the 5/10/25 spike in IA pressure reporting with CRU CD2-30 (PTD 213- 135). OPS reported a frozen gauge and the well’s IA did not exceed the OPL of 2,400 psi on gas injection. CPAI will continue the 30 monitoring and diagnostics due to increase of IA pressure post bleed to ensure there is no TxIA communication. Please, let me know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 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: AOGCC Notification: CRU CD2-30 (PTD 203-135) Date:Monday, May 19, 2025 2:57:48 PM Attachments:image001.png AnnComm Surveillance TIO for CD2-30.pdf From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Monday, May 19, 2025 2:17 PM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: AOGCC Notification: CRU CD2-30 (PTD 203-135) Well Name: CD2-30 Facility: WNS PTD: 203-135 Well Type: Inj AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): No Type of Issue: Plan forward Maximum Pressure (if applicable): 2450 Date of Occurrence (if applicable): 5/10/25 Chris, CRU CD2-30 (PTD 203-135) is a WAG injector currently on gas injection. On 5/10/25, OPS reported the IA exceeding the OPL of 2,450 psi. (OPL is 2,400 psi on gas injection). The IA was bled down to 1,500 psi. and the IA has been increasing. CPAI plans on completing Initial diagnostics and putting the well on a 30 day monitor. Depending on results, proper notifications will be made as needed. Attached is the 90-day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD2-30 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD2-30 2025-05-10 2450 1500 -950 IA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD2-30 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: SBHP, Set A1 CD2-30 10/14/2023 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic 10.03/11/2019 jennalt NOTE: In order to facilitate diagnostics, the IA should be circulated to clean fluid. 12/6/2016 pproven NOTE: Troubled with TxIA communication, & recently has demonstrated an elevated sustained IA pressur 12/6/2016 pproven NOTE: TREE: FMC 4 1/16 5K TREE CAP CONNECTION: 7" OTIS 10/29/2003 WV5.3 Conversio n Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1615.06 37.0 109.0 109.062.50 H-40 WELDED SURFACE 9 5/8 8.92 36.7 3,006.3 2,379.8 36.00 J-55 BTC PRODUCTION 7 6.28 34.6 11,481.1 7,304.5 26.00 L-80 BTCM OPEN HOLE 6 1/8 6.13 11,481.0 15,700.0 7,298.8 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.9 Set Depth… 10,838.2 Set Depth… 7,078.8 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 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) 32.9 32.9 0.10 HANGER 4.500 FMC Tubing Hanger FMC 3.958 2,795.8 2,258.7 54.47 NIPPLE 5.200 "X" Nipple 3.813" HES X 3.813 10,676.96,998.5 57.30 INJ 5.9854-1/2" x 1" Camco KBG-2 GLM w/DCK-2 SOV 2000 psi csg- tbg, H563 bxp Camco KBG-23.895 10,742.2 7,033.0 59.55 PACKER 5.940 Premium Baker Packer, 4-1/2" x 7" Baker Premier 3.850 10,810.9 7,066.3 62.26 NIPPLE 5.200 "X" Nipple 3.813" HES X 3.813 10,831.0 7,075.6 62.87 SEAL ASSY 4.500 7" x 4-1/2" non-sealing overshot - 6.56' Swallow Baker Poorboy 4.640 Top (ftKB) 10,832.6 Set Depth… 10,938.2 Set Depth… 7,122.3 String Max No… 4 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 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) 10,861.1 7,089.1 63.79 PACKER 5.970 4.5" X 7" BAKER S-3 PACKER w/ Millout ext. 5.97" OD x 3.875" ID BakerPremier 3.875 10,925.9 7,117.1 64.59 NIPPLE 5.200 4.5" "XN" NIPPLE HES XN 3.725 10,936.9 7,121.8 64.61 4 1/2" WLEG 5.000 4 1/2" WLEG 5" OD 3.875 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) 2,795.8 2,258.7 54.47 INJ VALVE 4.5" Injection Valve on 3.813" X-Lock Halliburt on MCX42816 78-2 10/14/2023 1.563 10,831.0 7,075.6 62.87 OVERSHOT TUBING CUT @ 10,830' RKB 1/20/2019 3.958 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) 10,676.9 6,998.5 57.30 1INJ DMY 1 2/17/2019Schlumb erger Camco DCK-2 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) 11,481.0 7,304.5 79.12 OPEN HOLE 6.125 6.125 CD2-30, 10/15/2023 9:15:59 AM Vertical schematic (actual) OPEN HOLE; 11,481.0-15,700.0 PRODUCTION; 34.6-11,481.1 FLOAT SHOE; 11,479.0- 11,481.1 FLOAT COLLAR; 11,391.5- 11,392.9 4 1/2" WLEG; 10,936.9 NIPPLE; 10,925.9 PACKER; 10,861.1 OVERSHOT; 10,831.0 NIPPLE; 10,810.9 PACKER; 10,742.2 INJ; 10,676.8 SURFACE; 36.7-3,006.3 FLOAT SHOE; 3,004.0-3,006.3 FLOAT COLLAR; 2,917.9- 2,919.3 INJ VALVE; 2,795.8 NIPPLE; 2,795.7 CONDUCTOR; 37.0-109.0 HANGER; 36.7-38.9 HANGER; 34.6-37.2 HANGER; 32.9 WNS INJ KB-Grd (ft) 43.91 RR Date 10/30/200 3 Other Elev… Elevation Hi t CD2-30 ... TD Act Btm (ftKB) 15,700.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032046500 Wellbore Status INJ Max Angle & MD Incl (°) 92.17 MD (ftKB) 12,258.37 WELLNAME WELLBORE Annotation Last WO: End Date 2/14/2019 H2S (ppm)DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-30 COLVILLE RIV UNIT CD2-30 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 CD2-30 50-103-20465-00-00 203-135-0 W SPT 7089 2031350 1772 2103 2101 2101 2101 725 757 759 759 4YRTST P Matt Herrera 6/27/2022 MIT-IA Performed to 2900 PSI Per Operations 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 CD2-30 Inspection Date: Tubing OA Packer Depth 1350 2900 2850 2850IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220629145500 BBL Pumped:1.7 BBL Returned:1.7 Thursday, July 21, 2022 Page 1 of 1         MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r�^Y-2 _ 7�) ge 5/ DATE: Tuesday, April 30, 2019 ,,,,,(((( P.I. Supervisor / i9 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. CD2 -30 FROM: JefPJones COLVILLE RIV UNIT C132-30 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv, NON -CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD2 -30 IInsp Num: mitJJ190424102441 Rel losp Num: API Well Number 50-103-20465-00-00 Inspector Name: Jeff Jones Permit Number: 203-135-0 Inspection Date: 4/1/2019 . Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well c132-30 • Type Inj w TVD 7089 Tubing n3z n39 . N36 - I 1734 PTD 2031350 Type Test SPT Test psi nz IA 9302510 i 2470 2455 . BBL Pumped: r I a '' _BBL Returned: L4 OA 280 890 - 890 880 Interval) iNITAL P/F P Notes: Initial MITIA post rig workover,. Sundry # 319-002. 1 well inspected, no exceptions noted. Tuesday, April 30, 2019 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS i.:UL:LVCL; MAR 1 4 2019 uc- A 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Qpgtgtiohsa td ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ ertorate New Pool ❑ Repair Well ❑� Re-enter Susp Well ❑ Other: ❑ 2. Operator ConocoPhlllipS Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ Stratigraphic ❑ Service Q 203-135 3. Address: P. O. BOX 100360, Anchorage, 6. API Number: Alaska 99510 50-103-20465-00 7. Property Designation (Lease Number): 9. Well Name and Number: CRU CD2 -30 ADL 38075 ADL 387207 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 15,700 feet Plugs measured None feet true vertical 7,299 feet Junk measured None feet Effective Depth measured 11,481 feet Packer measured 10742, 10861 feet true vertical 7,305 feet true vertical 7033, 7089 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 feet 16 109' MD 109' TVD SURFACE 2,970 feet 9 5/8 " 3,006' MD 2380' TVD PRODUCTION 11,447 feet 7 11,481' MD 7304' TVD OPEN HOLE 4,219 feet 6 1/8 " 15,700' MD 7299' TVD Tubing (size, grade, measured and true vertical depth) 4.5" L-80 10,938' MD 7,122' TND Packers and SSSV (type, measured and true vertical depth) PACKER (TUBING) -PREMIER BAKER 10,742' MD 7,033' TVD PACKER (TUBING) - BAKER S-3 PACK 10,861' MD 7,089' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN - - - - Subsequent to operation: SHUT-IN - - - - 14. Attachments (required per 20 AAc 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development ❑ Service [Z Stratigraphic Q Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data GSTOR E] WINJ Q WAG Q GINJ ❑ SUSP [] SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1 319-002 Contact Name: Dusty Ward Authorized Name: Dusty Ward contact Email: Dusty. Ward@cop.com Authorized Title: Sr. Wells Engineer Contact Phone: (907) 265-6531 Authorized Signature: Date: Y13 ;ko let (l77- 31/5-119 ,ql /l /h RBDMSffPJMAR 14 2019 Form 10-404 Revised 4/2017 Submit Original Only WNS INJ WELLNAME CD2 -30 WELLBORE CD2 -30 r h -' Well AtW butes Max Angle & MD TD �0(lOCO�)��IpS FIeW NaTe Wellpore APYa We11Wre Sons ncl l') MD'nMa) Aq a. HKR) A eBl01 )11L. NLPINE Sn1039nd6p (ua IN.I 7 t> 5v > 1 -Ann U. v Crgbx4aa PM Last Tag VavalxMmeec lanEidl Annagtian I OepinnISIR I and Date 1 lest Mare By ........: .:.... ...............:::::::::... .....:::::::::::::::: hander. no Last Tag: GD2A0 Imasbor Last Rev Reason AnnWl'vm 1 End D. welllwre Leet Mod By Rev Reason: Post RWO NormaWp 2/1&219 CD2 -30 IOOSIOFFIDS Casing Strings Casuq Oee'nIpi o0lin, mpni Top IKKa1 Set OePfp I go, set gap,arrob... widen p... Grade Top To. CONDUCTOR 16 15.06 370 109.0 1090 62.50 An WELDED Caalrp paurlPlbn OOlinl ID lin) Top lltltBl aN Dep1r 11B(B) bM Depth INO)... WOLen ll,..Gnde Top TAreW SURFACE 9Us 8.92 367 3,006.3 2,379.8 3600 J-55 BTC Cagnd De¢tlpMn ODllnl ID ling TOP1aKB) Set CeptM1 IIMBI8q pM IN01-orae. (I I... Top Tnmd PRODUCTION 7 628 34.6 11,4811 7,3 4.5 26.00 L-00 BTCM 9Wm1OTOIc En d -IMO rvipp. a, 2,2sr,.7 INJECTION VALVE; 2A5.6 SURFACE 56.T3One Meridtl: toare.e Fa4e,.161422 Ndd-x, m,fi10a OVER SMOT. Ia9310 owner IOWA NiFgM.xN:10.035.a a 1? WLEG;10.65.a PRODUCTION', X611,4at 1- WEN HOLE. 11,481 0-15,700.0� Oran Dexnpnon OR ling to (in) Top IaKB) r-CeyA Main den Urban lrv0)_. WULen (1...(mtle Top Thread OPEN HOLE 61,8 6.13 11,481.0 15,]00.0 7,298.8 Tubing Strings Tubing Description 4Hn29 me,11con) TIPWB) aN oaplM1 IS I DelMnW111bY1) G,aEe Top Connxlion Tubing-PrOdUchon 4112 3.96 32.9 10,838.2 ],0]8.8 12.60 LA0 Hytl563 ComplWon Details Toplrvot Tap Incl Nominal Toppu9) MR.) (1) Hemoaa Co. co(in) 329 32.9 0.10 Hanger FMCTuNng Hanger 3,958 2,795.8 2,258, 54.4] Nipple -X XNipple 3.813" 3.813 W742.2 7,0337 59.55 Packer Premium Baker Packed, 4-117x]" 3.850 10810.9 7.0 66,1 6226 Nipple -X "X" Nipple 3.813" 3,813 10,8310 ],0)56 62.87 Seal Assembly 7"x4-12"non-sealing overshot-656'Swalbw 4.640 Tugrq DeacrlMan and Ma... 110(h) Tap M ilb SM Oeptn ML. sat CpN night Imperial Grant Top connmtbn Lower TUBING 4112 3.96 10,8326 10,9382 ;122.3 12.60 L-80 BTM Completion Details Top IND) Topind Nomindl Top MOg (OKB) I•) Item Oes Cam IOlim 10,861.1 7,0891 63.79 Packer 4.6" X T' BAKER 5-3 PACKER wl Millout net 5.97' 00 x 3.8]5' ID 109259 ],11].1 64.59 Nipple-XN 45"'XN"NIPPLE 3725 10936.9 7,121.6 Mot 4112"WLEG 4112"WLEG 5 J 3.8]5 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tap IND) roP Inks) (aa Top Ind r) I Des card Runoaq to H) 1FK I 4 ZOra i dAUA/jIeUJMUIIUN 3.013" X LOCK wI MCX INJ VIAVE ( NM04E 2782-1 ID18/2019 1.500 VALVE 10,8310 7,075.6 .]OVERSHOT ITUBING CUT F10,830'RKB1120/2019 3.958 Mandrel Inserts aL an N Tap (XKB) Top(iV0) Khoo Make MioEat OD (to) Sen,Taps -dr.-.h Typ Fort blxe nnl TRO Bun IPs9 Ran DNe Co. 1 10,676.9 6,998.5 Camco KBG-2 1 GAS UFT DMV 0.000 2/1]/2019 Notes: General 8 Safety End Dare I Annotatlon 10/29Y2003 NOTE: TRE C 4 1/16 5K TREE CAP CONNECTION: 7' OTIS 5l1 ]!2009 NOTE. View Schematic w/ Alaska SChemaME9.0 121612016 NOTE: Troubled wit TxIA communication. & recently has Uemonsbate l an elevated sustained IA prea5ur i 16 ISOTE. In Order W facilitate dlagoo fics, Me IA Should be circulated to clean fluid. Operations Summary (with Timelog Depths) CD2 -30 Rig: DOYON 25 Job: RECOMPLETION Time Log Stan Time End Time Dur (M Phase Op Cade Activity Code Tirrre P -T -X Operation SIa (n Depth (WS) Entl Depth (flka) 2/6/2019 2/6/2019 3.00 MIRU WELCTL RURD P Doyon 25 accepted @ 00:00 hrs on 00:00 03:00 Feb 6th, 2019. Prep tiger tanks and lines to well head. Rig up to pump down tubing. 2/6/2019 2/6/2019 0.75 MIRU WELCTL SEQP P Blow air through flow -back lines. 03:00 03:45 Flood w/ water and test to 3500 psi. Good test. Blow down lines. 2/6/2019 2/6/2019 1.25 MIRU WELCTL MPSP P Bleed pressure from IA f/ 1000 psi U 0. 03:45 05:00 Monitor IA. Pressure increased U 100 psi in 5 minutes. Rig up lubricator and test U 3500 psi. Good test. Remove BPV. 2/6/2019 2/6/2019 2.50 MIRU WELCTL KLWL P Displace well to 8.6 ppg seawater. 05:00 07:30 Stage pumps up to 5 bbis/min while holding 600 psi back -pressure on choke. Pressure 2030 psi. Total bbis pumped = 414. Volume monitored for bbis in = bbis out. 2/6/2019 216/2019 1.00 MIRU WELCTL KLWL P Offload 85 bbis from tiger tank to 07:30 08:30 truck. Resume pumping 50 bbis of 8.6 ppg seawater @ 5 bbis/min w. 1985 psi. Blow down lines. 2/6/2019 2/6/2019 1.50 MIRU WELCTL OWFF P Monitor IA for pressure build up. 08:30 1000 Open tubing and monitor. No pressure, no flow. 2/6/2019 2/6/2019 2.00 MIRU WHDBOP MPSP P Install BPV in profile. Rig up and test 10:00 12:00 BPV U 1000 psi from direction of flow for 10 min. Blow down lines. 2/6/2019 2/6/2019 1.00 MIRU WHDBOP NUND P Nipple down tree. Make up blanking 12:00 13:00 plug and install w/ 10 turns. 2/6/2019 2/6/2019 10.00 MIRU WHDBOP NUND P Rig up 50'sling. Pick up speed head, 13:00 23:00 IDSA + riser. Nipple up same. Install choke hose and position BOP stack. Nipple up all flanged connections, flow line and diverter bas, lik line, koomey hoses and flow nipple. 2/6/2019 2/7/2019 1.00 MIRU WHDBOP RURD P Pick up and make up 4-1/2" ported 23:00 00:00 1 test joint to XO. Make up floor vales. 2/7/2019 2/7/2019 3.50 MIRU WHDBOP NUND P Continue nipple up BOPE's. Flood 00:00 03:30 stack and choke lines. Conduct body test on initial rig up. Stale rep notified @ 3:15 am. 2/7/2019 2/7/2019 3.00 MIRU WHDBOP RURD P Change saver sub to XT39. Lubricate 03:30 06:30 1 1 1 choke manifold, manuals and HCR's. Page 1/5 ReportPrinted: 2114/2019 Operations Summary (with Timelog Depths) CD2-30 Rig: DOYON 25 Job: RECOMPLETION Time Log start Time End Time our (ho Phase Op Code Activity Code Time P-T-X Operation Stan Depth (ftKB) End Deptt(@KB) 2/7/2019 2/7/2019 9.00 MIRU WHDBOP BOPE P Test BOPE's. All tests performed to 06:30 15:30 250 psi law, 3500 psi high for five minutes each test with 4" and 4-1/2" test joints. Test annular, 2-7/8" x 5-1/2" LVBR's and UVBR's. Test choke manifold valves 1-15, choke and kill manuals and HCR's, 4" valve on kill line, 4" TIW, 4" dart valve, upper and lower IBOP. All tests done with 4" and 4-1/2" testjoint. Test manual and super choke t/ 2,000 psi for 5 minutes. Koomey drawdown test. Starting pressure 3050. After function 1725 psi. 200 psi build up with 2 pumps; 27 seconds. Full pressure with air: 134 seconds. Test witnessed by AOGCC Rep Lou Laubenstein. 2/7/2019 2/7/2019 0.50 MIRU WHDBOP RURD P Blow down lines. Rig down test 15:30 16:00 equipment. 2/7/2019 2/7/2019 1.00 MIRU WHDBOP RURD P Drain stack. P/U dry rod. Check for 16:00 17:00 pressure beneath BPV: no pressure. Pull BPV. 2/7/2019 2/7/2019 1.00 COMPZN RPCOMP HOSO P Pick up landing joint. Make up 5" 17:00 18:00 acme XO to 4-1/2" IBT joint + pup joint for space out. 2/7/2019 2/7/2019 0.50 COMPZN RPCOMP SVRG P Lubicate and service TDS 18:00 1830 2/7/2019 2/7/2019 2.50 COMPZN RPCOMP PULL P Continue make up landing joint & 18:30 21:00 FOSV. Make up to tubing hanger with 9 full rotations. Set down 10k. BOLDS. Pull tubing hanger with 150k (110k w/o block weight). P/U 20'. P/U Wt. 142k S/O Wt, 103K. 2/7/2019 2/7/2019 2.00 COMPZN RPCOMP SEQP P Pill pipe @ surface stack. Attempt to 21:00 2300 test surface lines t/ 3,000 psi. Leaks found on stand pipe and TDS washpipe. Replace seal ring on standpipe. Service washpipe. Test to 3,000 psi - test good. 2/7/2019 2/7/2019 0.50 COMPZN RPCOMP CIRC P CBU. Pump 225 bbls seawater @ 23:00 2330 1 r 400 gpm w/ 1750 psi. 2/7/2019 2/8/2019 0.50 COMPZN RPCOMP RURD P Blow down lines. L/D 4" pup, TIW and 23:30 00:00 XO's. Blow down TDS. C/O elevators. 2/8/2019 2/8/2019 1.50 COMPZN RPCOMP RURD P Clean and clear the rig Floor. Hold JSA 0.0 00:00 01:30 for pulling hanger and tubing. Monitor well on trip tank, zero gain/loss. 2/8/2019 2/8/2019 4.00 COMPZN RPCOMP PULL P Lay down 4 1/2" 12.6 PPF IBT tubing 10,280.0 8,348.0 01:30 05:30 from 10,280'to 8,348 feet. Monitor hole fill on trip tank. P/U weight 142K, Slack off weight 103K. Hold trip drill with crews. Good drill. 2/8/2019 2/8/2019 0.50 COMPZN RPCOMP SFTY P Perform AAR after kick drill with all 8,348.0 8,348.0 05:30 06:00 crew members. Recognize the difficulty of slabbing the IBT XO. Page 2/5 ReportPrinted: 2/1412019 Operations Summary (with Timelog Depths) CD2 -30 Rig: DOYON 25 Job: RECOMPLETION Time Log Sten Depth n De Start Time Ertl Time Dur (hr) phase Op Cme Act vi Coen N Time P -T- % Operation EM Depth (ftNB) 2/8/2019 2/8/2019 6.00 COMPZN RPCOMP PULL P Lay down 4 1/2" 12.6 PPF IBT tubing 8,348.0 2,580.0 06:00 12:00 from 8,348 feet to 2,580 feet. 2/6/2019 2/812019 4.50 COMPZN RPCOMP PULL P Lay down 4 112" 12.6 PPF IBT tubing 2,580.0 0.0 12:00 16:30 from 2580 feet to surface. Lay down chemical cut joint 27.44 feet. 247 joinst and 27.44 feet pulled from well. 2/8/2019 218/2019 0.50 COMPZN RPCOMP RURD P Rig down 4 1/2" handling tools. Clean 0.0 0.0 16:30 17:00 1 rig Floor. 2/8/2019 2/8/2019 2.00 COMPZN RPCOMP BHAH P Load strap and tally 4" HWDP, 4" drill 0.0 0.0 17:00 19:00 1 pipe, overshot and clean out BHA to polish top of fish. 2/8/2019 2/8/2019 2.50 COMPZN RPCOMP BHAH P Pick up overshot dean out BHA. P/U 0.0 269.0 19:00 21:30 50 K, S/O 52K. 218/2019 2/9/2019 2.50 COMPZN RPCOMP PULD P Trip in hole with overshot clean out 269.0 1,846.0 21:30 00:00 BHA on 4" XT -39 singles to 1846 feet. Drifting to 2.25'. Monitor displacement on trip tank. P/U 67K, S/O 72K. 219/2019 219/2019 6.00 COMPZN RPCOMP TRIP P Continue in the hole with the 1,846.0 6,487.0 00:00 06:00 Overshot / Cleanout BHA on 4" singles from 1846 feet to 6487 feet. Drifting pipe to 2.25', monitoring displacement Ion trip tank.. P/U 72K S/O 65K. 2/9/2019 2/912019 5.00 COMPZN RPCOMP TRIP P Continue in the hole with the 6,487.0 10,685.0 06:00 11:00 Overshot/ Cleanout BHA on 4" singles from 6487 feet to 10,685 feet. Drifting pipe to 2.25', monitoring displacement on trip tank.. P/U 174K S/O 124K. 2/9/2019 219/2019 0.50 COMPZN RPCOMP TRIP P Rack back two stands of 4" to wash to 10,685.0 10,685.0 11:00 11:30 top of fish. Calculated displacement 35 Wis. Actual 34.1 bbls. 2/9/2019 2/9/2019 0.50 COMPZN RPCOMP CIRC P Trip in hole to 10,687, start taking 10,685.0 10,687.0 11:30 12:00 weight, kelly up and wash from 10,687. 2/9/2019 2/9/2019 3.00 COMPZN RPCOMP REAM P Wash and ream with 235 GPM, 1020 10,687.0 10,835.0 12:00 15:00 psi, 30 rpm, 5-71K torque 1 to 6k WOB, from 10,687 feet to 10,839 feet. Noticed psi increase when O/S covered stump at 10,832 feet. Polish stump with 143 gpm, 540 psi, 30 rpm. Shut down rotary and slack off to 5k ADD, at 10,842, pick up to neutral weight at 10,835 feet. 2/9/2019 2/9/2019 3.00 COMPZN RPCOMP CIRC P Circulate and reciprocate from10,830 10,830.0 10,785.0 15:00 18:00 to10,785 feet. Pump two hivis sweeps at 423 gpm, 2900 psi. P/U 160k S/O 122k. 2/9/2019 2/9/2019 0.50 COMPZN RPCOMP TRIP P Rack back a stand, install FOSV. 10,785.0 10,785.0 18:00 18:30 2/9/2019 2/10/2019 5.50 COMPZN RPCOMP RGRP P Monitor well on trip tank while 10,785.0 10,785.0 18:30 00:00 installing shims on pipe racks in A& B tubes for future storage. Changes allow 4" to be stored on move and doubles to be layed down. 2/10/2019 2/10/2019 12.00 COMPZN RPCOMP RGRP P Continue changing out shims in tubs A 10,785.0 10,785.0 00:00 12:00 & B in pipeshed from 5' to 4". Monitoring well on trip tank. 2/10/2019 2/10/2019 4.00 COMPZN RPCOMP RGRP P Continue changing out shims in tubs A 10,785.0 10,785.0 12:00 16:00 & B in pipeshed from 5' to 4". Monitoring well on trip tank. CBU , 8 BPM , 1735 psi, 3250 strokes. 2/10/2019 2/10/2019 6.00 COMPZN RPCOMP TRIP P POOH with 4" drill pipe from 10,785 10,785.0 3,865.0 16:00 22:00 feet to 3,865 feet, laying down doubles. Lay down 111 doubles in pipe magazine. Page 315 ReportPrinted: 2114/2019 e Operations Summary (with Timelog Depths) CD2-30 Rig: DOYON 25 Job: RECOMPLETION Time Log Start Time End`nme our (m) Please Op code Acinn Code tY Time PJ4 operation Stan epth (n KB) End Depth (flKa) 2/10/2019 2/1012019 0.50 COMPZN RPCOMP SVRG P Service Top drive and prep casing 3,865.0 3,865.0 22:00 22:30 shed to lay down singles of 4" drill pipe. 2/1012019 2/11/2019 1.50 COMPZN RPCOMP TRIP P POOH with 4" drill pipe from 3,865 3,865.0 2,390.0 22:30 00:00 feet to 2,390 feet, laying down singles. 2/11/2019 2/11/2019 2.50 COMPZN RPCOMP PULD P Continue laying down 4" XT-39 from 2,390.0 0.0 00:00 02:30 2390 feet to surface. 2111/2019 2/11/2019 1.00 COMPZN RPCOMP BHAH P Lay down overshot / cleanout BHA. 0.0 0.0 02:30 03:30 Clean out boot baskets and magnets. Recover .11 Itis of metal. 2/11/2019 2/11/2019 1.00 COMPZN RPCOMP BHAH P Clear the rig floor for punning 0.0 0.0 03:30 04:30 completion. 2/11/2019 2/11/2019 3.50 COMPZN RPCOMP WAIT T Shut down for weather Phase 3 called. 0.0 0.0 04:30 08:00 2/11/2019 2/11/2019 0.50 COMPZN RPCOMP WWWH P Jet wellhead in preparation of running 0.0 0.0 08:00 08:30 completion. 725 GPM. 2/11/2019 2/11/2019 1.00 COMPZN RPCOMP RURD P R/U to run new completion, verity pipe 0.0 0.0 08:30 09:30 count and new completion equipment in shed. 2/11/2019 2111/2019 2.50 COMPZN RPEQPT PUTS P RIH with new completion on 4 1/2" L- 0.0 686.0 09:30 12:00 80 12.6 PPF HYD 563 tubing to 686 feet. Torque connections to 3.8K 2111/2019 2/11/2019 11.50 COMPZN RPEQPT PUTB P Continue to RIH with new completion 686.0 10,775.0 12:00 23:30 on 4 1/2" L-80 12.6 PPF HYD 563 tubing from 686 feet to 10,775 feet. Torque connections to 3.8K P/U 137K -0 S/O 104K. 2/11/2019 2/12/2019 50 COMPZN RPEQPT CIRC P Kelly up and wash down to top of fish 10,775.0 10,815.0 23:30 00:00 at 1 bbl/min 39 psi from 10,775 feet to 10,815 feet. 2/12/2019 2/12/2019 1.50 COMPZN RPCOMP PUTB P Wash down with new completion from 10,815.0 10,736.0 00:00 01:30 10, 819 feet to 10,839 feet with 4 1/2" tubing and locate indicator pins in overshot shear, on tubing stub. Tag no go at 10,842. P/U 20 feet and retag to confirm depth. Lay down 3 joints to 10,736 feet. 2/12/2019 2/12/2019 2.50 COMPZN RPCOMP PUTB P P/U space out pups. 1.98', 9.78', 10,736.0 10,835.0 01:30 04:00 9.75'., hanger, and landing joint. M/U head pin 6'4" pup, x-over, 4.5" IBT pup and hose. 2/12/2019 2/12/2019 2.00 COMPZN RPCOMP CRIH P Close annular and reverse in 370 bbls 10,835.0 10,835.0 04:00 06:00 corrosion inihibited brine at 4 bbl/min 380 psi. 2/12/2019 2/12/2019 0.50 COMPZN RPCOMP RURD P Drain BOP slack, blow down choke, 10,835.0 10,835.0 06:00 06:30 kill and fill up lines. 2112/2019 2/12/2019 1.50 COMPZN RPCOMP HOBO P Land hanger and pun in lock down 10,835.0 10,838.0 06:30 08:00 pins. P/U 139K, S/O 107K. Test hanger seals to 500/5000 psi for 10 mins. (Charted) 2/12/2019 2/12/2019 0.50 COMPZN RPCOMP PRTS P Drop 1.875 ball and rod to set Baker 10,838.0 10,838.0 08:00 08:30 packer. Pressure up to 2900 psi to set packer. Hold for 5 minutes. 2/12/2019 2/12/2019 1.50 COMPZN RPCOMP PRTS P Pressure test tubing to 4200 psi for 30 10,838.0 10,838.0 08:30 10:00 minutes, charted.Bleed tubing to 2000 psi, test annulus to 3000 psi. 30 minutes charted. Bleed off tubing and shear SOV. 2/12/2019 2/12/2019 1.00 COMPZN RPCOMP OWFF P RID all test equipment , lay down 10,838.0 0.0 10:00 11:00 landing joint, clean and Gear rig floor. Flow check well. No flow. Page 415 Report Printed; 2/14/2019 Operations Summary (with Timelog Depths) CD2 -30 Rig: DOYON 25 Job: RECOMPLETION Time Log Slert Time Eno Time our (h) Phase Op Code Activity Cale Time P -T -x Opembcn Start Depth (Ma) End DepN (ftKB) 2/12/2019 2/12/2019 0.50 COMPZN WHDBOP MPSP P FMC install HP BPV in hanger. Test 0.0 0.0 11:00 11:30 from direction of flow to 1000 psi for 5 minutes and charted. 2/12/2019 2/12/2019 2.00 COMPZN WHDBOP RURD P Break down squeeze manifold and rig 0.0 0.0 11:30 13:30 down same. Break down high psi mud line and injection line. Rig down hoses. Break down hole fill line, flow Pine and flow box. 2/12/2019 2/12/2019 2.50 COMPZN WHDBOP NUND P N/D BOP's and Riser, DSA, and FMC 0.0 0.0 13:30 16:00 speed lock, P/U and UD beaver slide. Noted 80 psi on IA and bleed down 8 gallons to cutting box. B/D return line. 2/12/2019 2/12/2019 3.50 COMPZN WHDBOP NUND P Install two way check and mobilize 0.0 0.0 16:00 19:30 tree to rig floor. Lower tree to wellhead, nipple up same. Test void to 5000 psi for 10 minutes. Dry rod in dart and test tree to 250/5000 psi for 5/5 minutes. 2/12/2019 2/12/2019 2.50 COMPZN WHDBOP MPSP P Pressure noticed when attempting to 0.0 0.0 19:30 22:00 pull BPV. Rig up lines to bled off pressure due brine expansion (8 gal). Pull BPV. 2/12/2019 2/13/2019 2.00 COMPZN WHDBOP FRZP P Rig up LRS to pump diesel in tubing 0.0 0.0 22:00 00:00 for freeze protection. Pump 105 bbls deisel down tubing taking returns to rig thru IA to pits. 3 bbl/min at 1000 psi and 1700 psi when finished pumping. Open tubing to IA and allow to u -tube from 22:50 to 24:00. Concurently install bridle line yokes and bridal up. , begin disconnect fluid interconnects. 2/13/2019 2/13/2019 1.50 COMPZN WHDBOP FRZP P Complete U -tubing diesel in tubag and 0.0 0.0 00:00 01:30 annulus, until 140 psi equalized on both sides. Blow down and rig down all lines. Wipe down tree and clean cellar area. 2/13/2019 2/13/2019 0.50 DEMOB WHDBOP MPSP P FMC set Type H BPV. Well secure @ 0.0 0.0 01:30 02:00 02:00 him. Tubing pressure=0 psi, IA=O psi, OA=520 psi. 2/13/2019 013/2019 4.00 DEMOB MOVE RURD P Adjust bridal lines and prep derrick for 0.0 0.0 02:00 06:00 scoping down. Check air pressure in all tires, rig down interconnects between modules, prep casing shed for move, secure surface equipment for next well. Set diverter line for CD2 - 162. Rig release @ 02:00 hm. Page 515 Report Printed: 2/14/2019 ALASKA OIL AND GAS CONSERVATION COMMISSION RIG INSPECTION REPORT INSPECT DATE -2/7/2019 AOGCC INSPECTOR Lou Laubenstem Rig I Doyon 25 Rig Contractor Doyon Operator JCPAI Well ICRU CD2 -30 Operation lWorkover Working Pressure, W/H Flange Working Pressure, BOP Stack Annular Preventer Pipe Rams Blind Rams Locking Devices, Rams Stack Anchored Choke Line Kill Line Targeted Turns HCR Valve(s) Manual Valves Flange/Hub Connections Drilling Spool Outlets Flow Nipple Control Lines I 7 0 0 0 MISCELLANEOUS Working Pressure Operating Pressure Fluid Level/Condition Pressure Gauges Sufficient Valves Regulator Bypass Actuators (4 -way valves) Blind Ram Handle Cover Control Panel, Driller Control Panel, Remote PPE P Well Control Trained P Housekeeping P Well Control Plan P P FAILURES: 0 Coil Tubing Unit? No ' Rig Representative R. Fritts Contractor Representative R. Reinhardt Permit to Drill # Inspection Location Pit Fluid Measurement Flow Rate Sensor Mud Gas Separator Degasser Separator Bypass Gas Detectors Alarms Separate/Distinct Choke/Kill Line Connections Reserve Pits Trip Tank Kelly or TD Valves Floor Safety Valves Driller's Console Flow Mon Flow Rate Indic Pit Level Indicat Gas Detection Monitor Hydraulic Control Panel Kill Sheet Current UIi];73��i� PTO Ro3-/3S Loepp, Victoria T (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Wednesday, January 16, 2019 8:55 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]CRU CD2-30(PTD 203-135, Sundry 319-002) RWO Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you very much again. Appreciate it. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, January 16, 2019 8:51 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD2-30(PTD 203-135, Sundry 319-002) RWO This may have been approved or will be this morning so the courier will deliver. From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Wednesday, January 16, 2019 8:48 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: FW: [EXTERNAL]CRU CD2-30(PTD 203-135, Sundry 319-002) RWO Victoria, I checked with the field, and due to the phase conditions yesterday and getting the cutter to Alpine, they re -arranged to have the CD2 -30 cut done on Friday, so I can hang tight for today and most of tomorrow. Thanks tons again for working with us. I think I got you everything I have in response to the questions for your review. Please let me know if you need anything else from me or want to chat through anything. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Ward, Dusty K Sent: Tuesday, January 15, 2019 4:48 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Subject: RE: (EXTERNAL)CRU CD2-30(PTD 203-135, Sundry 319-002) RWO Victoria, I double checked on the CBL and didn't see one w/ TOC called out. The calculated TOC was the planned TOC from page 182/228 of for CD2 -30 here: http://aogweb.state.ak.us/weblink/Browse.aspx?cc=1&dbid=0 That online document matched the hard copies I looked at as expected. (There was documentation and a partial log of the cement job on pages 159-166/228, but I didn't see anything called out as conclusive TOC. It sounds like they agreed upon adequate isolation and moved forward per that letter on page 159.) From my understanding, we call out the planned TOC as the calculated TOC on our summary pages as a reference. I'll try to reach you on the phone early tomorrow morning. Then I'm still waiting on the BOP schematics. Thanks. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, January 15, 2019 2:18 PM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: (EXTERNAL)CRU CD2-30(PTD 203-135, Sundry 319-002) RWO Dusty, Please provide a BOP schematic with configuration and the choke manifold schematic. Was a CBL run to determine TOC in the 7"? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeop(a)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. It you are an unintended recipient of this e-mail, please delete if, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. LoeooCalaska.aov THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Dusty Ward Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD2 -30 Permit to Drill Number: 203-135 Sundry Number: 319-002 Dear Mr. Ward: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.a laska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, -P 4�C4� Cathy Foerster Commissioner DATED this L -day of January, 2019. RBDMS�C JAN 1 61019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECD' ' °�; AN 0 4 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well El Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑+ . Change Approved Program[-] Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑+ 203-135 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 501032046500CX> 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A CRU CD2 -30 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 380075, ADL 387207 Colville River Field / Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MID) Junk (MD): 15,700' 7,299' 11481 7305 3383 NONE NONE Casing Length Size MD ND Burst Collapse Conductor 80' 16" 109' 109' Surface 2,970' 10" 3,006' 2,380' Production 11,447' 7" 11,481' 7,305' Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD WA N/A 4.500" L-80 10,937' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): PACKER - BAKER S-3 PACKER W/MILLOUT EXTENSION MD= 10861 ND= 7089 12. Attachments: Proposal Summary ❑ Wellbore schematic Ei 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development ❑ Service [] 14. Estimated Date for 3/2 019 0 I/2 /Lz% 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG EI GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dusty Ward Dusty Ward Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: Dusty.Ward@cop.com Authorized Signature: � — 3 -'do Icf Contact Phone: (907) 265-6531 Date: Oo COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: r{•t / \ Plug Integrity ❑ BOP Test ET- Mechanical Integrity Test 13 Location Clearance ❑ Other. 8a P -"C5 f f0 ,35-OQ P $- g !j-nnvIaf- pf-cve qtr <sf to 2,5-6'DP5 fna /�r n Post a C k t r fzJ •(7L p /Acro F -to /41p wbc,,,� c O/-rgy t i'7 hole Initial Injection MIT Req'd? Yes Ell/ No ❑/- _ l n'+rrV4t l /JC y' �ir7i�ZS • �/z J Spacing Exception Required? Yes ❑ No Id Subsequent Form Required: /0-104 APPROVED BY Approved by: �COMMISSIONER THE COMMISSION Date: "/ 15'` 9 0 R I G I N A L RBDMS,�AN 1 61010 Submit Form and Form 10403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. ttachmenis in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 12 Dec, 2018 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t^ Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner ConocoPhillips Alaska, Inc. (CPAI) hereby applies for Sundry Approval to workover Injector CD2 -30 (PTD# 203- 135). CD2 -30 was drilled and completed in October of 2003 as an Alpine WAG injection well. The well was briefly flowed back then put on WAG injection. In February 2009 the well experienced IA pressurization after a bleed down, but the well passed diagnostic integrity tests in response to the pressurization. The well began to show further T x IA communication and the S-3 packer was suspect as the leak point, the packer was attempted to re -set, which appeared to stop the leak activity. The well was put back on WAG injection in early 2010. The well was again suspect for TXIA communication in August 2011 due to suspected tubing packoff leaks and it was unable to pass an MIT -OA, so the well was shut in. In August 2013 the adapter flange was tightened and the packoff leak was eliminated so that the well passed an MIT -IA. The well was brought back on water injection, but showed T x IA communication again. In October 2013, an ultrasonic leak detection log showed a leak in the S-3 packer. In mid -2014 a resin job was pump in the IA and onto the packer to try and seal the leak. The well passed MIT -T and MIT -IA following the job, but then quickly showed TxIA communication again and was ultimately shut in on November 2014. In October 2016, the well was tested on water injection and passed 60 -day monitoring period. It was put on gas injection for about 7 months. IA pressurization was again noticed when the well was put back on water in September 2017. The well was shut in and became a RWO candidate to be repaired to gas tight connections and service. The well will have a plug placed in the XN-nipple profile in the tubing tail as a barrier to the formation. The tubing will be pulled down to the pre -rig cut. The well will be recompleted with a non -sealing overshot and a stacked packer with gas tight completion to surface. The new stacked packer will be set at approximately 10740' RKB, which is about 40' below calculated TOC and 740' MD above open hole interval. This Sundry requests a variance from 20 AAC 25.412 to allow the stacked packer to be set approximately 740' MD above the open hole interval. If you have any questions or require any further information, please contact me at 265-6531 Sincerely, Dusty Ward Senior Wells Engineer CPAI Drilling and Wells CO2 -30 Proposed RWO Completion 6.15" Open Hole @ 15700' RKB PROPOSED COMPLETION 4-1/2" 12.6# HYD 563 4-1/2" X landing nipple at —2374' RKB (3.812" min ID) Set up for Injection Valve. 4-1/2" Camco gas lift mandrels @ TBD Baker 4-1/2" Premier Packer xxxx' RKB (3.880" ID) 4-1/2" 12.6# HYD 563 4-1/2" X landing nipple at xxxz' RKB (3.812" min ID) 4-1/2" Non -Sealing Overshot @ —10740' RKB REMAINING COMPLETION LEFT IN HOLE Baker 4-1/2" S-3 Packer @ 10861' RKB (3.875" ID) HES XN nipple @ 10926' RKB (3.725" ID) Baker Wireline Entry Guide @ 10937' RKB CD2 -30 RWO Procedure Alpine Injector PTD #203-135 Pre -Rig Work 1. Confirm injection valve is removed. 2. Get additional SBHP. 3. Set plug in tubing tale XN nipple at 10926' RKB to isolate RWO from formation. 4. Cut tubing at 10830' RKB. 5. Confirm deepest GLM is open. 6. Confirm latest packoff tests passed. 7. Get CMIT-IA to 3,000 psi to confirm plug is holding. 8. Install BPV. Rig Work MIRU 1. MIRU Doyon 25. 2. Record shut-in pressures on the T & IA. Plug and packer should provide competent barrier. If there is pressure, bleed off IA and/or tubing pressure and pull BPV. Complete 30 -minute NFT. Verify well is dead. a. Primary barrier: Plug, packer and competent casing. KWF will be available as backup primary. b. Secondary barrier: Packoffs and Tree OR BOP. (BPV in place and confirmed in direction of flow while swapping tree to BOP and vice versa.) 3. Set BPV if pulled to bleed off pressure, confirm BPV, ND Tree, NU BOPE and test to 25%3,50_0 psi. Test annular 250/3_,-500 psi. a. MPSP of 3383 PSIG calculated from SBHP of 4106 psig at 11200' RKB (7229' TVD) on 2/23/2015. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. S. Pull 4-1/2" tubing with jewelry down to pre -rig cut at 10830' RKB. Install in 4-1/2" Gas Tight Tubing 6. MU 4-1/2" completion with non -sealing overshot, nipples (one set up for wireline conveyed injection valve), packer, and GLMs. RIH and confirm overshot has engaged tubing stub. 7. Space out, land tubing hanger and install packoffs. 8. Drop ball and rod and set packer top @ approximately 10740' RKB (7031' TVD) w/ completion. a. TOC calculated at 10700' RKB (7011' TVD). 9. Pressure test tubing to 4200 psi for 5 minutes. 10. Pressure test inner annulus to 3000 psi for 30 minutes on chart. ND BOP, NU Tree 11. Confirm pressure tests, then shear out SOV with pressure differential. 12. Install BPV. Confirm BPV. 13. ND BOPE. NU tree. 14. Freeze protect well. 15. RDMO. Page 1 of 1 v WNS INJ CD2 -30 (,.onocoPhlllips W'NAttrbutea MaX ngle&MD TD IboraAWllWI PwM Name SOt032048500 ALPINE ellmmsu�Nd INJ ndl°I mo(nne) ameNn ln&e) 92.1] 12,2583) 15,]00.0 Comment H20(ppm) I bele P Anesed BeerM).Mg�rse DMB 91 10/302003coxs W m A.,.. n IXRB) EnU DeM Anndlbn MOU By Entl Last Tag: Rev Reason: %1LL A-0INJ VALVE, 3ET CAT, Isess ppmven 1246=7 GLV C/O, SET PLUG, PULL PLUG __._.... _.. _... asmg rgs GsinB Desarl"on OD lin) 10(n) Top In6B1 BrtCepin (XKBI Set D¢pIM1 ITV01... WI/Len ll... Gu]e Ted Tnrmi CONDUCTOR 16 15.062 370 109.0 1090 6250 H-40 WELDED Cam, DascrlMe OD On) He list TOp(flK81 3N CMnIXKa) sM DM1n jND1._ WXLen 11... terata Talle. SURFACE 9510 8921 38.] 3,008336.00 J-55 BTC easing De"nielon Celln) ID(101 Top IXKBI Set—pre IfMB) BeL OepM (rvel... WtlLen 11... Grab Top Tnlmtl xA11GFR:32.6 PRODUCTION ] 6.276 34.6 11481 11],304.5 26.00180 BTCM Casing Demi— Oe On) Men, Toprygta) SateepMIDKB) Sal Oealn 11 u'... W1/Len11..,G,We Tap TnreM OPEN HOLE 6118 6.125 11.481.0 15,]00.0 7,298.8 Tubing Strings iu0inp haanplion String Ma.. ID(in oP IXKBI Bel DeMn Va.IM beide(NDI l,..Wt IINflll GmOe IDp LonnMion TUBING 41/2 3958 32.8 10,930.2 7,1224 12.60 L80 IBTM Completion Details Top IflK61 iop lTVpl (nKBI TOp lnd l°I headed ea OK co. Nominal ID (m) 32.8 32.0 10 HANGER FMC TUBING HANGER 4.500 2.374.1 2,Ot6.9 54.58 NIPPLE CAMCO DB NIPPLE 3.012 10,0612 7,009.1 8379 PACKER BAKER S-3 PACKER a MILLOUT EXTENSION 3.875 10,925.9 ],117.1 64.59 NIP HES XV NIPPLE (PXN PLUG) 3.25 Cox0umoR: s]D4na.0 10,938.9 ].121.8 84.81 VS WIRELINE ENTRY GUIDE 3. 5 Mandrel Inserts s NIPPLE: za]4a x4 e. N Top lttKO) Top(TVD) MKBI MaM MWeI C011n) Oen vaiw Type takn Type Portsltt lin) TROOun (psis Run Dace I cam 10746.] ]035.2 CAMCO KBG2 1 GABLIFT OMY BK 0000 0.0 1020I20t] Notes: General & Safety End OM An.- nnol —10/29/ 10429/2003 003 NOTE: TREE: FMC 411165K TREE CAP CONNECTION: 7.OTIS 5/92009 NOTE: Vl.SlhdnNticw/AlaWSchelmtic9A 12/612010 NOTE. Troubled math T%(A cnlmnunicalibn,&reMntly has demonstrated an alienated sustained IA passur TON72018 NOTE :InoKu.1to fadfilate diagnostics, the A should be dlculaled to dean fluid. BURFACE:.1d nes d GPBLIFT:10,]ea] s PACKPA:1.11 NIPPLE:10,g25.9 WLEG.Idus PRODUCTION: Ma.11.4811— OPEN HOLE: HAB+a15,]W.o— Loepp, Victoria T (DOA) From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Tuesday, January 15, 2019 2:59 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]CRU CD2-30(PTD 203-135, Sundry 319-002) RWO Victoria, I've reached out to get the BOP information. Will send it to you when I received it. I'll verify on if a CBL was run. I didn't see one on my first pass through the documentation. Do we have green light to make the pre -rig cut tomorrow at least though? Thank you very much. Will be in touch soon. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, January 15, 2019 2:18 PM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Subject: [EXTERNAL]CRU CD2-30(PTD 203-135, Sundry 319-002) RWO Dusty, Please provide a BOP schematic with configuration and the choke manifold schematic. Was a CBL run to determine TOC in the 7"? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeopPalaska. 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 Victoria Loepp at (907) 793-1247 or Victoria LoeppCaska.00v Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Monday, January 14, 2019 12:32 PM To: Ward, Dusty K Subject: Re: CD2 -30 Sundry Request We will at the least have your pre -rig cut approved by Wed Sent from my iPhone On Jan 14, 2019, at 10:18 AM, Ward, Dusty K <Dusty.Ward@conocophillips.com> wrote: Victoria, I hope this finds you well and that your new year is off to a good start. I left a message on your phone pertaining to the request below. I apologize to request this of you, but do you think you'll have time to get the RWO Sundry request for CD2 -30 (PTD#: 203-135) done mid-day Wednesday? This well moved up in the schedule, where our planned start would now be end of this month —1/29. - Because this is an Infector well, we'd need the approved Sundry before the Pre -Rig cut from my understanding. o (If 'verbal approval' to do the pre -rig cut is allowed, then that maybe a simple way to allow pre -rig work to move forward AND give you more time to review the entire scope.) - Due to logistics of getting the cutter we want to use to Alpine, they were hoping to Pre -rig cut this well on Wednesday. Please give me a holler if you have any questions. The well will be done on Doyon 25 with the BOPS and VBRs I believe you guys are familiar with. Thanks, your time is appreciated. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday, November 1, 2017 2:43 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: CRU CD2-30 (PTD 203-135) Update and Plan Forward Chris, CRU injector CD2-30(PTD 203-135) has undergone diagnostics for suspect IA pressurization as previously reported. The well was shut-in and a drawdown test was performed on the IA. The result of this initial drawdown test was inconclusive due to significant gas in the returns. The IA was circulated with new fluid to remove the gas entrained fluid. Following the circulation, DHD performed diagnostics and obtained passing results on a MITT, MITIA,and IA drawdown test. DHD had also previously obtained passing packoff tests. Based on these results,CPAI plans to restart the 30-day monitor on water injection with intent to pursue a water-only Administrative Approval if the well shows integrity on water injection. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED i-LI' 2 8 % 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Thursday, October 5, 2017 5:23 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE:CRU CD2-30 (PTD 203-135) Suspect IA Pressurization Chris, Another update on CRU CD2-30(PTD 203-135). Our DHD crew performed diagnostics today showing that the packoffs have pressure integrity. The IA pressure is showing sustained elevated pressure, however,and stabilizing above DNE (-2160 psi currently). We believe we'll need to set a plug in the tubing and circulate clean fluid to the IA in order to perform clear diagnostics. Our intent is to leave the IA pressure above the DNE level temporarily while waiting on this wellwork (anticipated to happen in the next few days) since bleeding the pressure further could compromise the freeze-protect volume and freeze the IA. Please let me know if you have any questions or disagree with this plan. Regards, Travis SCANNED :, From: NSK ell Integrity Supv CPF3 and WNS ' '; .t -s+ Sent:Wednesda, I ctober 04, 2017 10:28 AM To:Wallace, Chris D S )<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyle enden@conocophillips.com> Subject: RE:CRU CD2-30(PTD 213 35) Suspect IA Pressurization Chris, I wanted to update you on the status of CRU CD2-3i PTD 203-135),an injector that was previously reported for suspect IA pressurization. We are about a week into the water -Section monitor that started after the initial report,and operations is unable to keep the IA pressure below 2000 psi "'2300 psi at present). The production casing is 7", 26 lb, L- 80 pipe with a burst pressure rating of 7240 psi. DHD arrived in •ine yesterday to investigate. After an initial evaluation,the new plan forward is to shut-in and freeze protect the -II as soon as operationally possible. Since the problem at present is IA pressurization,we may forgo a MITIA at this time : d instead drawdown the IA to look for a leak rate to see if a leak detect log or other diagnostic work is warranted. Plea - let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 From: NSK Well Integrity Supv CPF3 and WNS Sent:Tuesday,September 26, 2017 5:40 PM 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday, October 4, 2017 10:28 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE:CRU CD2-30 (PTD 203-135) Suspect IA Pressurization Chris, I wanted to update you on the status of CRU CD2-30(PTD 203-135),an injector that was previously reported for suspect IA pressurization. We are about a week into the water injection monitor that started after the initial report,and operations is unable to keep the IA pressure below 2000 psi(-2300 psi at present). The production casing is 7", 26 Ib, L- 80 pipe with a burst pressure rating of 7240 psi. DHD arrived in Alpine yesterday to investigate. After an initial evaluation,the new plan forward is to shut-in and freeze protect the well as soon as operationally possible. Since the problem at present is IA pressurization,we may forgo a MITIA at this time and instead drawdown the IA to look for a leak rate to see if a leak detect log or other diagnostic work is warranted. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED Fiiil rom: NSK Well Integrity Supv CPF3 and WNS Se •Tuesday, September 26, 2017 5:40 PM To:Wa e,Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, '. ler<R.Tyler.Senden@conocophillips.com> Subject: CRU CD2- PTD 203-135)Suspect IA Pressurization Chris, CRU CD2-30(PTD 203-135) is an Alpine i •-ctor that is displaying suspect IA pressurization after being WAG'd to water injection. The well was WAG'd from gas injec '•n to water injection about three days ago, so CPAI plans to monitor the well for 30-days on water injection. If the well co . ues to exhibit suspicious behavior we will proceed with preliminary diagnostics, including a MITIA and packoff tests,and up: .te you as necessary. Please let me know if you have any questions or disagree with this plan. Attached is a schemati .nd 90-day TIO plot. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday, September 26, 2017 5:40 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: CRU CD2-30 (PTD 203-135) Suspect IA Pressurization Attachments: CD2-30 TIO plot 90-day 9-26-17.docx; CD2-30 schematic.pdf Chris, CRU CD2-30(PTD 203-135) is an Alpine injector that is displaying suspect IA pressurization after being WAG'd to water injection. The well was WAG'd from gas injection to water injection about three days ago, so CPAI plans to monitor the well for 30-days on water injection. If the well continues to exhibit suspicious behavior we will proceed with preliminary diagnostics, including a MITIA and packoff tests,and update you as necessary. Please let me know if you have any questions or disagree with this plan. Attached is a schematic and 90-day TIO plot. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED :Tr: 2 'a ,f 1 RECEIVED • • 2_03- 1,35 MAR 07 2011 2--`6 o'St WELL LOG TRANSMITTAL AOOCG To: Alaska Oil and Gas Conservation Comm. February 2, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOGGED 3 61/2011 M K.BENDER RE: Leak Detect Log with ACX: CD2-30 Run Date: 11/19/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-30 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20465-00 Leak Detect Log with ACX 1 Color Log 50-103-20465-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. NE® AP p3.j Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: iMvit& . '' • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Thursday,January 26, 2017 4:55 PM To: Wallace, Chris D (DOA) Subject: CD2-30 (PTD#203-135) Attachments: CD2-30 90 day TIO 1-26-17.PNG Chris— CD2-30(PTD#203-135) is nearing the end of a 60-day period of water injection to monitor the well for IA pressure increase. The 60-day time frame is complete on January 29, 2017. At that time,CPAI intends to swap the well to gas injection service and continue to monitor pressures for an additional 30-day time period. If suspect IA pressure increase is observed a follow up email with the plan forward will be sent. If pressures appear normal,we intend to treat the well as a normal MWAG injection well. Attached is a 90 day TIO trend. Please let me know if you have any questions or concerns with this plan. Thank you, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED FEB 1 0 2017 1 W H a a. Ga" aa' = � wwww H w 1- I- I- I-- u .__ 0000 Cn c, O C) C) 0 W N- Lf1 CO ,Cl CO 44 d CO D K( ,Il 8 O N — 0 co 0 0 U. N ul ul N N cf.CO M LCI SY S G 4J Z _4 W m NO C1 0 0 O¢. E CO C) C.-- O O C) CO O O 6l O ek 1- N CO CO CO CD CO 0 0 0 0 0 W N N N N N M N e- .- r ..- O O 9 0 0 0 0 0 JI M f'I M [n (°7 J N N N N N LL+ 00000 00000 CI n n n n n n CG Ul V Cl C'! CJ n Cr) CJ C7 +- .k.- .- -jBap •-• Ji a) N C ('- ('- , I I I t I 1 I 1 1 --- ' U_ u_ [n 5-, a d V C RI 0.1 3 CA C ti-1 k I MC, 9 n � V O C 3 E E O 07 U L NA d OC Z C / Q (LI - O 2 (O M C O N N N t N CO V '•-- N o a x� `a os .0m < Y ! . I I I ( I w a I dn n n n n n C] c_)O i I I I 4) c7 n n n n n n n C) 0 0 to A v� o u, o U' n UC n , z 0 a a c.)l c.-.c.-. (I r! uH El E E. r 'ACdli'0.M 11) NtzW isd • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, November 29, 2016 10:00 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: CD2-30(PTQ#243-135) Update 11-29-16 Attachments: CD2-30 90 day TIO trend 11-29-16.JPG Chris, CD2-30(PTD#203-135)was logged on water and gas injection and no leak was detected. Throughout the 30 day monitor period no IA pressure increase was observed. CPAI intends to leave CD2-30 online for an additional 60 days of water injection to monitor the well for IA pressure increase. At the end of the monitor period or if suspect IA pressure increase is observed a follow up email with the plan forward will be sent. Attached is a 90 day TIO trend. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn Well Integrity Supervisor ConocoPhillips Alaska, Inc. SCANNED JUN 2 8 2017 Desk Phone (907) 659-7126 Cell Phone (907) 943-0450 ' WELLS TEAM ConocoPhillips 1 W cce 5 • 0.a a aaa a z`ac - wwww ywwwI- I-- I- I- u _ = - 0 0 0 0 N! 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Tyler Subject: CD2-30 (PTD #203-135)Update to diagnostics Attachments: CD2-30 TIO plot.JPG Chris- This email is to serve as an update to the status of the diagnostics in which CPAI is performing on CRU CD2-30(PTD 203- 135). The well is currently 14 days into the 30 day water injection monitor period and the IA liquid leak rate was much smaller than anticipated. DHD calculated it to be approximately 0.03 gals per min. Due to the small leak rate it is CPAI's intentions to attempt the leak detect log while on water injection and if unsuccessful in identifying the leak source, swap the well to dry gas injection and reattempt the leak detect log. The theory is to attempt to change the acoustic signature and/or the leak rate enough so that the acoustic log is capable of identifying it. At the conclusion of the diagnostic logging on gas injection,the well will be returned to water injection for the remainder of the 30 day water injection period while the logs are processed. Depending on the results of the diagnostics,the proper paperwork will be submitted for continued injection or repair. Please let me know if you have any questions or disagree with the plan. Attached is the current 90 day TIO plot. Dusty Freeborn/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907) 943-0450 oWELLS TEAM SCANNED MAY 2 X017, ConocoPhillips Cr CRU CD2-3 203-135)Alpine water injector has been troubled by TxIA communication. A resin packer repair was pumped on 4/26/14, he well continued to exhibit TxIA communication during the subsequent diagnostic monitor periods and has remained shu since 11/5/14. CPAI intends to bring the well online for no more than 30 days to allow the TxIA communication to re-activate and[perform an ultrasonic log on the well to determine if the previously located packer leak remains the communication source or if there are any additional leaks The well will be shut in and freeze protected upon completion of the log. This informatid will be used to determine repair options or push the well toward RWO. Please let us know if you have any questionsardisagree with this plan. Dusty Freeborn I Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 illitWELLS TEAM ConocoPhillips 1 LJ • Q0000Q c7 CCCCCLCC _ W W W W u, LL1 F— F— I— I— U _ DOD O ul Cr. O O O O W N- kil CO kr) CO d CO CD K 4C, O O ✓i .-- O O O O tn a co Cn .n Tr 's a Ts c 4) a 4) W FO N O O O O O W CO O O N. r a CO 0 O,0 07 0 a )- un co CO CO CO CO W O O O O O N N N N N f i cNl r- r r M e-2 r r O C7 - 0 0 0 0 0 JI ?C i On C,) C,-, J OV OV CV N CV 64 0 0 0 0 00000 n ci c7 el c7 c3 *S r', c I Q � C. C] c. C] G —j8a — 0., co r- u.CO cc 1 I f i I 1 I I I CV di 0 i. ci - k Z e \-2...ase---' & V .. 0C ea .D lP CO C O 47, 63 V D C E OD E a - a O a' m U iii a3 r O C Z C Q OD 4J 4 m O LCD r' ih O O N N O N Q ea CTI ..:3' IiV a— ir- III II t E CI CJ n o .� » ) y c�5 d o o o o ry I, ip CJ VI O I.11O u7 Cl u, Z C t9V V el o Ci C9 r t+ N C CdlB!Gs OM 5inow isd • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, October 26, 2016 5:22 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: CRU CD2-30 (PTD 203-135) Report of diagnostic plan Chris, CRU CD2-30(PTD 203-135)Alpine water injector has been troubled by TxIA communication. A resin packer repair was pumped on 4/26/14, but the well continued to exhibit TxIA communication during the subsequent diagnostic monitor periods and has remained shut in since 11/5/14. CPAI intends to bring the well online for no more than 30 days to allow the TxIA communication to re-activate and perform an ultrasonic log on the well to determine if the previously located packer leak remains the communication source or if there are any additional leaks The well will be shut in and freeze protected upon completion of the log. This information will be used to determine repair options or push the well toward RWO. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne/Dusty Freeborn Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager(907)659-7000 pgr. 123 WELLS TEAM cow,s SCANNED MAY I 9 201? 1 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d03 - L35 Well History File Identifier Organizing (done) ~o-sided 111111111" 11111111 o Rescan Needed 1111111111111111 III RE¡eAN plcolor Items: o Greyscale Items: DI'7TAL DATA 1¢'Oiskettes, No. I o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ( Maria;> Date: if ¡ 4 oS- /s/ yY)':: Project Proofing 1111111111111111111 BY: C Maria) Date: Jd-- 14- DS /s/ mr BY: CMw , ;-j X 30 ,= 010 +;2.3 = TOTAL PAGES 113 ~ " i L AC (Count does not include cover sheet) m () D~:l~ T ~ ~ r 1111111111111111111 Scanning Preparation Production Scanning Stage 1 Page Count from Scanned File: J J L/- (Count does include '7r sheet) Page Count Matches Number in Scanning Prep.aration: V YES ( Maria) Date I d- I if- J 05" If NO in stage 1 page(s) discrepancies were found: BY: /s/ NO mp Stage 1 YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 1III111111111111111 10/6/2005 Well History File Cover Page.doc ,,i)°, 1//7, ,s,_ THE STATE � -..',:c-(--, C 2 C l S __ ----- ---- 333 'Nes' Sevc�ih A:'e��uc ^'r GOV .R NOR Si AN PARNELL Anchorage, Alaska 99501 3572 YET Main: 907.279. 433 �p dtLA.5'� Fax: 907.275.7542 ,GANMEC3 MAY 0 7 2014 Mick Davasher Sr. Wells Engineer 1 ConocoPhillips Alaska, Inc. ap3 ' ` P.O. Box 100360 ------------------------------ Anchorage, -�Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2-30 Sundry Number: 314-235 Dear Mr. Davasher: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i -7/4e_a7,______ Cathy P. oerster Chair DATED this l- day of April, 2014. Encl. RECEIVED STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMMI—ION APR j 4 2G11 • APPLICATION FOR SUNDRY APPROVALS 40511i- 20 l511i- 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Plug for Redrill r Frforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Fbrforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate Alter casino 9 r Other:Production Packer Repair F.- 2.Operator Name: 4.Current Well Class: , 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory r Development r 203-135 • 3.Address: Stratigraphic r Service 1. 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20465-00 - 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r - CD2-30 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380075,387207- Colville River Field/Alpine Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 15700 - 7299 - 11481' - 7305' - 10926' ' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 109' 109' SURFACE 2970 9.625 3006' 2380' PRODUCTION 11447 7 11481' 7305' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): open hole completion - open hole 4.5 L-80 10938 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER S-3 PACKER W/MILLOUT EXTENSION ' MD=10861 TVD=7089 NIPPLE-CAMCO DB NIPPLE •MD=2374 TVD=2017 12.Attachments: Description Sunmary of Proposal - r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/16/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r- WAG Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mick Davasher @ 265-6870 Email: Mick.J.Davasher@conocophillips.com Printed Name Mick Davasher Title: Sr. Wells Engineer Signature //l, Phone:265-6870 Date f-(—f/— /(4 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 2�\1--. 2..SG Plug Integrity r BOP Test r Mechanical Integrity Test VLocation Clearance r Other:ter1-c tAIti .z'S5cJ MdTdi� )-t ��,`�:'r 4rdS�''_`c l B,3�� c` vl� c$�dvl Spacing Exception Required? Yes ❑ No Er/ Subsequent Form Required: RBDMa' A I U 1 20 14 V _49APPROVED BY Approved by: ' )D"-----1--74--- ,{� COMMISSIONER THE COMMISSION Date: `i--kr---/4 Approvedp G t ons is a Id for 12 months tram the date of approval. Form 10-403(Revised 10/2012) ??Kilt41114111 Submit Form and Attachments in Duplicate leriF //5 / 11/ —`fo* i ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 10 April 2014 State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit— Request to repair leaking packer Dear Sir/Madam: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to repair the leaking packer in CD2-30 by placing a 115' resin plug on top of the packer. CD2-30 is an Alpine A and C injector that was drilled and completed in 2003. CD2-30 has been shut in for the bulk of the period since August 2011 due to T x IA communication. It was originally thought the leak path was in the pack-offs in the wellhead. The pack-offs were repaired in August 2013 and the well was returned to service as a water injector. In September 2013 the well was shut-in again due to continued T x IA communication. An Ultrasonic LDL was run on 10/17/2013 where the leak was found to be at the production packer. The leak was only detectable if the pressure on the IA was less than 400psi. The well has remained shut-in until it can be repaired. The objective of the proposed packer repair is to pump a 10.5ppg resin pill into the IA through the GLM. The resin pill will swap out with the lighter packer fluid and cover the leaking packer. It is intended to save the functionality of the GLM. After the resin cures, coil tubing will mill out the composite plug. CD2-30 will be returned to injection service after obtaining a passing MIT-IA. The attached proposal illustrates the plan forward. If you have any questions or require any further information, please contact me at 265-6870. Sincerely, 1/1/1 ,0691 Mick Davasher Wells Engineer CPAI Drilling and Wells ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 CD2-30 Packer Repair Procedure Outline 1. Set a composite bridge plug at 10,776' MDRT (30' below the GLM). 2. Pull Dummy Valve from GLM and install a Circulation Valve. 3. Rig up Coil Tubing. Pressure test PCE as required. 4. RIH with coil to 20' above the GLM and circulate two tubing volumes of 140 degF diesel through coil and up the TxCT annulus (this brings the coil and tubing to temperature to ensure the pumpability of the resin product). 5. When temperatures are sufficiently high, pump resin product into the IA with the following schedule: a. 140 degF diesel followed by; b. 10 bbls inhibited 9.0ppg brine c. 2.8 bbls 10.5ppg Resin d. 10 bbls inhibited 9.0ppg brine 6. Wait 30 minutes for resin to swap with IA fluid. 7. Pump 10 bbl solvent pill to contaminate resin in tubing, to jet across the GLM to ensure functionality of the GLM, and confirm circulation to the IA. 8. Rig down coil tubing. 9. Rig up Slickline 24 hours later. Pressure test PCE as required. 10. Confirm circulation from tubing to IA. 11. RIH and retrieve circulation valve from GLM. Install Dummy Valve in same GLM. 12. Rig down Slickline 13. After a minimum of 7 days since resin was pumped, perform a MIT-T and MIT-IA to 2500psi. If MIT-IA fails may need to pump another resin job. If this is done the GLM will be lost. 14. Rig up coil tubing. Pressure test PCE as required. 15. Mill out composite bridge plug. 16. Rig down coil tubing. 17. Return CD2-30 to injection service. -a 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 -_-\ WNS INJ CD2-30 ConocoPhillips __ � Mac Angle ItMD TD a.. •I (I�S310Y'Yi4fE0C I.-PPE IINI f.r.. r r_•-I. --„,,.s.„k.c `S 750 __ �- c n.Mwo .-'- C ..�aNIR 1e. l.e2ur caz-At',OVA 4`reY SSS:NFP_E IxI°� • � � 435' 183n.1'2032• e.eti 544.1. I�` 1..... Am%ran PLL'NEN SET P_C Orr I”1,32014 Casing Stings mile. Ic In! Tee 4.re w.lwe P55 r 254.men.. I.30m• 2..name CCNCl1C'S? w..fE 'SCC\ 4Ja �6n 5/6 1000 6.15241' WELDED 8. «.rs..x1 SLSFAC.e1r. con. �.e. +� �1a LseA 2,.v... .X GE. ..rwr S:.P4 5 -i X 61:1 #.� 3.0{6_' .79 J6.00 '.. E!T". 2545 O54 _ 1PI.I.I oos.111..1 aw YID 1215... 8.ar PI/O176.TCO, 617 54.6 6',45'.1 036.6. 26.20 L.88 13TLY Cw1..Q1r.. la*. 'tie P... I.C•66611771 I.Da.0Mh.. 2..Es rwre F OPENICLE �I s•.8 6125 11.161.3 15,006.0 0438 fatal' . I... l0P5 IN1�1 r.*�1..1r.1217LI---71 t"` I, 'U6'c 41 3 32 109361 12�LdS IETO ii Completion Detain .t... '"::::3A.,.7:201 . 4 reCP.H 0426.0.."s. ha: .0142-4N3t+ um lemeimeeetree %war 63 2,316.4 54 56 NPFP.E C4.510'.3 86 NIPPLE 7201.6 62.04 PtiF41a7P SI Pa:11EP6.1.1L_C1.17]RECSI'N 15 0 3.612 3.6'6 .aaar 0.1'0.1 56.3.N1°P_E CP.MC::SA/SIPPLE 3..45 ¢6111.1.-06.761611:.6. A '29365 7,1.'.6 :.4.61 AUG 55'I+ELNE 611H1 Ii116E Other In Rue iYYmelm>le retrievable plugs,vats,Pulps.Gish,et¢) an Pao ew44ral /1.74. 6 a e41 I .nI 'C P. . 6.4 v0.:: 1 '10. 652 M. .59 I`i.' 450 -4 3JPX2W PLW,7UCCk S?N SO �.W' 4•t:'6:C^ IT6.XC OAL 43r)®tons Mandrel rlseens SI 7. 756 7-rcl 1 1 001. w I 1 7 61 ,35^.2:AMC •& -TT12 14.4AS. T TW+ 9 '.. 5048 CI 181`:513 'Votes:General&Safety end Cad* Maillmida• .5441-1X. ♦l._. .-EE FMC 4 1,16 56 7'6E5 CAP 03N+EPCTleN.770-5 t16'73.53--INC 0.Stew•x r.n.lc..New 5u516.1.61k9C li .m m r, Fh I • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 CD2-30 ✓ Downhole Diagram Sketch ConocoPhillips POST—Resin Packer Repair Alaska Co16" dur(Driven): A % , ik 16"Conductor 109'MD/TVD DB Nipple:2,374.1'MDRT NM Surface Casino: A 9-5/8",36ppf,J-55,BTC k. Set @ 3,006.3'MDRT Tulin : 4-1/2",12.6ppf,L-80 IBTM Tubing Tail at 10938.2'MDRT Approx.115'resin product in GLM:10,746.7'MDRT MI IA from Packer to GLM. Top of resin at 10,746.7' MDRT. Composite plug set at 10,776,7'MDRT(to be milled out after resin Baker S-3 Packer 10,861.2' placement) MDRT1110 XN Nipple:10,925.9'MDRT WLEG:10,936.7'MDRT i Production Casino: 7",26ppf,L-80,BTCM Ii..... Set at 11,481'MDRT \+ 1 Open Hole• 15,700'MDRT 7,298.8'TVD OF T4 • • / „.c s THE STATE Alaska Oil and Gas ofALAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF A y�P Anchorage, Alaska 99501-3572 Main: 907.279.1433 sum ED Fax: 907.276.7542 sum Duncan Hyden Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2-30 Sundry Number: 313-591 Dear Mr. Hydenr: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / is)L616 Cathy P. 'oerster Chair, C.mmissioner DATED this day of November, 2013. Encl. • • . \'l5 c4 STATE OF ALASKA NOV 14 2013 ALASKA OiL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrit❑ Perforate New Pool ❑ , Repair Well ® Change Approved Program Suspend❑ Plug Perforations❑ Perforate ❑ -Pull Tubing 0 Time Extension Operations Shutdown❑ Re-enter Susp.Wet ❑ Stimulate❑ Alter Casing❑ Other ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Dill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑ 203-135 - 3.Address: Stratigraphic ❑ Service 6.API Number. P.O.Box 100360 Anchorage,AK 99510-0360 50-103-20465-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing ki this pool? CD2-30 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation{Lease Number): 10.Field/Pool(s): ADL 380075, 387207 - Colville River Field/Alpine River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 15,700 7,299 11,481 7,305 Casing Length Size MD ND Burst Collapse Structural Conductor 80 16 109 109 Surface 2,970 9.625 3,006 2,380 3520 1717 Intermediate Production 11,446 7 11,481 7,305 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 4.5 L-80 10,937 Packers and SSSV Type: SSSV:Camco DB Packer: Packers and SSSV MD(ft)and TVD(ft): • SSSV:2,374'MD,2,017'ND Backer S-3 1, Packer:10,861'MD,7,089'TVD 12.Attachments: Description Summary of Proposal Q . 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 151.- 14.Estimated Date for 1/7/2014 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ r j 91NJ , WAG [ Abandoned ❑ Commission Representative: //'4.t-/3 GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Duncan Hyden @ 285-6862 Email Durlcan.P.HvdenCvcop.corn Printed Name Duncan Hyden Title Drilling Engineer Signature ------, Phone 265-6862 Date " � � l f 1 ' sion COMMISSION USE ONLY ° approval: Notify of a Commis so that a representative may witness Sundry Number: fY 2,,'2) — '5"`(. Plug Integrity ❑ BOP Test Q/ Mechanical Integrity Test V Location Clearance ❑ Other: # LIOa) Ds,,, 4070 ICS Spacing Exception Required? Yes ❑ No g Subsequent Form Required: `Q — /'jf 6 1 APPROVED BY Approved by COMMISSIONER THE COMMISSION Dater // Z 2 -L --?"03 14 45/l3 Submit Form and Form 10-403(Revised 10/2012) Appro app ctt q�2 onths from the date of approval. Attachments in Duplicate -/ I V H .0'10-71, ASDMS NOV 25 2a • NOV 14 2013 ConocoPhillips Alaska GCC P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 13 November 2013 Commissioner Dan Seamount State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover Alpine Well CD2-30(PTD 203-135). Well CD2-30 was drilled and completed in 2003 and was pre-produced before being turned around as an injector in February 2004. This well was shut in in August 2011 after experiencing TxIA communication through what was believed to be a tubing packoff leak.After tightening the tree adapter flange in August 2013, CD2-30 passed an MITIA and positive pressure packoff test. CD2-30 was brought online August 15th,2013 with permission for waivered water injection for or diagnostic work. Continued injection resulted in TxIA communication and CD2-30 was shut in September 22"d, 2013.The well failed an inner annulus drawdown test on September 27th, 2013. Further testing was indicative of a one-way packer leak. The purpose of this workover is to restore mechanical isolation by cutting and pulling the existing 4-W tubing above the existing packer and running a new 4-1/2"tubing string above a stack packer which will overshot the tbg stub atop the existing packer. If you have any questions or require any further information, please contact me at 265-6862. Regards, Duncan Hyden Drilling Engineer CPAI Drilling and Wells • • CD2-30 Horizontal Alpine Injector Expense Rig Workover PTD #: 203-135 Current Status CD2-30 is currently SI awaiting RWO operations. Scope of Work ♦ Pull 4-%" L-80 tbg from well ♦ MU &TIH w/new 4-%" L-80 stack pkr assembly ♦ Set Premier pkr, shear PBR • Space out& land new 4-%" L-80 stack pkr assembly General Well info MASP: 2,651 psi using 0.1 psi/ft gas gradient Reservoir pressure/TVD: 3,377 psi/7,259'TVD Measured w/Spartek gauges on 21 April 2013 Wellhead type/pressure rating: FMC Gen I 2-1/16°x 11" 5M BOP configuration: Annular/Pipe/Blind/Flowcross/Pipe TIFL/MIT-IA/MIT-OA: IA-DDT—LDL showed leak at packer 10,861' MD October 20, 2013 CMIT-T+IA—passed on October 4, 2013 MIT-IA—passed on September 27, 2013 IA-DDT—failed on September 27, 2013 Well Type: Injector Estimated Start Date: 04 January 2014 Production Engineer: Dan Kolesar RWO Engineer: Duncan Hyden Work: 265-6862 Cell: 317-1910 E-Mail: Duncan.P.Hyden @cop.com • • Proposed RWO Procedure: Pre-Rip Well Work 1. Attempt to pull X plug and obtain an updated SBHP 2. Reset X plug w/catcher 3. Cut 4-1/2"tbg 4. Set BPV RU.Test,and Pull Tba 1. MIRU Rig. Accept Rig and take on fluids. Pull BPV, circulate 10.3 ppg KWF around 2. Install BPV, ND tree, NU BOPE, install blanking plug, function and PT BOPE to 250/4000 psi and annular to 250/3500 psi 3. Pull blanking plug & BPV. Screw in landing jt, BOLDSs, and pull tbg hgr to the rig floor. 4. LD tbg hgr and TOOH sideways w/4-'/2" L-80 IBTM tbg NOTE: If tbg is not cut RU HES E-line for 2"d tbg cut Run 4-%"GL Completion 1. MU and TIH w/4-%" L-80 stack pkr to just above existing tbg stub 2. Spot— 15 bbls 10.3 ppg NaCI/NaBr brine around Po' Boy overshot, pkr, and PBR. Locate tbg stub, run X plug on wireline to set Premier pkr. 3. PT tbg 3500 psi and IA to 3500 psi 30 min each and record on chart. Shear PBR upon successful PTs. 4. MU 4-%" L-80 tbg, space out, and land completion. 5. Set 2-way check. ND BOPE. NU tree and pressure test tree and packoffs to 250/5000 psi. 6. Pull 2-way check. Displace well to CI Brine w/freeze protect. Set BPV. 7. RDMO Rig. Post-Rig Work: 1. MIRU HES Slickline 2. Pull BPV 3. Pull X plug 4. Drift for tag 5. Handover to Ops via handover form for POI... 14)i-l-nL5sef2 M( i- IA fZ 5 .6'."C4�e-P 1-µd WNS INJ S CD2-30 • ` Conoco Phillips Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status Inc!(7 MD(ftKB) Act Btm(ftKB) 501032046500 ALPINE INJ 92.17 12,258.37 15,700.0 ••- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD2-30,102820132:04.45 PM SSSV:WRDP Last WO: I 43.91 10/30/2003 Vertical schematic(actual Annotation Depth(ftKB) End Data Annotation Last Mod By End Date Last Tag Rev Reason:WELL REVIEW/TD CHECK osborl 10/26/2012 ................................_...._......_........,._..,,...,....,,.....,,,.,.,....,,,..,......,,.-_Casing Strings Casing Description OD(inl ID eel Top IftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 37.0 109.0 109.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread l�_ SURFACE 95/8 8.921 36.7 3,006.3 2,379.8 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread HANGER,32.8 }. ▪ PRODUCTION 7 6.276 34.6 11,481.1 7,304.5 26.00 L-80 BTCM ] • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...•Wt/Len(I...Grade Top Thread ;;- OPEN HOLE 61/8 6.125 11,481.0 15,700.0 7,298.8 i. Tubing Strings Tubing Description String Ma...ID(n) Top(ftKB) 'Set Depth(ft..'Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.958 32.8 10,938.2 7,122.4 12.60 L-80 IBTM Completion Details 1 Nominal ID Top(ftKB) Top(ND)(ftKB) Top loci(°) Item Des Corn (in) 32.8 32.8 0.10 HANGER FMC TUBING HANGER 4.500 2,374.1 2,016.9 54.56 NIPPLE CAMCO DB NIPPLE 3.812 ,w• •-■• 10,861.2 7,089.1 63.79 PACKER BAKER S-3 PACKER w/MILLOUT EXTENSION 3.875 10,925.9 7,117.1 64.59 NIPPLE CAMCO'XN'NIPPLE 3.725 CONDUCTOR;37.x I109.0 10,936.9 7,121.8 64.61 WLEG WIRELINE ENTRY GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc' VALVE;2,374.0 g0. Top(ftKB) (ftKB) (°) Des Com Run Data ID(in) NIPPLE;2.374.11 2,374.0 2,016.8 54.56 VALVE 3.813"A-1 INJECTION VALVE(SN:HYS-445) 3/112012 1.250 Mandrel Inserts St Ott c on Top(TVD) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 10,746.7 7,0352 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 2/1/2004 Notes:General&Safety End Date Annotation 10/29/2003 NOTE:TREE:FMC 4 1/16 5K TREE CAP CONNECTION:7"OTIS 5/17/2009 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE;36.7-3,006.3 GAS LIFT;10,746.7 :1 I-1 1 1 PACKER,10,861 2 fTL—' ems` 5.1-4-n) irj1 'NIPPLE;10,925.9 I ( Cyt I 'Mi WLEG',10,936.9 PRODUCTION;34,6-11,481.1 OPEN HOLE,11,481.0-15700.0 Wallace, Chris D (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Sunday, October 20, 2013 10:08 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Kolesar, Dan J; Dethlefs, Jerry C Subject: RE: Request to return Alpine injector CD2-30 (PTD 203-135)to water injection 08-14-13 Chris, An Ultrasonic LDL was run and found a leak in the packer @ 10,861. The well will remain shut in until a rig workover can be done to repair the leak. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons SCANNED `' " ,r Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 From: Wallace, Chris D (DOA) [mailto:chris.wallace©alaska.gov] Sent: Wednesday, August 14, 2013 4:30 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Request to return Alpine injector CD2-30 (PTD 203-135) to water injection 08-14-13 Kelly, Our records indicate a passing MIT witnessed on 6/11/2010 to 3020 psi, and no AA actions—and a status of WAGIN. I approve the restart of water only injection for diagnostic monitoring. Let's review monthly. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7t"Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace @alaska.gov From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Wednesday, August 14, 2013 4:20 PM T.• A allace, Chris D (DOA) Subject. •-quest to return Alpine injector CD2-30 'TD 203-135) to water injection 08-14- Chris, Alpine injector CD2-30(PTD 203- has been shut in since August 2011 d : to TxIA communication. The leak pat' as suspected to be through the compromised tubing .ckoff. Initially it was believed that th- •ackoff could not be repaired without . ig. On 7/26/13 and 08/01/13,tubing packoff tests ed,and the API ring was discovered to •e leaking. On 08/02/13,the tree ad.: or flange connection was tightened,after which a p. 'ng packoff test was achieved. Folio, 'ng the repair,a passing diagnostic IA was completed on 8/6/13. 1 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 08, 2011 10:10 AM To: 'NSK Problem Well Supv'; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: CD2 -30 ( PTD 203 -135 ) Suspect TxIA Thanks Ian. Based on the history, you all have been chasing a small leak for some time on this well. Keep us advised of the diagnostic outcome. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Sunday, August 07, 2011 8:29 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: CD2 -30 ( PTD 203 -135) Suspect TxIA Tom, Jim, Guy, Alpine SW injector CD2 -30 ( PTD 203 -135 ) is suspect to have T X IA communication while on SW injection based on annular trends and recent bleed events. Diagnostics will be performed including T -POTS and an MIT -IA. I will update you with the results. The last MIT -IA passed on 6/11/2010. Based on the results of diagnostics the well may be added to the monthly Failed MIT report. Attached is a 90 day TIO plot and schematic. Ian Ives Problem Wells Supervisor DHD Lead Technician AES Central Shops Phone: (907) 659 -7224 Pager: 909 0 r i q 1.1 ry j c L t 1 8/8/2011 b 3 — i 3s MIT /Limitations/Waiver Details I Event Log I Mechanical Data I Bleed Events T /I /0 Plot 1 Pressure Events ] Well Events I CHOKE FTP FTT r Black Bkg IAP OAP T /I /O Plot - CD2 -30 2000 — , t r . ' s t t . 200 Time Period _ - Past - = C Week - C` Month - !.;' 3 M = 150 l~ s Mo 1500 — " C Year _ r_ — Q. C This Period — I 1 / 1 1 1 9 8 0 Id f 1 1 u i - To p„ 1000 - I... it. i . ; ./ t — 100 0 1 1 r , - I 500 - i t t — 50 0 t I I 1 t t I I I I I l t I I I t t I l I I l l 1 I l 0 07- May -11 20- May -11 02- Jun -11 15 -Jun -11 28- Jun -11 11- Jul -11 24- Jul -11 06- Aug -11 Date • MEMORANDUM TO: Jim Regg j~ P.I. Supervisor ' l~~ ~'(Z~j~`~ FROM: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, June 28, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-30 COLVILLE RIV UNIT CD2-30 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: COLVILLE RIV UNIT CD2-30 API Well Number: 50-103-20465-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ10061508532] Permit Number: 203-135-0 Inspection Date: 6/11/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - -,- -T- ~ - - Well CD2-30' Type Inj. ~, W it TVD _ 7089 P.T.D 2031350 ~ T eTest SPT TCSt SI I 1772 ~ yp ~~ ~ -- -T IA 400 ~ QA 100 ~ ~ -- ~ 3100 125 ~ 3020 3020 ] 20 ] 50 ~ ~ _ _ --- Interval aYRTST per, P i Tubing ~ 23a0 ~ 23ao - z3so ~ z3so Notes: 23 BBLS diesel pumped; no exceptions noted. Monday, June 28, 2010 Page 1 of 1 • V ~~~~ L~i7 ~1= PrtoACmE DiAgNOniC Sertvic~, INC. To: State of Alaska - AOGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing lnspection(Cafiper/ 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 99516 Fax: (907j 245.8952 1) Leak Detection - WLD 23-0ec-09 CD2-30 EDE 50-103-20465-00 2) l~ r~~ Signed Print Name: Date : ,_ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)2458952 E-MAIL : '=~ - _ - - ~ _ - ---__~ . --j; WEBSITE : r _ C:\Documents and Settings\Diarte Williams~Desktop\Transmit_Coneco.docx ~~'~ X03 13.S" • Regg, James B (DOA) From: Regg, James B (DOA) ,~ Sent: Tuesday, December 29, 2009 10:18 AM ~~ ~ (~ ~~ To: 'NSK Problem Well Supv' Cc: Maunder, Thomas E (DO~,; Schwartz, Guy L (DOA) Subject: RE: CD2-30 (PTD 203-135) Report of suspect TxIA communication Page 1 of 3 ?.~3- j3S Based on the results of the testing and TECWEL LDL, it appears CPAI has successfully resolved the packer leak. CPAI may put this well back on WAG injection. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~~ J~~~~ ~ 2~1C From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, December 25, 2009 4:02 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: CD2-30 (PTD 203-135) Report of suspect TxIA communication Tom, Jim, Guy Since the last report below, CPAI has successfully reset the packer restoring IA integrity. The following actions have been taken on this well: 09/07/09: MITIA passed, IA drawdown test failed. 09/24/09: PULLED 3.812" A-1 INJ. VALVE (HRS-309) FROM 2374' RKB. GAUGED TUBING 3.65" TO 10,925' RKB. MEASURED BHP @ 9500' RKB: 4265 PSI. WELL IS READY FOR E-LINE 09/26/09: Eline ran a Tecwel ultrasonic leak detect log and identified a leak at the packer @ 10861'. c= 11/29/09: PULLED 3.812 A-1 INJ VALVE @ 2374' RKB, SET CAT STANDING VALVE @ 10926' RKB, PRESSURE UP TUBING TO 4500 PSI HELD PRESSURE FOR 30 MIN BLEED TUBING TO 1500 PSI MIT IA TO 4500 PSI GOOD TEST, PULLED CAT STANDING VALVE. COMPLETE 12/09/09: IA DD Test -Passed, Initial T/l/0= si 1125/1100/110. Well was shut in upon arrival. Tubing and IA are equalized. Bleed IA down to common line to 225 psi. 1 Hour monitor T/I/0= 1125/250/110, 2 hour T!I/0= 1125!275/110, 3 hour T/I/0= 1125/280/110, 4 hour and final T/I/0= 11251280/110. 12/23/09: HOISTED TECWEL LEAK DETECT LOG. LOOKING FOR LEAK AT PACKER AT 10861'. LOGGED FROM THE PACKER TO SURFACE, BLEEDING THE IA DOWN FROM 80 PSI TO BLEED TANK. 20 PSI AT FINISH. NO LEAK FOUND. Given the results of the testing and the Tecwel LDL, packer leak appears to have been repaired. It is ConocoPhillips intention to return the well to WAG injection as a normal well and the well will be removed from the y monthly report. As per Rule 7 of AIO 18B, if any further indication of communication is observe red, the well will be reported and further diagnostics will be done at that time. Please let me know if this plan is unacceptable or if you have any questions. 12/29/2009 Page ~ -' • • Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: NSK Problem Well Supv Sent: Friday, August 28, 2009 3:54 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: 'guy.schwartz@alaska.gov'; NSK Problem Well Supv; ALP DS Lead and Simops Coord Subject: CD2-30 (PTD 203-135) Report of suspect TxIA communication Jim, Alpine water injector CD2-30 (PTD 203-135) was reported to have suspected TxIA communication due to frequent IA bleeds. The well has been shut in and will be freeze protected. The TIO prior to being shut in was 2399/2100/128. The well was originally reported to the AOGCC on 02/10/09 for similar behavior at which time all diagnostics passed the testing and the well was returned to injection. It is ConocoPhillips intention to perform further diagnostics and repair if possible. Pending the outcome of the diagnostics, a 10-403 or an AA will be submitted at that time. The well will remain SI unless injection is needed for diagnostics. Attached is a 90 day TIO plot and a schematic. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 12/29/2009 __ _ ~ \ ~ WNS , CD2-30 COCIOCOP~1lI~t 5 P 1 / - Well Attributes _ -- - - Max Angle & MD _- .. TD ~.. W Ilt, .:I'INWI TField Name WellSbtus Incl (al MD :r.2) Act etm (RKB) ~~ ~ e^ 046500 ALPINE INJ 92.17 12,258.37 15,700.0 ~- _-- _ "'-- __ ~d u c i 3F C t SSSV, WRDP - H2S (ppm) Date Annotation Last WO: End Date KBGrd (ft) 43.91 Rig Release Date 10/302003 ~ ~ ac , ~ ~ic~,_ Annotation Dep Last Ta th (ttK8) End Date Annotation Last Mod By Rev Reason: RESET INJ VLV Imosbor End Date 5/172009 g. Casin Strings I -- _ Casing Description . String 0... 'String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrtl CONDUCTOR 16 15.062 0.0 109.0 109.0 62.50 H-40 WELDED Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Sat Depth (ND) ... String Wt... String ... Siring Top Thrd SURFACE 9 5/8 8.921 36.7 3,006.3 2,379.8 36.00 J-55 BTC Casing Description String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 34.6 11,481.1 7,304.4 26.00 L-80 BTCM Casing Description String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrtl Open Hole . 61/8 6.125 11.481.0 15700.0 7,298.8 ~ ~; ~ __..,, - Strin s Tubing ` _ _ _ _ - _ ~: _ Tub ng Desc pion Sf ng O.. jStri g 10 Top (RKB) Set Depth (t.. Set D pth (TV D) Str ng Wt.. 51 g ~ ' String Top Thrd ' TUHING .. __ 4 1/2 3 95Yi L 80 ~ 10 938 2 7 12L 4 12.60 32 8 _- __ _ ._- - 16TM _ ,. i 33 Y HANGER = )~ Coin letlon Details ____ __- __ ~ , ' -- Top Depth _ ' (ND) Top Incl Top (RKB) (RKB) (°) Rem Description Comment ID (1n) - _ -` 32.8 32.8 -0.01 HANGER FMC TUBING HANGER 4.500 2,374.1 2,016.4 54.33 NIPPLE CAMCO DB NIPPLE 3.812 10,861.2 7,089.0 63.79 PACKER BAKER S-3 PACKER w/MILLOUT EXTENSION 3.875 10,925.9 7,117.2 64.77 NIPPLE CAMCO'XN' NIPPLE 3.725 coNDUCTOR, o-1 as 10,936.9 7,121.9 64.76 WLEG WIRELINE ENTRY GUIDE 3.875 VALVE, 2,374 NIPPLE, 2,374 SURFACE. 37-3,006 PACKER, 10.861 NIPPLE, 10.926 WLEG. 10,937 TD. 11,491 PRODUCTION. 35-11,481 • :J • ,~ w Open Hole. 71,461-15,700 t ~, r? 1 ~/~~ I _. y Oth_e_ r In Hole Wireline retrievable plugs, valves, pumps, fish, etc. _ - -Top uepth (ND) lop Incl Top (RKB (RKB) (°) Description Comment Run Data ID (in) 2,374 2,016.3 54.33 VALVE 3.812" A-1 INJECTION VALVE (HRS-309) W/1.25" 5/13/2009 1.250 ORIFICE ~ Notes: General 8 Safety_ _ r- - _- - - End Date Annotation 10/29/2003 NOTE: TREE: FMC 4 1/16 SK TREE CAP CONNECTION: 7" OTIS ails ~p Depth Top Port (ND) Incl OD Valve Latch Size TRO Run (RKB( i (°) l Make Model (in) , Sarv Type Type lin) (psi) • • '~ ,;.~\ ~J ___._____--.---_.~ ~f, PaoA~rive Diaynostic SEevicES, Inc. YV~LL ~~~ ?`I~A/V~M/T7'AL To: State of Alaska - AOGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 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 tetter to the following : BP Exploration (Alaska), Inc. petratechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and z~~~~~~~ Cv`~1;' ~ ~ 2~Q~ ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Raad Suite C (..~ ~~ ~ b3 -' l ~ ~~- Anchorage, AK 99518 Fax: (907) 245-8952 /~~~~ 1~ Leak Detection - WLD 26-Sep-09 CD2-30 EDE 50-103-2046~00 2~ ~ i Signed : ~ Print Name: PROACTIVE DtAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AlRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-NIAIL _ __.._~ ta:'".=_ ~".'_ ~.~._ WEBSItE: ~_. _.m_ _ __._______ C~`~Docutnent uld Szttings\Owner'~Desktop~Transmit_BP.~iocx CD2-30 (PTD 203-135) Report o~spect TxIA communication ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Weli Supv [n1617@conocophillips.com] Sent: Friday, August 28, 2009 3:54 PM ~p~~ °~~i ~(~q To: Regg, James B(DOA); Maunder, Thomas E(DOA) ~ Cc: Schwartz, Guy L(DOA); NSK Problem Weii Supv; ALP DS Lead and Simops Coord Subject: CD2-30 (PTD 203-135) Report of suspect TxIA communication Attachments: CD2-30 schematic.pdf; CD2-30 90 day TIO plot.jpg Jim, ~ Aipine water injector CD2-30 (PTD 203-135) was reported to have suspected TxIA communication due to frequent IA bleeds. The well has been shut in and will be f_rPP~P rRotected. The TIO prior to being shut in was 2399/2 ~. The well was originally reported to the AOGCC on 02/10/09 for similar behavior at which time all diagnostics passed the testing and the well was returned to injection. It is ConocoPhillips intention to perform further diaqnostics and repair if possible. Pending the outcome of the ./ diagnostics, a 10-403 or an AA wili be submitted at that time. The well will remain SI unless injection is needed for diagnostics. Attached is a 90 day TIO plot and a schematic. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ' ~' , ~o t,~l ~~ N.. ~ ~ . ~ ~ , ~ ~ ~}~~y: «CD2-30 schematic.pdf» «CD2-30 90 day TIO plot.jpg» 9/16/2009 CRU CD2-30 PTD 203-135 8-28-2009 TIO Pressures WELLS WLHD f'ifDAFliT VaTfIF f RARFHT VdLRE CIIRRENT VAT.IIH Ci1RRENT VALIIE OPERATOR NOTES SFT CHfIICF CHORE 45. INJ RATE 0. WH PRESS 2209. ORIF DP ~.4F9 INJ 1'EMP Bfi. IN.7 VOL '~tn~t. 7(;v;n(,v nrr~„ r~L ~~~lr:;;: ~~ ~~~ ~~~ ~ -- -_ _ ., ~i~ ~ ~ ~i _- -- - ._...__ _ -- __ - _ -- ---- . ? 1 2 4 B _ . . p "+ _ . _ - ,--~ -- - • --- - . - -- + - - .. - - ----- - -- ~a - ~ z H _ - ~ -- , ~ - ~ - _. -- ~- - --- - - ~ ~ I R - _ _ __ - --- I` --- - --- _ - - - - - _ ._- - ~ T , , , _ _ __ . ii u • WNS CD2-30 _,~ ; ~ _ ~,,,~_ -- `(1:~'~ _ E~a~°' . _ .. ~~ ~ , -.. ~ = a~• ~ ~. ~ ;+x,. : ~ ~+~:h~ 5 ~,_ . _ . dl~[# . -_ .~i ~~ ..: = (U _ ~~'!~ Wallbora API/UWI Fieltl Neme Well Status Ind (°) MD (ttKB) Act Btm (fHCB) ~~~~. ~~~. 501032046500 ALPINE INJ 92.17 12,258.37 15,700.0 ---- ~~- - ---- Comment N2S (ppm) Date Annotation Entl Date KB-0rd (ft) Rig Release Dal ~ • ee-~~ :•cerz~r. ri~.~~~ . SSSV: WRDP Last W0: 43.91 10/30/2003 ~~~. ~~~. Annotation Depth (kKB) End Date Annotation Last Mod By End Date ~ Last Tag: Rev Reason: RESET INJ VW Imosbor 5/17/2009 Ga~irf Sfr~1=~ ; ~ ~ , ~ ..z, ~,r ~~ z. ~ , ~ .> ! -~ . ~ ~ e ~ e F. : Casing Dascriptlon String 0... String ID ... Top (kKB) Set Depth (f... SM Depth (ND) ..~. String Wt... String ... String Top Thrd~ CONDUCTOR 16 15.062 0.0 109.0 109.0 62.50 H-40 WELDED ~~ ~~'~~ ~ ~~~~~ ~~~~~~ CasingDeacriptlon String0... StringlD...7op(RKB) SetDepth~f... SotDapth~TVD~... StringWt... String... String7opThrd SURFACE 9 5/8 8.921 36.7 3,006.3 2,379.8 36.00 J-55 BTC Caeing DeacripHon String 0... String ID ... Top (ftKB) Set Dapth (f... SM Depth (ND) ... String Wt... String ... String 7op 7hrd PRODUCTION 7 6.151 34.6 11,481•1 7,304.4 26.00 L-80 BTCM Casing DescripUOn String 0... String 10 ... Top (/d(B) Set Depth (f... SM Depth (ND) ... String Wt... String ... String Top Thrd = Open Hole 6 1/8 6.125 11,481.0 15,700.0 7,298.8 U~EY ~:~F'1 S;il I _ ak~„ i~ ,~ ~ _~ ~^~~~ ,; ~'~`i.~ ~-st*~A.' ~ iH~e '. .-...~- _ .~. ~ . ~ „_ ~ ., ~ < . ~e ... ~~ i, Tubing Description Stnng O.. String ID ... Top (ftKB) Set ~epth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd ~ -~~ TUBWG 41/2 3.958 32.8 10,938.2 7,122.4 12.60 L-80 BTM ~ - HANOER.33 = ~~ a ~ i. ~~uti _ E`'eEk is V~~~ T-~ M~y a = _ Top Depth (ND) 7op Inal ,-~... .....,.. . Too fRK81 (ftKB) (°) kem Deacrlotfon Comment ID (li I~~u~ 7opincl To (ftK8 (ttHB) (°) Deseri i CommeM Run Date ID in) 2,374 2,016.3 54.33 VALVE 3.812" A-1 INJECTION VALVE (HRS-309) W/1.25" 5/132009 1250 VALVE, 2,374 ORIFICE NIPPLE, 2,374 ~ i y~ S7~~ 1 ,~ " Iitl E~~- ; x'~ ^ ~t; "~ ='- ~ . c" ~ -~ ~ ~~ ~i'~~ . „ ~'~ ` s ~. : End D ete 1 . . ~ ., ,e ,. : ~.. a ~ AnnMefion ~ . - 10/29/2003 NOTE: TREE: FMC 4 1l16 5K ~ TREE CAP CONNECTION: 7" OTIS _ 5/17/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 ri SURFACE. 37-3,006 -,.:~'.'~i "i3 GAS LIFT, 10.747 PACKER, iii 10.861 NIPPLE, 10,926 ~ .,,'..,,'I ~T~ ~" ~ ~ a i a ~~~ " jI9 }~ ~ h~ ' WLE0.10.937 ~ ~ ~alts~ M~ri , ~ l r ~ -° ~ ~G, ~ ~ f i ~r a ~ - Top Oepth Top Port ~~ (ND) Incl OD Valve Lateh Size TRORun Stn Too IftKB) (RKB) (°) Make Modal (~~) Serv Type Type (~~~ (psi) Run Date Com... TD, 17,4Bt PRODUCTION, 35-11.481 Open Hole, 11.481.15.7W FW: CD2-30 (PTD# 203-135) ~ort Of Suspected TxIA Communicati• Page 1 of 3 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, May 08, 2009 8:56 AM ~ ~q 7 ~ ~~~~ To: Regg, James B (DOA) ~ t~ Cc: Maunder, Thomas E (DOA) Subject: RE: CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication Brent - as discussed this morning via phone, the Commission concurs with CPAI plans to restart water injection ih CD2-30. Please keep the well on the monthly report or at east mon pas res a ing in~ec io . .~---~ Jim Regg AOGCC 333 W.7th Avenue, Suite 100 ,~,r ,~•: a~ ~~~+ ~ ~~ ~~~~ Anchorage, AK 99501 ~>'~~„,,,~3~ ~ ° ~'~ ~ .k. 907-793-1236 From: Regg, James B (DOA) Sent: Tuesday, April 21, 2009 2:18 PM To: 'NSK Problem Well Supv' Cc: Maunder, Thomas E (DOA) Subject: RE: CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication Also, not clear but I assume you are going to bleed pressures before bringing well on line. I suggest keeping the well on the monthly rpt for at least 1 month past restarting injection to make sure there is not indication of pressure communication. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (DOA) Sent: Tuesday, April 21, 2009 1:50 PM To: 'NSK Problem Well Supv' Subject: RE: CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication bring back on injection with ...? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 5/8/2009 FW: CD2-30 (PTD# 203-135) ~ort Of Suspected TxIA Communicate, Page 2 of 3 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, April 21, 2009 1:16 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: ALP DS Lead and Simops Coord; Schneider, Tim S.; Shirtliffe, Ryan; Barreda, Brian B; Tsunemori, Phil G; NSK Problem Well Supv Subject: FW: CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication Jim, Diagnostics have been completed on CD2-30. A plug was set in the XN nipple @ 10,926 and a passing MITT and MITIA (see attached MIT form) was performed on 04/18109. On 04120/09, DHD performed a passing IA DD test. The results from the DD test were as follows: IA DDT -passed, IA FL AS. (AC EVAL) Initial T/l/0= 1175/1330/120. IA FL AS, Bled IA to nearby producer. (20 min) Start 2 hr IA DDT. T/I/0= 1175/210/110, 30 min: 1175/240/110, 60 min: 1175/240/110, 90: 1175/240!110, 120 min and final T/I/0= 11751240/110. With the diagnostic indicating both tubing and production casing integrity, it is ConocoPhillips intention to bring the well back on injection and remove it from the monthly MIT report. If any further annular communication is suspected, it will be reported to the AOGCC and further diagnostics will be done at that time. Attached is the MIT form for both the MITT and MITIA. «MIT CRU CD2-30 04-18-09.x1s» Please let me know if you have any questions or if this plan is unacceptable. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: NSK Problem Well Supv Sent: Tuesday, February 10, 2009 7:46 PM To: 'tom maunder@alaska.gov'; 'jim.regg@alaska.gov' Cc: NSK Problem Wel! Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Schneider, Tim S.; Barreda, Brian B Subject: CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication Tom/Jim, Alpine WAG injector CD2-30 (PTD# 203-135) is suspected of having TxIA communication based upon recent frequent bleeds and pressure performance. Slickline will begin troubleshooting and repair the leak if possible. CPAI intends to inject in the well only if necessary to conduct diagnostics and will submit a 10-403 as appropriate to repair or seek administrative approval to continue water only injection. The well will be shut in and added to the Monthly MIT Report. Attached is a 90 day TIO plot and wellbore schematic. «CD2-30 TIO Plot.pdf» «CD2-30 Wellbore Schematic.pdf» 5/8/2009 FW: CD2-30 (PTD# 203-135) ~ort Of Suspected TxIA Communicati~ Page 3 of 3 Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 5/8/2009 FW: CD2-30 (PTD# 203-135) ~ort Of Suspected TxIA Communicati~ Page 1 of 3 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ~~1C ~ I zt;'Z-~%u J Sent: Tuesday, April 21, 2009 2:30 PM f To: Regg, James B (DOA) Subject: RE: CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication Jim, The well will remain on the monthly report for at least the next month and a request to remove it can be made later if no indication of communication. The final T/I/O fol-owing the IA DD test was 1175/240/110. The well will be monitored for thermal pressurization while bringing the well on line. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~eu~,>~~~~. APf~ ~' ~~ 2D~ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, April 21, 2009 2:18 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: RE: CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication Also, not clear but I assume you are going to bleed pressures before bringing well on line. I suggest keeping the well on the monthly rpt for at least 1 month past restarting injection to make sure there is not indication of pressure communication. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (DOA) Sent: Tuesday, April 21, 2009 1:50 PM To: 'NSK Problem Well Supv' Subject: RE: CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication bring back on injection with ...? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 4/21 /2009 FW: CD2-30 (PTD# 203-135) ~ort Of Suspected TxIA Communication Page 2 of 3 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, April 21, 2009 1:16 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: ALP DS Lead and Simops Coord; Schneider, Tim S.; Shirtliffe, Ryan; Barreda, Brian B; Tsunemori, Phil G; NSK Problem Well Supv ,~- Subject: FW: CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication Jim, Diagnostics have been completed on CD2-30. A plug was set in the XN nipple @ 10,926 and a passi~Cn MITT and MITIA (see attached MIT form) was performed on 04/18/09. On 04/20/09, DHD performed a passing IA DD test. The results from the DD test were as follows: IA DDT -passed, IA FL AS. (AC EVAL) Initial T/I/0= 1175/1330/120. IA FL AS, Bled IA to nearby producer. (20 ~ min) Start 2 hr IA DDT. T/I/0= 1175/210/110, 30 min: 1175/240/110, 60 min: 1175/240/110, 90: 1175/240/110, 120 min and final T/I/0= 1175/240/110. With the diagnostic indicating both tubing and production casing integrity, it is ConocoPhillips intention to bring the well back on injection and remove it from the monthly MIT report. If any further annular communication is suspected, it will be reported to the AOGCC and further diagnostics will be done at that time. Attached is the MIT form for both the MITT and MITIA. «MIT CRU CD2-30 04-18-09.x1s» Please let me know if you have any questions or if this plan is unacceptable. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: NSK Problem Well Supv Sent: Tuesday, February 10, 2009 7:46 PM To: 'tom.maunder@alaska.gov'; 'jim.regg@alaska.gov' Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Schneider, Tim S.; Barreda, Brian B Subject: CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication Tom/Jim, Alpine WAG injector CD2-30 (PTD# 203-135) is suspected of having TxIA communication based upon recent frequent bleeds and pressure performance. Slickline will begin troubleshooting and repair the leak if possible. CPAI intends to inject in the well only if necessary to conduct diagnostics and will submit a 10-403 as appropriate to repair or seek administrative approval to continue water only injection. The well will be shut in and added to the Monthly MIT Report. 4/21 /2009 FW: CD2-30 (PTD# 203-135) ~ort Of Suspected TxIA Communication Page 3 of 3 Attached is a 90 day TIO plot and wellbore schematic. «CD2-30 TIO Plot.pdf» «CD2-30 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 4/21 /2009 ('i ~ z~3-i3~ Well Name CD2-30 Notes: (~Z - Inj ATP 2 IA ~nriU,ita ~~~ I~~si End Date 2!1512009 Days 90 Start Date 11 /17; 2008 WHP IAP Annular Communicaton Surveillance _ OAP - -- - -- _ _ _ 90 2500 WHT --~~_~---_- ----- - - 80 2000 - 70 60 1500 ----- 5QL •N sZ C1 ~ a ao iooo 30 - 20 500 --- - - - .-. 10 0 p Nov-08 Dec-08 Jan-09 Feb-09 ~DGI ~ 4000 _ ~MGI i ..---.,._.-..__-- --~..~_ _--- 3500 ~pyyi SWI 3000 a ~BLPD 2500 m 0 2000 - U 1500 -- 1000 - 500 n J ~J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.govG OPERATOR: ConocoPhillipsAlaskalnc. '~~ ~I~I~~"I FIELD /UNIT /PAD: ~ ~ DATE: OPERATOR REP: AOGCC REP: Alpine / CRU /CD2-30 04/18/09 HES Packer Depth Pretest Initial 15 Min. 30 Min. Well CD2-30 Type In'. N TVD 7,089' Tubin 1,225 3,050 3,000 3,000 Interval O P.T.D. 2031350 Type test P Test psi 1772 Casing 1,650 1,810 1,810 1,800 P/F P Notes: Diagnostic MITE OA 150 150 150 150 Plug is set @ 10926' in HES XN nipple Well CD2-30 Type Inj. N TVD 7,089' Tubing 1,500 1,725 :1,725 1,725 Interval V P.T.D. 2031350 Type test P Test psi 1772.25 Casing 1,700 " 3,050 ' 3,025 3,025 P/F P '~ Notes: Diagnostic MITIA OA 150 200 200 200 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater 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 0 =Other (describe in notes) MIT Report Form BFL 11/27/07 2009-0418_MIT_CRU_CD2-30_MITIA.xIs Cana~QPhili~ps Al~~k~, lac. TUBING (0-10938, Op:4.500, ID:3.958) SURFACE (0-3006, OD:9.625, Wt:36.00) 'RODUCTION (0-11481, OD:7.000, wt:zs.oo) Gas Lift 3ndrel/Dummy Valve 1 ;10747-10748, OD:5.984) PACKER ;10861-10862, OD:5.970) NIP ;10926-10927, OD:5.000) WLEG ;10937-10938, OD:5.000) I'...' , OPEN HOLE I ' ;11481-15700, -~- -._ ALPINE CD2-30 CD2-30 API: 501032046500 Well T e: INJ An le TS: de SSSV Type: WRDP Orig Completion: 10/30/2003 Angle @ TD: 89 deg @ 15700 Annular Fluid: Last W/O: Rev Reason: Reset CSG to s Reference Lo 36' RKB Ref Lo Date: Last U ate: 11/4/2004 Last Ta TD: 15700 ftK6 Last Ta Date: Max Hole An le: 92 de 12258 Casin Strin -ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 109 109 62.50 H-40 WELDED PRODUCTION 7.000 0 11481 7304 26.00 L-80 BTCM SURFACE 9.625 0 3006 2380 36.00 J-55 BTC OPEN HOLE 6.125 11481 15700 15700 0.00 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 4.500 0 10938 7122 12.60 L-80 IBTM Gas. Lift Mandrals/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TR O Date Run Viv Cmnt 1 10747 7035 CAMCO KBG-2 DMY 1.0 BK 0.000 0 2/1/2004 Other lu s e ui ete -JEWELRY De th TVD T e Descri lion ID 33 33 HANGER FMC 4.5"TUBING HANGER 3.958 2374 2017 NIP CAMCO'DB' LANDING NIPPLE 3.812 2374 2017 VALVE 3.812" A-1 INJECTION VALVE HWS-S W/1.25" ORIFICE set 2/1/2004 1.250 10861 7089 PACKER BAKER S-3 PACKER W/MILLOUT EXTENSION 3.875 10926 7117 NIP HES'XN' NIPPLE W/NO GO PROFILE 3.725 10937 7122 WLEG BAKER WIRELINE GUIDE 3.875 General Notes Date Note 0/29/200 TREE: FMC 4 1/16 5K TREE CAP CONNECTION: 7" OTIS CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication Regg, James B (DOA) W From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, February 10, 2009 7:46 PM ~~ ~' ~i~~ ZC10~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Schneider, Tim S.; Barreda, Brian B Subject: CD2-30 (PTD# 203-135) Report Of Suspected TxIA Communication Attachments: CD2-30 TIO Plot.pdf; CD2-30 Wellbore Schematic.pdf Tom/Jim, Page 1 of 1 Alpine WAG injector CD2-30 (PTD# 203-135) is suspected of having TxIA communication based upon recent frequent bleeds and ressur erform nce. Slickline will begin troubleshooting and repair the leak if possible. CPAI m ends to inject in the well only if necessary to conduct diaano~tics and will submit a 10-403 as appropriate to repair or seek administrative approval to continue water only injection. The well will be shut in and added to the Monthly MIT Report. Attached is a 90 day TIO plot and Wellbore schematic. «CD2-30 TIO Plot.pdf» «CD2-30 Wellbore Schematic.pdf»:/~ Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~~.~~ 2/12/2009 • I I ~ ~ o ~ ~6aP~ M N ° C ea [ y Q. .~ o > ~ o ~ ~ = N c O 3 v Q ~ ,~} C ~ a . O ~ U N O ~ y d ~ = Z Q S gyf E G1 O C' N O O 0 N _ O ~ ~ O ~ U r N ~ ~ a = a < _ 3ao 3 1 d *; ~ _ o Z D ~ N N ~ ~WC fA 0 0 0 °o ~°n °o N isd I °' ° a °' LL ~-~ ~ it ~ ~~ 'I I i a, L° °o 0 U 0 ~, ° m LL rn ' 0 0 0 0 U N 0 D c~~33~ c~amm o I I I_I I_ o > ~ > 0 0 ° Z °o °o °o °o °o °o °o °o ° Z O Ln O ~ O ~ O l17 ~ C7 M N N adl8`Od~W * $ ~ ~` 3 ~I ~J, ' ~'~ ~ - Cp~t~coF'~~Il~p~ Alaska, TUBING (0-10938, OD:4.500, ID:3.958) SURFACE (0-3006, OD:9.625, W L 36.00 ) PRODUCTION (0-11481, OD:7.000, wt:zs.oo) Gas Lift 3ndrel/Dummy Valve 1 ;10747-10748, OD:5.984) PACKER ;10861-10862, OD:5.970) NIP ;10926-10927, OD:5.000) WLEG ;10937-10938, OD:5.000) OPEN HOLE ;11481-15700, OD:6.125) -~ i~ _: inc. ALPINE CD2-30 CD2-30 AP1: 501032046500 Well T e: INJ An le TS: de SSSV Type: WRDP Orig Completion: 10/30/2003 Angle @ TD: 89 deg @ 15700 Annular Fluid: Last W/O: Rev Reason: Reset CSG to s Reference Lo 36' RKB Ref Lo Date: Last U date: 11/4/2004 Last Ta TD: 15700 ftKB Last Ta Date: Max Hole An Ie: 92 de 12258 Casin Strin -ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 109 109 62.50 H-40 WELDED PRODUCTION 7.000 0 11481 7304 26.00 L-80 BTCM SURFACE 9.625 0 3006 2380 36.00 J-55 BTC OPEN HOLE 6.125 11481 15700 15700 0.00 Tubin Strin -TUBING Size To Bottom ND Wt G rade Thread 4.500 0 10938 7122 12.60 L-80 IBTM Gas Lift MandrelsNalves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TR O Date Run Vlv Cmnt 1 10747 7035 CAMCO KBG-2 DMY 1.0 BK 0.000 0 2/1/2004 Other lu s e ui ., etc. -JEWELRY De th TVD T Descri lion ID 33 33 HANGER FMC 4.5"TUBING HANGER 3.958 2374 2017 NIP CAMCO'DB'LANDINGNIPPLE 3.812 2374 2017 VALVE 3.812" A-1 INJECTION VALVE HWS-S W/1.25" ORIFICE set 2!1/2004 1.250 10861 7089 PACKER BAKER S-3 PACKER W/MILLOUT EXTENSION 3.875 10926 7117 NIP HES'XN' NIPPLE W/NO GO PROFILE 3.725 10937 7122 WLEG BAKER WIRELINE GUIDE 3.875 General Notes Date Note 0/29/200 TREE: FMC 4 1/16 5K TREE CAP CONNECTION: 7" OTIS I i I i I i • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, July 08, 2008 10:38 AM To: 'Reilly, Patrick J' Cc: Galiunas, Elizabeth C; Noel, Brian Subject: RE: CD - .OE4) -AGAIN Thanks much Pat. I knew what was submitted couldn't be for the surface. • .Page 1 0 A From: Reilly, Patrick J [mailto:Patrick.].Reilly@conocophillips.com] Sent: Tuesday, July 08, 2008 10:36 AM To: Maunder, Thomas E (DOA) Cc: Galiunas, Elizabeth C; Noel, Brian Subject: RE: CD2-73~LU8=0C~ -AGAIN Tom, I am sorry about the mix up. The LOT sent in with the AD package was for the intermediate. The attached PDF has both the surface and intermediate LOT's. ,~ g -~-~" \ ~SP~:~ ~' ~. ~~ `~.,®a ~- ~'~~ i ~~k~: 6 ~:.~ is ~°~. Pat Reilly ConocoPhillips Alaska Drilling & Wells ~ 'i;~ (907) 265-6048 WORK ~-~ ~" ~~~ ' (907) 244-5558 CELLULAR. (907) 265-1535 FAX Patrick.]. Reilly@conocophiliips.com From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] ~~~~, ~UL ~ ~ 2008 Sent: Tuesday, July 08, 2008 9:21 AM To: Reilly, Patrick J Cc: Noel, Brian; Galiunas, Elizabeth C; Eggemeyer, Jerome C. Subject: RE: ~~z'~913=~) -AGAIN Pat, I am continuing to look at this annular disposal application. Would you and your colleagues please have a look at the initial LOT for CD2-30 (10/23103)? It appears that the depths of the 7" casing are used for determining the EMW rather than the depths of the 9-5/8". I wondered when the calculated EMW given was only 12.5. If the tvd of the 9-5l8° is used, the FIT value calculates to 20.0 EMW!! From the record, no application was ever made for CD2-30 and since the cementing/LOT information is only now being submitted, it is possible that this weft was never within the'/< mile radius of any other well considered for AD. I look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC 'rrom: i~iaunder, T homas E (DuH) Sent: Tuesday, July 08, 2008 8:43 AM To: 'Reilly, Patrick J' Cc: Noel, Brian; Galiunas, Elizabeth C Subject: RE: CD2-75 (208-064) 7/8/2008 • • CD2-30 Details ~~ ~~ ~ • '~ PHILLIPS PAlaska~IncY Casing Detail 9 5/8"Surface Casing Well: CD2-30 Date: 8/19/2003 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.70 FMC Gen V Hanger 2.20 36.70 Jts 3 to 71 69 Jts 9-5/8" 36# J-55 BTC Csg 2878.95 38.90 Davis Lynch Float Collar 1.45 2917.85 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 84.73 2919.30 Ray Oil Tools "Silver Bullet" Float Shoe 2.30 3004.03 3006.33 TD 12 1/4" Surface Hole 3016.00 RUN TOTAL 41 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #3) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64, 66, 68, 70 76 joints in the pipe shed. Run 71 joints-5 joints to stay in the shed Use Best-o-Life 2000 i e do e Remarks: Up Wt - 160k Dn Wt-130k Block Wt - 70k Supervisor: Whitlock /Burley • Security Level: Development Daily Drilling Report CD2-30 Report Number: 4 Rig: DOYON 19 Report Date: 8/28/2003 AFE Type Network/ID # Total AFE+Sup 10030031 3,530,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2-30 Well Services ALPINE 3.00 4.0 0.00 3,016.0 3,016.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 327,532.00 750,368.00 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 8/25/2003 8/26/2003 Last Casing String Next Cas ing OD (in) Next Casing Set Depth (ftKB) Ops and Depth ~ Morning Report 24hr Forecast Drilling out shoe track. Perform FIT, dril l 8 1/2" intermediate hole. Last 24hr Summary Run and cement 9 5/8"" casing, F S @ 3006', FC @ 2918'. ND riser, NU wellhead and BOPE -Test BOPE. PU 60 jts of DP, slip and cut drlg line. Stand back DP - MU BHA 2. General Remarks Weather Head Count 34/26/E@ 9mph 47.0 Supervisor - _-- - ----- -----... - - - _ Title.... _. G. Whitlock / D. Burley, Supervisor Supervisor Vern Johnson / Zane Kuenzler, E ngineer Engineer .Time Log -- Start End I Dur - _ - ~ Time I Depth Start ~ - __ --- Depth End - -~---- i Time Time hrs (_ Phase ~; ( ) - ' p ~ O Code O Sub Code P N-T ~ Trbl Code Trbl Class (ftKB) p (ftKB) O eratlon - --- l)t)a)~ ~~ 00:45 0.75' SURFAC CASE RUNC _ _ _ P 1,574.0 - - - _ 2,285.0 Continue running surface casing to 2285' 00:45 01:00 0.25 SURFAC CASE CIRC Np DH 2,285.0 2,326.0 Circulate joint 56 down from 2285' to 2326' to break gels in mud. 01:00 02:15 1.25 SURFAC CASE RUNC P 2,326.0 3,006.0 Continue running 9-5/8"" surface casing. M/U landing jt and land casing @ 3006'. Total of 71 jts of 9-5/8"" 36#, J-55 BTC casing run. 02:15 02:30 0.25 SURFAC CASE RURD P 3,006.0 3,006.0 UD fillup tool 02:30 03:00 0.50 SURFAC CASE RURD P 3,006.0 3,006.0 R/U cement head 03:00 04:30 1.50 SURFAC CEMENT CIRC P 3,006.0 3,006.0 Establish circulation @ 334 gpm @ 530 psi. Circulate and condition mud. Final rate=369 gpm @ 470 psi 04:30 06:00 1.50 SURFAC CEMENT PUMP P 3,006.0 3,006.0 Mix and pump 40 bbl viscosified water w/ 6 sx nut plug w/ rig pump while reciprocating pipe @ 1 spm for 20' stroke. Cementers pump 5 bbl water and pressure tested lines to 2500 psi. Drop bottom plug. Mix and pump 50 bbl Mudpush XL @ 10.5 ppg, 5.6 bpm, 195 psi. Mix and pump 343 bbl Lead @ 10.7 ppg @ 7.5 bpm 175 psi. Had nut plug at shakers and switched to Tail. Mixed and pump 47.5 bbl Tail @ 15.8 ppg 4.7 bpm, 210 psi. Dropped top plug and Pumped 20 bbl water w/ cementer. Quit reciprocating after 32 bbl tail were mixed and pumped. 06:00 06:45 0.75 SURFAC CEMENT DISP P 3,006.0 3,006.0 Displace cement w/ 9.8 ppg mud w/ rig pump @ 6.7 bpm 650 psi. Bumped plug w/ 2469 strokes and 1150 psi. Floats held. Pumped 125 bbl cement to surface. 06:45 07:45 1.00 SURFAC CASE DEOT P 3,006.0 3,006.0 R/U and test casing to 2500 psi for 30 minutes 07:45 08:30 0.75 SURFAC CEMENT RURD P 3,006.0 0.0 R/D cement head and UD landing jt. 08:30 09:30 1.00 SURFAC CASE NUND P 0.0 0.0 N/D riser, surface equipment and slip lock assembly Latest BOP Test Data __ Date ~ ~ -- _ - - --' ~~-Comment-- _. .. Page 1/2 Report Printed: 6/16/2008 • • Security Level: Development . Daily Drilling Report y CD2-30 Report Number: 4 Rig: DOYON 19 Report Date: 8/28/2003 Time Lo ~, . StaA ? £nd Dur ~' Time ' - '.-._... _ . _._ ___._. -. _.- Depth Start Depth End ~ - --. _.. __-__ -. _. ... _-- --~ ~~ ', Time '. Time (hrs) Phase Op Code OpSub-Code ~ P-N T Trbl Code Trbl Class. (ftKB) (ftKB) G Operation ~ 09:30 11:30 2.00 SURFAC CASE NUND P 0.0 0.0 N/U unihead and test to 1000 psi for 10 min. N/U BOPE and change Topdrive saver sub. 11:30 12:00 0.50 SURFAC WELCTL BOPE P 0.0 0.0 R/U to test BOPE- Install mousehole 12:00 16:30 4.50 SURFAC WELCTL BOPE P 0.0 0.0 Test BOPE: Pipe & Blind rams, choke line, kill line, manifold and surface safety vales to 250 / 5000 psi -Annular preventer 250/3500 psi. AOGCC (Chuck Sheve) waived witnessing tests. 16:30 17:00 0.50 SURFAC CASE NUND P 0.0 0.0 Blow down lines, pull test plug and install wear bushing. 17:00 17:30 0.50 SURFAC DRILL RIRD P 0.0 0.0 Install drilling bails and drill pipe elavators. 17:30 19:00 1.50 SURFAC DRILL PULD P 0.0 1,880.0 RIH - PU 60 jts of 4"" drill pipe from shed. 19:00 20:30 1.50 SURFAC RIGMNT RSRV P 1,880.0 1,880.0 Slip and cut drilling line -service Top Drive. 20:30 21:30 1.00 SURFAC DRILL TRIP P 1,880.0 0.0 POH -set back 20 stands of drill pipe. 21:30 00:00 2.50 SURFAC DRILL PULD P 0.0 82.0 MU BHA #2 - 8 1/2"" Geo Pilot assembly - upload MWD. Mud Check Data YP Ga~c i. GeI (10s) ~ Gel (~Om) Gel (30m) HTHP Fllt j Density Temp Solids Cort. yPe ~ ~ Dens ~ h Vis (s65 (1 PV Calc 4pJ {Ibf , (Ibf!'IOOfN( ~. (Ibf/100ft ) _ (Ibf b~l5 (mL/30min) PH M8T (Ibl ~ l`F)---- - (off' Spud 389 ~ 2 9.70 1 ~ 1 000 O O 2 9.2 4.8 50.021 Spud 2,389.0 9.80 60 18.0 20.000 6.0 16.0 26.011 22.5 8.8 Spud 2,389.0 9.90 120 26.0 36.000 16.0 34.0 43.018 22.5 8.7 i Wellbores - _- _ _ - ----- - -_ _ _ _ _ Wellbore Name _ _ _ _ __ _ -- -- -- Wellbore API/UWI CD2-30 501032046500 l ~~ Sectan ~ T Size (In) 18 Act Top (ftKB) Act Btm (ftKB) Start Dafe ' End Date 0.0' 109.0 8/26/2003 10!2012003 11 5/8 109.0 3,006.0 9 3,006.0 11,481.0 10/30/2003 _ ___ I Cement Surface Cas in -Started 8/28/2003 Type Wellbore Cemented String Cement Evaluation Results casing CD2-30 Surface, 3,006.OftKB Bond log run (Y/N): N Remedial cement required (Y/N): N Pressure used to test shoe (psi): 16.1 Test pressure (psi): 2500 Test time (hrs): 30 Top of cement sufficient (Y/N): Y Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Cement Casing 0.0 3,006.0 4 650.0 Fluitl Cl ass Amount (sacks) V (bbl) Density Qblgap i Yield (fi'/sack) :. - Cst Top (ftKB) Est Btm (ftK6/ FLUSH 0 50.0 10.50 0.00 LEAD 450 343.0 10.70 4.28 0.0 2,506.0 TAIL G 235 47.5 15.80 1.16 2,506.0 3,006.0 Page 2/2 Report Printed: 6116/2008 Cement Detail Report CD2-30 Production Casing Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing 9/3/2003 16:31 9/3/2000 19:09 CD2-30 Comment '.Cement Stages _ - -- -- - -- -- ----- 'Sta e # 1 ~-_ - - -T - _ _ _ - Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? Cement Casing 10,593.0 11,486.0 0.0 No 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) 5 5 4 830.0 1, 500.0 0.00 Depth tagged (ftKB) Tag Method Depth P lug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Annular flow after cement job (Y/N): N Pressure before cementing (psi): 520 Hours circulated between stages: 1.5 Returns (pct): Minimal 4% Time cementing mixing started: 16:31 __ _ 'Cement Fluids i3< Additives -- - -.. - --- _- '.Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) ' Class Volume Pumped (bbl) FLUSH CW100 0 20.0 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.00 0.00 0.00 8.30 0.00 0.0 Additives Additive Type Concentration Conc Unit label 'Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) FLUSH MUDPUSH XL 0 50.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 0.00 0.00 0.00 12.50 0.00 0.0 Additives Additive Type Concentration Conc Unit label Fluid - --- -__...- --- -- --- Fluid Type Fluid Description Estimated Top (ftKB) - - -- __ _ Est Btm (ftKB) _-T - - _ Amount (sacks) _ _ _ _- Class --_ _ ----- Volume Pumped (bbl) PRIMARY G 10,593.0 11,486.0 153 G 31.5 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi). 1.16 0.00 0.00 15.80 0.00 0.0 Additives Additive Type Concentration Conc Unit label B-800 0.02 Additive Type Concentration Conc Unit label D-167 0.4 Additive Type Concentration Conc Unit label D-46 DEFOAMER 0.2 Additive Type Concentration Conc Unit label D-65 DISPERSANT 0.25 Page 1/1 Report Printed: 6/16/2008 o ' 0 w °o H C Q r H ~ ~ ~ O ~ C a ? ~~ °: 5 a ~ a ~, ' ~ a ~ ~ to O Y_ ~ O ` ~e • + , N ~ 'y a o L7 ~f7 ~ m c N O O L C O ~ W ~ ~ '- O ~ O ++ C O a ' ~ c_ '~ a ~~ a N O 3 v ~^ ~ i ~ H W = o ~ ~ ~ ~ ~ - ° N .: ~ ~L N p O l0 ~ n ~ = ~ N Q ° ^ V N . ~ I ~ ~ d G W a , ~ ~ ~ d I ~ m Z J °+r' c = ~ W = ~ ~ O ~` 0 ~! to CO 1~ 00 p O ~ N O t17 tf7 0 O O ~A O O O N 1~ 0 O O h to ~ ~' ~ (D ~ 67 0 0 ~ N GO O N ~ O O N N N ~~ ~ - a ~-~- w ~ ~ a C i o rn ti O O O ~ y ~ ~ ZT ~ N N O7 .~ ~ d L ~ _ :6 O 0 0 C F, I _ ~' ~ 0 o 0 o 0 CO ~ . a ~ I ' ~ >> O ~ y N h ~ a o °- ~ N ~ a ~ ~o ° `~~L~~~ o~ O y ~ O 4! rn C9 m~ d J O U 7 C ~,.~ ' ~ C y N w f. ~ ~ ~ m w ~ > of Z a . oo ~ a U o ~' - ~ ~ ~ o o .N ° ~ ~ ~ N ~ oMO •- "' Cfl O ~ t ~ 11 Y 0 ~ V W N ~ U O ~ r~n a ~ II ~ Q M vii p N 1[f Q U O N ~ ii O O ~ o = # ~ L y 0 M LL ~ O ~ ~ , ~ ~ ~~ ~ ~ M N ~ ~ M - V 0 II v ~ L m ~ ~ O ~,.~ O p ~~ 07 ~ d~ ~ W t G ~ ~ p J a n v» ~ O> O.J sZJ J ~ ~ ' O ~ , C r NO GOON ~' LLI G)~ ~OON N ' ~ N ~ to ~ O N o _ C tl! r` ~ ~ U en LL to F .. .. .. .. + M C ~ C'7 ~ C y L~ ~ L L a! ~ 0~ H ~ ~ ~ ~ ~ V ~ ~ c ~ x ~ ~ N ' CC d O L ~ ~ C o d N ao a rn>w aN ' H N ~ Z ~ w ~~ ° o0 o LL oo ~ ~~£ ~ ci ~ N C. U ~ U Y h m ~ W ~ ~ H N N Y GC J o m Z • d 3 d ~ o x w Y V eE m 3~ a M N H 7 o ~ N O c :. a° o C H ~+ d ~N O e ,_ 0 H ~ ZT W C W U ~ m O N ~ YQ U O W c o J ~ ,~ ~ Q ~~ 7 ~ Q~ N Z i ~~ m ~ ~ N U ~ cn ~ ~ m ~ ~ c ~ ~ o Z U ~ Q N ~ N CQ ~U 0 o °o °o °o o °o ~ ~ N ~ ~ ~ ~ 3~nss3ad N C r ~ 7 C m •G> ' a ~ Y Y~ ~ O ` N, ~ N L= ~ LZ m 1 O L O ~ 00 O ~ F ~ O ~+ C o. ~ ' ~ U c 'v, fl- ar ~ ~ ~I ~ ~ of >I ~ M o ~ , ~ ~ W ~ ° .:' l~ r <L Y N ~ O ~ 0 ii a ~ r N r R Q v a Gi a ~ W ~ d N ~ G1 o o . ;; ~ x i ~ Z . J R o ~ c w ~ ~ ~ ~ ~ ~ ~ ~ ~ 117NtAM ~~~ t(7 ~ N M ~ ~ r tn00.-~ IOM O 0 r-~NN NMM M M ~ ~~ti 0000 ~ N a~ ~ ~ ~ ~ a w ~ LL N ~ ti ~ 3 O GPI y O rn ~ rn rn rn .- a~ ~~ aN h ~ ~a M ~ a J J J Q O. b ~o 0 ai O o O o t.() c~i ~ N °~ ~ d ~ ~ ~ ~ ~ W za ~ ~o ~ -`=~~L~ N O E E H~•~ ~ ~~ to Z rn d d ~a~o •°c_'p-ao ahi + a °~ ~ ~_ ~~c~£ NN O W a~ GIN U ~ ~N ~ r; ~ o D o O~ ~~ ~ J J C ~ ~ ~ ~ c .~ ~ ^' N 00 ~ U ~ LL. ~ ~ v ~ O II V r. y C~C QJ aJ J ~ Cf ~ ~ C CO O O O M ~GI ~"~ O ~ / Y ~ ~ 0 0~ ~ ~ N y 'V tl) M O t` 7 00 U a~i LL tl~I H ~ r, d C L d~ L t i-7 N ~+ O M ~ R d C y N j H ~ H• °° v~•~ ~~> c d "~ is H ~ N '0 O~ 0> '~ a N H y 'b y ~ ~ y'~0 d ~o W .Z w ii C ~~ H o g a ~ x. o H ~ ~ ~ ~ F N Y U ~ I o W J Z ~ ~ ~ m II 3 ~ o x° w Y V t6 m M n N a~+ 7 N C d a c ~ 3 L ~ ~~ H v H LL O W J y V A ~ m f- w C7 Z N Q U 0 0 0 0 o ion 3anss3bd • Casing Detail Well: CD2-30 7"intermediate Casing Date: 09/03/03 ConocoPhillips Alaska DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.60 FMC 11" X 7" Hanger 2.65 34.60 Jts 3 to 269 267 Jts 7" 26# L-80 BTCM Csg 11354.26 37.25 7" Weatherford Float Collar 1.40 11391.51 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.05 11392.91 7" Ray Oil Tools Float Shoe(Silver bullet) 2.10 11478.96 11481.06 7" Shoe @ 11485.71' MD 7290' TVD TD of 8-1/2" hole @ 11499' MD 7290' TVD Total Centralizers: 58 Straight blade centralizer one per jt on jts # 1-22 Straight blade centralizer one per jt on jts. # 198,199, & 200 202,204,206,208,210,212,214,216,218,220,222,224,226,228,230,23 238,240,242,244,246,248,250,252,254,256,258,260,262,264,266 280 joints in pipe shed - 269 total jts. to run / last 11 joints stay out Use Best-o-Life 2000 i e do e Drifted to 6.151" MU Torque 7,200 ft/Ib Remarks: Up Wt = 220K Dn Wt = 100K Block Wt= 26K Supervisor: WhitlocWKuenz/er l J • Security Level: Development Daily Drilling Report CD2-30 Report Number: 10 Rig: DOYON 19 Report Date: 9/3/2003 AFE Type Neiwork/ID # Total AFE+Sup-- - _-- - ------ -- - --- 10030031 3,530,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2-30 Well Services ALPINE 9.00 10.0 0.00 11,499.0 11,499.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 263,601.00 1,878,359.00 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 8/25/2003 8/26/2003 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Ops and Depth ~ Morning Report 24hr Forecast Pertorming infectivity test on 9-5/8"" x 7"" annul Run 7" csg to 11485' and cement Last 24hr Summary Land casing at 11,481 and cement. Lack of significant returns d uring cement job. Decision made for operation shutdown (suspension) and move to CD2-18. General Remarks Weather Head Count 35 /28 / NNE @ 8 mph 47.0 ___ SL1peM50r __. __... Tdle G. Whitlock / Z. Kuenzler, Superv isor Supervisor Vern Johnson / Zane Kuenzler, E ngineer Engineer Time Lo ~ - Start End Dur ~ Tlme Tlme (hrs) phase ~ - Op Code OpSub-Code p -'-----------------. . ___-----'--_. ---- Time De th Start ~ Depth End P~N-T Trbl Code Trb1 Clasa (ftKB) ~ (ftKB) Operafion - 00:00 00:30 0.50 1NTRM1 CASE RUNC ----- - __ _ P -- 4,297.0 5,016.0 Run casing to 5016' 00:30 01:00 0.50 INTRM1 CASE CIRC P 5,016.0 5,016.0 Establish circulation @ 4 BPM, 390 psi. Circulate volume equal to casing capacity. FCP=520 psi @ 6 BPM 01:00 04:15 3.25 INTRMI CASE RUNC P 5,016.0 8,636.0 Run casing from 5016' to 8336'. Lost circulation at 8636'. 04:15 04:45 0.50 INTRM1 CASE CIRC T DH 8,636.0 8,636.0 Attempt to regain circulation. Attempt failed. 04:45 06:00 1.25 INTRMI CASE CIRC T DH 8,636.0 8,554.0 Lay down 2 jts of casing from 8636' to 8654'. Attempt to circulate @ 2.5 BPM, 450 psi..unsuccessful 06:00 07:45 1.75 INTRM1 CASE CIRC T DH 8,554.0 8,384.0 Lay down casing in 2 jt increments and attempt to circulate. Unsuccessful. 07:45 11:00 3.25 INTRMI CASE RUNC P 8,384.0 11,480.0 RIH while keeping casing full also keep annullus full with trip tank. P/U landing jt RIH to 11,480' 11:00 11:30 0.50 INTRM1 CASE RUNC P 11,480.0 11,484.0 Work casing down to 11,484' with PUW=350K SOW=150K. Need 1' to land casing. 11:30 12:00 0.50 INTRMI CASE RUNC P 11,484.0 11,484.0 Lay down Franks fill-up tool, RU cement head. Lost 245 bbl mud while running casing 12:00 14:00 2.00 INTRM1 CASE RUNC Np DH 11,484.0 11,484.0 Unable to land casing (1' short). Work casing and circ at 2.5 BPM, 510 psi. with 100% losses for 102 bbls. 14:00 15:00 1.00 INTRM1 CASE RUNC Np DH 11,484.0 11,481.0 Rig down casing head, POOH and UD landing jt. and UD jt. # 269 and exchange for shorterjt, RIH and P/U landing jt. S/O and land casing @ 11,481' 15:00 16:30 1.50 INTRM1 CASE CIRC P 11,481.0 11,481.0 Work casing and circulate @ 2.1 BPM, 520 psi with no returns. Latest BOP Test Data Date ~ I CommenE Page 1/2 Report Printed: 6/16/2008 Security Level: Development Daily Drilling Report CD2-30 Report Number: 10 Rig: DOYON 19 Report Date: 9/3/2003 - -- Time Lo -- _ -_ - - Start End Dur '~, __ _ __ __ -- j - i Time - - ~'~ Depth Start ~. Depth End Time l Time (hrs) Phase ' Op Code OpSub-Code P-N-T 7rbl Code ~ Trbl Class. ~' (ftKB) (ft#CB) Operafion 16:3019:00 2.50 iNTRM1 CEMENT PUMP P 11,481.0 11,481.0 PJSM, Pump 40 bbl LCM pill @ 5 BPM, 710 psi, Dowell pump 5 bbl Mudpush XL Spacer, drop bottom plug, pump 34 bbls15.8# tail slurry cmt, drop top plug, pump 20 bbl water, displace with 416 bbls 8.8 ppg brine, bump plug at 970 psi pump up to 1500 psi, bleed pressure, check float OK 19:00 20:00 1.00 INTRM1 CASE DEOT P 11,481.0 11,481.0 Pressure test casing to 3500 psi and hold for 30 minutes. Good test presure steady. 20:00 20:30 0.50 INTRM1 CASE RURD P 11,481.0 11,481.0 Rig down lines, UD casing elevators and landing jt. 20:30 21:30 1.00 INTRM1 CASE NUND P 11,481.0 11,481.0 Pull bushing, set pack-off and test to 5K psi, set bushing change out bails. 21:30 00:00 2.50 SUSPEN MOVE MOVE X 11,481.0 11,481.0 RIH with 55 stands DP to 5251'. POOH UD drillpipe (Balance derrick and make sure not overloaded for rig move) ~- Mud Check Data Type Depth (ftKB) Dens (Ib/gal) ~i Us (s/qt) YP Calc Gel (10s) Gel (10m) Gel (30m) T HTHP Felt -~ Denshy Tamp Solids, Corr PV Calc {cp) (Ibf/100iP) (Ibf/100ft') (Ibf/100fF) ', (Ibf1700ft') MBT (Ib/bbl) (mU.30min) ~, pH (°F) (%) Brine - KCL 7,290.0 8.80 LSND 7,290.0 10.00 49 9.0 25.000 9.0 14.0 15.006 15.0 10.0 8.8 LSND 7,290.0 10.00 51 9.0 27.000 13.0 17.0 19.008 15.0 10.2 8.7 Wellbores - -- Wellbore Name _ Wellbore APIlUWI CD2-30 ~ 501032046500 ~,. ~ Section Size (In) ~. Act Top (ftKB) Act Btm (ftKB) _ Start Date End Date 18 0.0 109.0 8/26/2003 10/20/2003 11 5/8 109.0 3,006.0 9 3.006_.0 11,481.0 10/30/2003 - - ----- - Cement _ _ Production Casin -Started 9/3/2003 Type Wellbore Cemented String Cement Evaluation Results casing CD2-30 Prod uction, 11,481.OffK6 Stg No. Description Top (ftKB) Bottom (ftKB] Q (end) (bbU... P (final) {psi) 1 __ _ _ Cement Casing - - - 10,593.0 11,486.0 5 830.0 Fluid Cl ass Amount (sacks) i V (bbl) i Dens1Ty (Iblgal) - Yield (ft'/sack) J Est Top (ftKB) _ ~ ~ Est Btm (ftKB) FLUSH 0 20.0 8.30 0.00 FLUSH 0 50.0 12.50 0.00 PRIMARY G 153 31.5 15.80 1.16 10,593.0 11,486.0 Page 2/2 Report Printed: 6!16/2008 • Security Level: Development Daily Drilling Report CD2-30 Report Number: 11 Rig: DOYON 19 Report Date: 9/4/2003 AFE Type - Network/ID # ~ Total HEE+Sup '~ 10030031 3,530,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ttKB) CD2-30 Well Services ALPINE 9.60 11.0 0.00 11,499.0 11,499.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 196,723.00 2,075,082.00 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 8/25/2003 8/26/2003 Last Casing String Next C asing OD (in) Next Casing Set Depth (RKB) Ops and Depth ~ Morning Report 24hr Forecast Rig released at 14:30 hrs Move to CD2-18 Last 24hr Summary UD drill pipe, freeze protect 7"" casing. Set tubing hanger to protect wellhead, N/D BOPs, N/U tree, release rig at 14:30 hrs. Dowell run infectivity test on 7""X9-5/8"" annulus and freeze protect. General Remarks Weather Head Count 35 /28 / NNE @ 8 mph 48.0 SupeMsor ~ Title - G Whitlock / Z Kuenzler, Supervi sor ',Supervisor Vern Johnson / Zane Kuenzler, E ngineer Engineer iTime Lo Start End ] Time Time '~ - _ --- Dur ~, (hrs) Phase '~ y - Op Cod - - -- e OpSub-Code Tlme J n-N-T { Trbl Code Trbl Class. _.._.-- Depth Start (RKB) - - Depth End (RKB) -- Operation ~'~ -.. - -_----- -.-_. 00:00 01:30 1.50 - SUSPEN MOVE MOVE X 11,481.0 11,481.0 UD drill pipe to 1813' 01:30 03:00 1.50 SUSPEN MOVE MOVE X 11,481.0 11,481.0 PJSM, cut 60' of drilling line, C/O rams to 3-1l2""X6"", service rig. 03:00 05:00 2.00 SUSPEN MOVE MOVE X 11,481.0 11,481.0 UD MH, R/U Dowell, freeze protect 7"" casing with 60 bbls diesel @ 2.1 BPM, 150 psi (reversing down annulus taking returns up DP) 05:00 05:45 0.75 SUSPEN MOVE MOVE X 11,481.0 11,481.0 POOH with 19 stands DP and stand back in derrick. 05:45 06:00 0.25 SUSPEN MOVE MOVE X 11,481.0 11,481.0 Top of 7"" casing with diesel. 06:00 06:15 0.25 SUSPEN MOVE MOVE X 11,481.0 11,481.0 Pull wear ring (Dowell test annulus, injecting brine) 06:15 07;30 1.25 SUSPEN MOVE MOVE X 11,481.0 11,481.0 P/U hanger, land jt, install two way check, land hanger. Unable to land, shear junk ring as hung up in stack. 07:30 09:30 2.00 SUSPEN MOVE MOVE Xt EOIP 11,481.0 11,481.0 Pull tbg hanger free, install new shear pins, C/O TDXO while working on hanger. Attempt to land hanger unsuccessful. 09:30 11:00 1.50 SUSPEN MOVE MOVE Xt EOIP 11,481.0 11,481.0 Push on hanger 6K with blocks, shear junk ring, pull hanger, FMC work on hanger. RIH with rebuilt hanger (sheared out). 11:00 11:30 0.50 SUSPEN MOVE MOVE X 11,481.0 11,481.0 UD hanger, land jt. 11:30 12:00 0.50 SUSPEN MOVE MOVE X 11,481.0 11,481.0 Install thin wall wear ring 12:00 14:30 2.50 SUSPEN MOVE MOVE X 11,481.0 11,481.0 N/D BOPs, pull thin wall wear ring by hand (profile to tall for wellhead to fit), P/U landing jt. B, install tubing hanger and two way check, N/U tree and test to 5K psi. FMC test hanger seals to 5K psi OK, secure well. Rig release at 14:30 hrs on (9/4/2003) Wellbores - -- - _ Wellbore Name ~ Wellbore AP!/UWi i CD2-30 50103204650 1 Section Size (in) ', Act Top (ftK8) i Act Btm (RKB) Start Date End Date - 'I 18 0.0 109.0 8 /26/2003 10/20/2003 Latest BOP Test Data Date j _ Comment Page 1/2 Report Printed: 6/1 6120 0 8 • • Security Level: Development Daily Drilling Report y CD2-30 Report Number: 11 Rig: DOYON 19 Report Date: 9/4/2003 Section _.. j _ Size (in) Act Top (ftKB) ~ Act Btm (ftK6) _ Starl Date E nd Date _ 11 5/8 109.0 3,006.0 _ _ - 9 3,006.0 11,481.0 10/30!2003 Page 2/2 Report Printed: 6/16/2008 • a: ~_~': Cement Detail Report CD2-30 ... Surface Casing 'Cement Details Description Cementng Start Date Cementing End Date Wellbore Name Surface Casing 8/28/2003 05:03 8/28/2003 06:42 CD2-30 Comment Cement Stages _ --- - - _ _ _ _ _ -- _ ' Stake #_1 Description Objective Top (ftKB) Bottom (ftKB) Full Return? ' Cmnt Rtrn ... Top Plug? Btm Plug? Cement Casing 0.0 3,006.0 125.0 Yes Yes Q (start) (bbl/min) Q (end) (bbllmin) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 650.0 1,150.0 20.00 Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pipe movement: Reciprocating Drag down (Ibs): 120 Drag up (Ibs): 180 Time started reciprocating: 03:00 Time stopped reciprocating: 05:53 Cement Found Between Shoe and Collar (Y/N): Y Cement found on liner tool (Y/N): N Annular flow after cement job (Y/N): N Pressure before cementing (psi): 470 Hours circulated between stages: 1.5 Bbls cmt to surf: 125 Method used to measure density: DS Returns (pct): 100 Time cementing mixing started: 05:03 'Cement Fluids & Additives '~~Fluid _ - - - -- - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) FLUSH MUDPUSH XL 0 50.0 Yield (fN/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) o.oo o.oo o.o0 10.50 0.00 0.0 Additives Additive Type Concentration Conc Unit label _ - - - - Fluid _ - - --- _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) LEAD ASLite 0.0 2,506.0 450 343.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.28 19.39 0.00 10.70 0.00 0.0 Additives Additive Type Concentration Conc Unit label D-44 ACCELERATOR 9.0 %BWOW Additive Type Concentration Conc Unit label S1 ACCELERATOR 1.5 %BWOC Additive Type Concentration Conc Unit label D-46 DEFOAMER 0.6 %BWOC Additive Type Concentration Conc Unit label D-65 DISPERSANT 0.5 %BWOC Additive Type Concentration Conc Unit label D-79 EXTENDER 1.5 %BWOC Additive Type Concentration Conc Unit label D-124 FILLITE 43.1 %BWOC Additive Type Concentration Conc Unit label D-53 GYPSUM 30.0 %BWOC Page 1/2 Report Printed: 6/16/2008 Cement Detail Report CD2-30 Surface Casing 'Cement Fluids 8 Additives __ --_-__ - _ - Fluid - - -- _ _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) 'Amount (sacks) Class Volume Pumped (bbl) TAIL 2,506.0 3,006.0 235 G 47.5 Yield (ft%sack) Mix H2O Ratio (gaUsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.10 0.00 15.80 0.00 0.0 Additives Additive Type Concentration Conc Unit label S1 ACCELERATOR 2.0 %BWOC Additive Type Concentration Conc Unit label D-46 DEFOAMER 0.2 %BWOC Additive Type Concentration Conc Unit label D-65 DISPERSANT 0.3 %BWOC Page 2/2 Report Printed: 6/16/2008 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-30 Rig: [)oyon 19 Date: 9/4/2003 Drilling Supervisor: Kuenzler/Whitlock Pump used: Cement Unit ._ ~ P i d T f T t ~ Volume Input Barrels ~ Pump Rate: 0.0840 Bbis/strk l ~ 6.0 strk/min ~ ype O es : Annulus Leak Off Test for Disposal Adequacy ~ ump ng own annulus. Casing Test Pressure In te rit Test Hole Size: ~ s-1/2^ ~ Casin Shoe Depth Hole Depth Pumpin Shut-in Pumpin Shut-in RKB-CHF: 36.7 Ft 3,006 Ft-MD 2,383 Ft-TVD 3,036 Ft-MD 2,401 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9-s/s" 36#/Ft J-55 BTC ~ 0 0 0 530 Chan es for Annula r Ade ua c Test Pressure In te rit Test 0.5 116 0.25 449 uter casing shoe test results 16.1 in comments Mud Weight: 10.0 ppg 1 177 0.5 434 Description references outer 14.0 casing string. Inner casing OD: 7.0 In. 1.5 237 1 424 ize is that drilled below outer 2,500 casing. 2 288 1.5 '119 timated TOC for Hole Depth. 75,000 2.5 348 2 414 Enter inner casing OD at right 75,000 Desired PIT EMW: 16.0 ppg 3 399 2.5 409 --- - --- _ -- Estimates for Test: 743 psi 0.3 bbls 3.5 449 3 404 ~ ~ ~ 4 495 3.5 399 EMW =Leak-off Pressure + Mud Weight = 631 PIT 15 Second 4.5 530 4 399 + 10 0.052 x TVD 0.052 x 2383 Shut-in Pressure, psi 5 565 4.5 394 EMW at 3006 Ft-MD (2383 Ft-ND) = 15.1 449 5 ~~ 591 5 389 iooo - - - ~~ 616 5.5 384 6.~ 631 6 384 ' 626 6.5 379 - 7.5 570 7 374 8 555 7.5 374 - - - - 8 5 545 8 374 - . w 9 540 8.5 369 ~ - - - 9.5 540 9 369 ~ I 10 530 9.5 364 eao rn w ~ I 10 359 a I -- --- ~ 0 0 2 4 6 8 10 12 0 5 1 0 1 5 2 0 2 5 3 0 ~~CA Barrels SING TEST --+•-L EAK-OFF TES T S hut-I O PI n tim T Poin e, Mi t nute s Volume PUm ed Volume Bled Back Volume PUm ed Volume Bled Back s 7 bls 0.0 B s s Comments: 9-5/8" casing shoe tested to 16.1 ppg EMW when drilled out. TOC behind 7" casing shoe unknown due to lost returns. Slurry top calculated at 11,600' MD based on volumes of cement pumped. • ~~,.>- ~~ ~...~ „~:~ - ,~, MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_InsertslMicrofilm_Marker.doc y/ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 SCANNED APR 2 7 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 :Jþ3~ \&5 Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~.t:~--_/ ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft Qal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-1 09 6" na 6" na 2.5 2/18/2007 C02-404 206-054 6" na 6" na 1.8 3/22/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 318/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 , CD2..ao 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~,"" ;1-(~ ~=, March 31,2007 .,' .... ...-- Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK. 99501 5GkNMiD APR () 5 2007 ~-' \ ôS ~Ðv Dear Mr. Maunder: . ....,' ..~",-,,,,,.,....-.-.~ Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 CO2-3D 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 CD2-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 CD2-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 CD2-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . WELL LOG TRANSMITTAL ~. .<"..~'}i~_2"f¡~'::Ü Novgrñ1Jêr'~16, 2006 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: CD2-1O_PB1, CD2-11, CD2-17A, CD2-27, CD2-28_PB1, CD2-30. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-1O_PB1: 803 - JCJS- -J:f ¡4L/lfo Digital Log Images: 50-103-20473-00, 70 u::rc... CD2-11: f)o-S--13.9 ;:t 141..//1- Digital Log Images: 50-103-20515-00 1 CD Rom SCANNED FEB 0 1 2007 1 CD Rom CD2-17A: UIC.. &OS--Oì--:¡' -d. ILILIle>, Digital Log Images: 50-103-20406-01 1 CD Rom CD2-27: v:r..c...- 6>06 -¡":f+ t t...fL} 11) Digital Log Images: 50-103-20471-00 1 CD Rom CD2-28 PB1: ¿)08 -Ç)I¿' tt 1¿../¿../lS- Digital Log Images: 50-103-20435-00, 70 CD2-30: U IC- Q0"3-13S- tr 14L/IL/ Digital Log Images: 50-103-20465-00 1 CD Rom 1 CD Rom ?- MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commissl TO: Jim Regg P.I. Supervisor ,/j . C) ¡~·'I. "t- ì¡(,:2fl ;),'> v, DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-30 COL VILLE RIV UNIT CD2-30 ; \?J~ ~OÔ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ''j.'7,ç - P.I. Suprv , I~ Comm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT C02-30 API Well Number 50-103-20465-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060828 I 42546 Permit Number: 203- I3 5-0 Inspection Date: 8/26/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well C02-30 ¡Type Inj. w TVD 7089 IA 1500 2480 2460 2460 P.T. 2031350 TypeTest SPT Test psi 1772.25 OA 150 150 150 150 Interval INITAL P/F P v' Tubing 2000 2000 2000 2000 I Notes Pretest pressure observed and found stable SCANNED SfP 082003 Wednesday, August 30, 2006 Page I of I e e WELL LOG TRANSMITfAL J3EE5C) To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 February 17, 2004 RE: MWD Formation Evaluation Logs: CD2-30, AK-MW-2601675 CD2-30: Digital Log Images: 50-103-20465-00 ;}ðS"-/3fJ- 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Dólling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ?l h '') nl' 7\/ Date: '/ (;r 'ct, lÁLJ Signed: ~()[! n 3 ~ 116 v .;«() <,') l DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 s,4 À' 4~ ;'ðo) API No. 50-103-20465-00-00 Permit to Drill 2031350 Well NamelNo. COLVILLE RIV UNIT CD2-30 Operator CONOCOPHILLlPS ALASKA INC MD 15700 ,.- TVD 7268 ..", Completion Date 1 0/30/2003 / Completion Status WAGIN Current Status WAGIN é UIC Y--L "- REQUIRED INFORMATION DirectiOQ~eS ) Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes, USIT, CBL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~D Asc Directional Survey 0 15700 2/3/2005 IIFR (Sag Corrected) og Cement Evaluation 5 Col 9950 11270 Case 9/28/2003 SCMT-Cement Bond Log - SCMT wlWelltec Tractor /g Cement Evaluation 5 Col 9876 11270 Case 11/24/2003 Ultrasonic Imager Tool - Cement USRS-AB/SGT- N/CAL- Y ~ Cement Evaluation 5 Col 9900 11350 Case 11/24/2003 Ultrasonic Imager Tool - Cement USRS-B/DSL T- H/SGT -N I Rpt Directional Survey 0 15700 12/8/2003 Rpt Directional Survey 0 15700 12/8/2003 MWD .rED D '-.() 12313 Induction/Resistivity 2982 15644 Open 12/22/2003 GR, EWR4, Rap ~Pt IflQldction/Rocioti\'ity Vt"'';''~ '-....\ \ "'- ~.1 r-- 2982 15644 Open 12/22/2003 ~D D "" t ~ 12313 Rate of Penetration 2982 15644 Open 12/22/2003 GR, EWR4, Rap /~ R.)~ of Pe,\et,ðtion (OR? -15<;,1 A n.r~'1 1 ?/??/'70n<>. r.R. ~'^'Pi, no:-' - ;"AD C Las 12479 Temperature 10650 14636 Open 3/22/2004 Baseline Temp Log ~ Pdf 12479 Temperature 10650 14636 Open 3/22/2004 Baseline Temp Log Temperature BM 1 10650 14636 Open 3/22/2004 Baseline Temp Log JED C Las 12479 Temperature 2 10650 14642 Open 3/22/2004 Temperature Warm Back ~ Log ED C Pdf 12479 Temperature 2 10650 14642 Open 3/22/2004 Temperature Warm Back ~ Log Temperature BM 2 10650 14642 Open 3/22/2004 Temperature Warm Back Log -~ . . Permit to Drill 2031350 DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 Well Name/No. COLVILLE RIV UNIT CD2-30 Operator CONOCOPHILLlPS ALASKA INC MD 15700 TVD 7268 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis Received? T'7"JCJ Comments: Compliance Reviewed By: Completion Date 1 0/30/2003 Jo Completion Status WAGIN Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status WAGIN Sample Set Number Comments <ÐN ~/N Date: API No. 50-103-20465-00-00 UIC Y ) C{ IJ~rJJroy . . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . 01-Feb-05 DEFINITIVE Re: Distribution of Survey Data for Well CD2-30(Sag Corrected) Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 15,700.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage,AK 99518 Date Jhb~ç- µ/) 1iLJ PI ¡ 'I Signed .. (J , Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ;< C)~- (~)~ MEMORANDUM - State of Ala. Alaska Oil and Gas Conservation Commission TO: JimRegg \3, 4\Z3\ctr P.I. Supervisor e11 FROM: Lou Grimaldi Petroleum Inspector API Well Number: W, ."en:.¡. C02-30 IType I~j. ",;:T¡¡' 20313S0 TypeTèst Interval Initial Test Notes: No Problems Tuesday, April 20, 2004 DATE: Tuesday, April 20, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-30 COLVILLE RJV UNIT CD2-30 Src: Inspector NON-CONFIDENTIAL 50-103-20465-00-00 Insp No: mitLG04040 1183951 Inspection Date: 15 Min. 30 Min. 45 Min. 60 Min. Packer Depth Pretest Initial P TVD 7072 IA 1700 2300 SPT Test psi 1768 OA 500 500 P/F P Tubing 1000 1000 2280 2280 500 980 500 980 Reviewed By: . P.I. Suprv :1!;a.. 4/'1.3(04- Comm 3/31/2004 Page I of I MEMORANDUM TO: . Jim Regg ~¿; .t~ lo.t" P.I. Supervisor ~1 FROM: Lou Grimaldi Petroleum Inspector API Well Number: Well: I. CD2-30 P .T. 103U5O Interval IType Inj. TypeTest Initial Test Notes: No Problems Friday, April 02, 2004 50-103-20465-00-00 Packer P I TVD SPT Test psi PIF State of A.c.a I Alaska Oil and Gas Conservation Commission DATE: Friday, April 02, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-30 COLVILLE RIV UNIT CD2-30 Src: Inspector NON-CONFIDENTIAL Insp No: mitLG040401183951 Depth Pretest Initial 7072 I IA 1700 2300 1768 OA 500 500 Tubing 1000 1000 Reviewed By: /'j 4- h I ok P.I. Suprv -J f!:R-- Comm Inspection Date: 3/31/2004 15 Min. 30 Min. 45 Min. 60 Min. 2280 2280 500 500 980 980 Page I of! (Ws --.=I\J II' dL. LOG TRANSM,"AL . 3ð3'-J35 ProActive Diagnostic SelVices, 'nc. To: AOGCC 333 West 7th Ave, Ste. 100 Anchorage, AK 99501-3539 RE: Distribution - Final Print(sJ 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 : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL DATE loG TVPE DIGITAL OR CD-ROM 1 MVLAR / SEPIA FILM 1 BLUE LINE PRINT(S] REPORT OR BLUE LINE Open Hole 1 C02-3D 2-23-04 , Res. Eva!. CH 1 J 8 J-} '1-CJ 1 1 Mech. CH Caliper Survey 1CO 1 Rpt or 1 Color Signed : -.....,... - ..-'\:) ~j'--"-Á i~ . '\ -.f ~:;¡~ J~..~. Date: RECEIVED Print Name: ~·1 ,~p ?:) 0004 t ,; ,\... '- .._ L Alaska OH & Gas Cons. Commisaktn Anchorage PRoACTivE DÌAGNOSTic SERVicES, INC., PO Box 1 ~69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~~Y\\~ (ids· =\J II- WtfL LOG TRANSMITTAL . ~03--J3£:) ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave. Ste. 100 Anchorage, AK 99501-3539 RE : Distribution - Final Print(s) 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 : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL DATE loG TyPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 CD2-3D 2-25-04 Res. Eva!. CH 1 J ~)../ '1C1 1 1 Mech. CH Caliper Survey 1CD 1 Rpt or 1 Color Signed: -....... .. . , ~éj \.~""~ '(6L~ J~ ,/v"",, Date: RECEIVED Print Name: ~.i .c\ f) ? ,) 1')004 ~ U-'I" '- :._ L.. .Alaska Oil & Gas Cons. Commisakm Anchorage PRoAcTivE DiAGNosTic SERvicES, INC., PO Box 1 }b9 STAffoRd IX 77477 Phone:(28l) 565-9085 Fax:(28l) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com 'R~~'~J'" ~~ . Conoc~hillips . G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 March 2, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-30 (APD 203-135) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD2-30. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, _4- L_ ~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad MAR 0 3 2004 OR' G 1 t\lð\ t_ . STATE OF ALASKA .- ALA OIL AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas U GINJ D 2. Operator Name: WINJ D WDSPL D Plugged D Abandoned D 20AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1865' FNL, 1527' FEL, Sec. 2, T11 N, R4E, UM At Top Productive Horizon: 7' FSL, 2637' FWL, Sec. 3, T11 N, R4E, UM Total Depth: 1448' FNL, 609' FWL, Sec. 3, T11 N, R4E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371712 y- TPI: x- 365262 y- Total Depth: x- 363298' y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GR/Res, USIT, CBL 22. CASING SIZE WT. PER FT. 16" 62.5# 9.625" 36# 7" 26# GRADE H-40 J-55 L-80 Zone-4 Zone-4 Zone-4 5974493 5971197 5975058 ' Suspended D WAG 0 20AAC 25.110 Other 5. Date Comp., Susp., or Aband.: October 30, 2003 6. Date Spudded: August 26, 2003 . 7. Date TD Reached: October 28, 2003 8. KB Elevation (It): 36.9' RKB / 52.8' AMSL 9. Plug Back Depth (MD + TVD): · 15700' MD / 7268' TVD 10. Total Depth (MD + TVD): 15700' MD / 7268' TVD 11. Depth where SSSV set: DB nipple @ 2374' 19. Water Depth, if Offshore: N/A feet MSL CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 3006' Surface 11481' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): not perforated, open hole completion from 11481' - 15700' 26. Date First Production February 3, 2004 Date of Test Hours Tested N/A Flow Tubing press. xxx psi 27. Casing Pressure iØJMS BfL Form 10-407 Revised 2/2003 24-Hour Rate -> MA~ \) 1DO~ONE 1b. Well Class: Development D Exploratory D Service 0 Stratigraphic Test D 12. Permit to Drill Number: 203-135/303-268/303-300/303-321 13. API Number: 50-103-20465-00 14. Well Name and Number: CD2-30 15. Field/Pool(s): Colville River Field Alpine Oil Pool 16. Property Designation: ALK 380075, 387207 17. Land Use Permit: ADL N/A 20. Thickness of Permafrost: 1561' MD CEMENTING RECORD HOLE SIZE 42" 12.25" 8.5" 12 yds POrtland Type III 450 sx AS III Lite, 235 sx Class G 153 sx Class G 24. SIZE 4.5" AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 10937' PACKER SET (MD) 10861 ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A WATER-BBL GAS-MCF WATER-BBL Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). "...__.....;.-,...__'..__..»t Submit core chips; if none, state "none". i COMPLETION ¡ \ JD;\!~ðd \ ~=D .J ~-,....---""-"~ PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) Injector Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL CORE DATA CONTINUED ON REVERSE SIDE ,;\ \t\I.i~.' ~: ':(ò t \ t>:.~ CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY - API (corr) not available MAR 0 :~ 2004 Submit in duplicate c.,F 28. GEOLOGIC MARKERS. 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state 'None'. CD2-30 Seabee Form. Nanushak Gamma Ray Shale Kalubik Kuparuk Formation Miluveach Top Alpine 0 Top Alpine C TO 3054' 5413' 10460' 10818' 10914' 11018' 11291 ' 11362' 15700' 2411' 3839' 6860' 7053' 7095' 7139' 7240' 7259' 7268' N/A PI o 3 2004 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Zane Kuenzler @ 265-1308 p~nted Name .II ..L G..t1ipj\lvord Signature r- {}{/.- Title: Alpine Drilling Team Leader Phone t.c..S - 4 ILQ Date ~lL(O+ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 poot completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". ORIGINAL Form 1 0-407 Revised 2/2003 ,.. A Page 1 of 9 ConocoPhillips Alaska Operations Summary Report Move back Pit/Motor Complex - skid rig floor - move rig off CD2-40 - remove outside walkway (rigfloor to mud pits) for modifications. Move subbase to CD2-30. Move subbase over CD2-30, attempted to set cantilever feet, ODS ram would not retract. Troubleshoot hydraulic problem - unable to identify problem - mechanically retracted ram to install onto foot. Level subbase - skid rig floor - spot Pit/Motor complex and Ball Mill. Connect service lines, take on mud at 1830 hrs. Complete repairs to Iron Roughneck. Accepted rig @ 1900 hrs. NU riser and prepare to pick up BHA. MU bit, motor and MWD, scribe tools and upload MWD. MU stab and collars - fill Conductor and test mud lines to 2500 psi. Spud well @ 0005 hrs, Drill from 114' to 166' - 400 gpm / 540 psi - WOB 20K - 50 rpm. Run Gyro survey @ 84'. Drill from 166' to 255' - 450 gpm / 640 psi. Run Gyro survey @ 174', no good - gyro drifted. Re-run Gyro survey @ 174'. Drill from 255' to 346' - 450 gpm / 650 psi 20-25K WOB - 50 rpm Run Gyro survey @ 266', no good - gyro drifted. Re-run Gyro survey @ 266'. Drill from 346' to 436' - 500 gpm / 820 psi 20-30K WOB 50 rpm Run Gyro survey @ 356'. Drill from 436' to 1375' (1323' tvd) survey with MWD. 0000-1200 ART=3.05 hrs AST=3.05 hrs PUW 125K SOW 120K ROTWT 122K 550 gpm /1620 psi 50 rpm WOB 20-35K 12.00 DRILL DRLG SURFAC Drill from 1375' to 2750' (2234 tvd) ART =5.7 hrs AST =1.91 hrs 550-650 GPM /1620-2140 PSI - 60170 rpm PUW 135K SOW 120K ROT WT 130K WOB 30-40K 2.00 DRILL DRLG SURFAC Drill from 2756' to 2853' ART =1.8, AST =0, ADT =1.8 0.50 DRILL REAM SURFAC Pump pressure increased to 2800 psi. Work tite hole form 2853' to 2782' w/ 60 rpm, 650 gpm, 2460 psi. 2.50 DRILL DRLG SURFAC Pumped 30 bbls wt. sweep (2 ppg over) Drill from 2853' to 3016' TVD= 2295', ART=1.65, AST=.54, ADT=2.19, PUW= 145k, SOW=125k, ROT =130k, Torque=9000 on/7000 off. Rotary = 60, WOB=25/40, pump=2420 psi @ 184 spm (650 gpm) Large increase in cuttings volume and size with sweep back. Circ 2 - 30 bbl weighted sweeps around ( 2.5 ppg over) large increase in cuttings volume and size back with each sweep. 650 gpm / 2280 psi / 60 rpm (book limit) Pump out of hole from 3016' to 2560'. POOH on trip tank from 2560' to 944' Hole starting to get tite @ 944' CBU and work pipe from 944' to 850' POOH on trip tank from 944' to 600' RIH from 600' to 1037' worked through bridge 1027' to 1037' Establish circulation and ream from 1037' to 1133'. CBU Legal Well Name: CD2-30 Common Well Name: CD2-30 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code: ---.-....-..--.... .... .. . " 8/25/2003 08:00 - 12:00 4.00 MOVE MOVE MOVE 12:00 - 13:00 1.00 MOVE MOVE MOVE 13:00 - 16:00 3.00 MOVE RGRP MOVE 16:00 - 19:00 3.00 MOVE MOVE MOVE 19:00 - 21 :30 2.50 MOVE RURD RIGUP 21 :30 - 00:00 2.50 DRILL PULD SURFAC 8/26/2003 00:00 - 00:40 0.67 DRILL DRLG SURFAC 00:40 - 01 :00 0.33 DRILL SURV SURFAC 01 :00 - 01 :30 0.50 DRILL DRLG SURFAC 01 :30 - 01 :50 0.33 DRILL SURV SURFAC 01 :50 - 02:05 0.25 DRILL SURV SURFAC 02:05 - 02:45 0.67 DRILL DRLG SURFAC 02:45 - 03:05 0.33 DRILL SURV SURFAC 03:05 - 03:20 0.25 DRILL SURV SURFAC 03:20 - 04:10 0.83 DRILL DRLG SURFAC 04:10 - 04:30 0.33 DRILL SURV SURFAC 04:30 - 12:00 7.50 DRILL DRLG SURFAC 12:00 - 00:00 8/27/2003 00:00 - 02:00 02:00 - 02:30 02:30 - 05:00 05:00 - 06:30 1.50 DRILL CIRC SURFAC 06:30 - 08:30 2.00 DRILL WIPR SURFAC 08:30 - 09:00 0.50 DRILL REAM SURFAC 09:00 - 09:30 0.50 DRILL WIPR SURFAC 09:30 - 09:45 0.25 DRILL WIPR SURFAC 09:45 - 10:15 0.50 DRILL REAM SURFAC Start: 8/25/2003 Rig Release: 10/30/2003 Rig Number: Spud Date: 8/26/2003 End: 10/30/2003 Group: Description of Operations Printed: 12/9/2003 3:06:17 PM ... ,., ... Page 2 of 9 ConocoPhillips Alaska Operations Summary Report RIH from 1133' to 1200' and hit bridge. Ream to 1230'. RIH from 1230' to 1250' and hit bridge. Ream from 1250' to 1420' RIH from 1420' to 2940' wI no problems. Precautionary ream from 2940' to 3016', circ and condition mud- pumped 2 - 20 bbls wt. sweep around - moderate incease in cuttings back with sweeps. 650 gpm I 2050 I 60 rpm POOH on trip tank from 3016' to 978' 15-10K over, no problems. Monitor well static - stand back hwdp and flex collars. LD BHA #1 - stab, UBHO, MWD, xo, FS, motor and bit. Clear tools and clean rig floor. RU to run 9 5/8" casing. Held prejob safety and opts meeting with crew. Run 9 5/8",36#, J-55 BTC casing: FS, 2 jts, FC, 2 jts (all connections BakerLoc'd) circ to check floats, ok. Run casing to 1574' (38 jts total). Worked pipe through tight spots from 620' to 700' - Washed down from 1320' to 1360' and from 1489' to 1500' - 4.0 bpm 1260-300 psi. Continue running surface casing to 2285' Circulate joint 56 down from 2285' to 2326' to break gels in mud. Continue running 9-5/8" surface casing. M/U landing jt and land casing @ 3006'. Total of 71 jts of 9-5/8" 36#, J-55 BTC casing run. UD fillup tool RlU cement head Establish circulation @ 334 gpm @ 530 psi. Circulate and condition mud. Final rate=369 gpm @ 470 psi Mix and pump 40 bbl viscosified water wI 6 sx nut plug wI rig pump while reciprocating pipe @ 1 spm for 20' stroke. Cementers pump 5 bbl water and pressure tested lines to 2500 psi. Drop bottom plug. Mix and pump 50 bbl Mudpush XL @ 10.5 ppg, 5.6 bpm, 195 psi. Mix and pump 343 bbl Lead @ 10.7 ppg @ 7.5 bpm 175 psi. Had nut plug at shakers and switched to Tail. Mixed and pump 47.5 bbl Tail @ 15.8 ppg 4.7 bpm, 210 psi. Dropped top plug and Pumped 20 bbl water wI cementer. Quit reciprocating after 32 bbl tail were mixed and pumped. Displace cement wI 9.8 ppg mud wI rig pump @ 6.7 bpm 650 psi. Bumped plug wI 2469 strokes and 1150 psi. Floats held. Pumped 125 bbl cement to surface. RlU and test casing to 2500 psi for 30 minutes RID cement head and UD landing jt. N/D riser, surface equipment and slip lock assembly N/U unihead and test to 1000 psi for 10 min. N/U BOPE and change Topdrive saver sub. RlU to test BOPE- Install mousehole Test BOPE: Pipe & Blind rams, choke line, kill line, manifold and surface safety vales to 250 I 5000 psi - Annular preventer 250 I 3500 psi. AOGCC (Chuck Sheve) waived witnessing tests. 0.50 CASE NUND SURFAC Blow down lines, pull test plug and install wear bushing. 0.50 DRILL OTHR SURFAC Install drilling bails and drill pipe elavators. 1.50 DRILL PULD SURFAC RIH - PU 60 jts of 4" drill pipe from shed. 1.50 RIGMNT RSRV SURFAC Slip and cut drilling line - service Top Drive. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-30 CD2-30 ROT - DRILLING doyon1 @ppco.com Doyon 19 Date From-to Hours Code Sub Phase Code 8/27/2003 10:15-11:00 0.75 DRILL REAM SURFAC 11 :00 - 12:00 1.00 DRILL WIPR SURFAC 12:00 - 14:30 2.50 DRILL CIRC SURFAC 14:30 - 16:30 2.00 DRILL TRIP SURFAC 16:30 - 18:30 2.00 DRILL PULD SURFAC 18:30 - 20:15 1.75 CASE RURD SURFAC 20:15 - 20:30 0.25 CASE SFTY SURFAC 20:30 - 00:00 3.50 CASE RUNC SURFAC 8/28/2003 00:00 - 00:45 0.75 CASE RUNC SURFAC 00:45 - 01 :00 0.25 CASE CIRC SURFAC 01 :00 - 02:15 1.25 CASE RUNC SURFAC 02:15 - 02:30 0.25 CASE RURD SURFAC 02:30 - 03:00 0.50 CASE RURD SURFAC 03:00 - 04:30 1.50 CEMENTCIRC SURFAC 04:30 - 06:00 1.50 CEMENT PUMP SURFAC 06:00 - 06:45 0.75 CEMENTDISP SURFAC 06:45 - 07:45 1.00 CASE MIT SURFAC 07:45 - 08:30 0.75 CEMENTRURD SURFAC 08:30 - 09:30 1.00 CASE NUND SURFAC 09:30 - 11 :30 2.00 CASE NUND SURFAC 11 :30 - 12:00 0.50 WELCTL OTHR SURFAC 12:00 - 16:30 4.50 WELCTL BOPE SURFAC 16:30 - 17:00 17:00 - 17:30 17:30 - 19:00 19:00 - 20:30 20:30 - 21 :30 21 :30 - 00:00 Start: 8/25/2003 Rig Release: 10/30/2003 Rig Number: Spud Date: 8/26/2003 End: 10/30/2003 Group: Description of Operations 1.00 DRILL TRIP SURFAC POH - set back 20 stands of drill pipe. 2.50 DRILL PULD SURFAC MU BHA #2 - 8 1/2" Geo Pilot assembly - upload MWD. Printed: 12/9/2003 3:06:17 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ... .. Page 3 of 9 ConocoPhillips Alaska Operations Summary Report CD2-30 CD2-30 ROT - DRILLING doyon1 @ppco.com Doyon 19 Date From - To Hours Code ···.;~dfe Phase 8/29/2003 00:00 - 00:45 00:45 - 02:00 02:00 - 02:30 02:30 - 04:15 04: 15 - 04:45 04:45 - 05:00 05:00 - 07:30 07:30 - 08:00 08:00 - 08:45 08:45 - 12:00 12:00 - 00:00 8/30/2003 00:00 - 12:00 12:00 - 00:00 8/31/2003 00:00 - 12:00 12:00 - 18:00 0.75 DRILL PULD SURFAC 1.25 DRILL PULD SURFAC 0.50 DRILL TRIP SURFAC 1.75 DRILL TRIP SURFAC 0.50 DRILL TRIP SURFAC 0.25 CEMENTCOUT SURFAC 2.50 CEMENTDSHO SURFAC 0.50 DRILL CIRC SURFAC 0.75 CEMENT FIT SURFAC 3.25 DRILL DRLG INTRM1 12.00 DRILL DRLG INTRM1 12.00 DRILL DRLG INTRM1 12.00 DRILL DRLG INTRM1 12.00 DRILL DRLG INTRM1 6.00 DRILL DRLG INTRM1 18:00 - 19:30 1.50 DRILL CIRC INTRM1 19:30 - 21 :15 1.75 DRILL WIPR INTRM1 21:15-00:00 2.75 DRILL WIPR INTRM1 9/1/2003 00:00 - 00:15 0.25 DRILL WIPR INTRM1 00:15 - 00:45 0.50 RIGMNT RSRV INTRM1 00:45 - 04:00 3.25 DRILL WIPR INTRM1 Start: 8/25/2003 Rig Release: 10/30/2003 Rig Number: Spud Date: 8/26/2003 End: 10/30/2003 Group: Deßçription pr Operations Load MWD and test Trouble shoot communications problems wI MWD and Geopilot RIH wI NMDC's, HWDP and change handling equipment to 4" P/U 45 jts 4" d.p. and 2 ghost reamers to 2078'. Fill drillpipe RIH wI d.p. from derrick to 2837' Wash and ream while breaking in geo-pilot from 2837' to 2905' @ 495 gpm @ 1930 psi. Drill cement/ float equipment from 2905' to 3016'1 Drill 20' of new hole from 3016' to 3036' Circ and displace hole wI new LSND mud. Clean surface equipment Perform FIT to 16.1 pgg EMW. (800 psi @ 2383' TVD shoe depth wI 9.6 ppg mud) Drill from 3036' to 3666'. ART=2.4 TVD=2772', PU=140, SO=110, Rot=120, Torque= 8500 onl 7000 off. Rotary = 180 WOB= 5-10, Pump = 2250 psi @ 185 spm (650 gpm) Pump hi-vis sweeps every 300 feet. Housing on geopilot rolling due to soft formation-causing no directional problems Drill from 3666' to 4937' (3557" tvd) ART =7.0 PUW 155K SOW 115K ROT WT 135K 600-650 gpm I 2450 - 2800 psi ECD 10.8 - 11.1 ppg Torque onloff 8500/7000 ft/lbs RPM 90-180 Pumped 40 bbls 180 FV sweeps @ 3920',4217',4750' 5050' with slight/moderate increase in cuttings volume with sweeps back. Drill from 4937' to6465' (4427' tvd) ART =7.96 hrs PUW 185K SOW 122K bRaT WT 145K 600-640 gpm I 2480-3550 psi ECD 10.5 - 11.1 ppg Torque onloff 11000/10000 ft/lbs Pumped 35 bbls 200+ FV sweeps @ 5050', 5430', 5830' and 6375' - moderate increase in cuttings volume and size with sweeps back. Drill from 6465' to 8065' (5352' tvd) ART =7.64 hrs PUW 213K SOW 125K ROTWT 160K 640 gpm 13620 psi ECD 10.6 - 10.8 ppg Torque onloff 12300/11000 ft/lbs Pumped 35 bbls 200+ FV sweeps @ 6856', 7350' and 7803' slight/moderate increase in cuttings back with sweeps back. Drill from 8065' to 9465'. TVD=6198', ADT=8.7 PU=220, SO=142, Rot=172, Torque=14000 up/13500 off. Rotary=170 rpm, WOB=10-25, Pump=3500 @ 185 spm (650 gpm) Drill from 9465' to 9998' (6552' tvd) ART =4.6 PUW 230K SOW 145K ROT WT 177K Torque onloff 15500/14000 ft/lbs @ 175 rpm 625 gpm 13790 psi ECD=10.6 - 10.9 ppg Pumped two 40 bbls 200+ FV sweeps(150 bbls apart) and circ clean for wiper trip - 630 gpm I 3780 psi 1175 rpm - flow check well, static. Backream from 9998' to 9139' - 625 gpm I 3740 - 3350 psi 1175 rpm- no problems. Flow check well, static. POOH on trip tank from 9139' to 7688', 5-15K over, hole took proper fill. Pump dry job - blow down lines. POOH on trip tank from 7688' to 4550' - 5-10K over - hole in good condition. Continue POOH to shoe @ 2950' Moitor well while servicing top drive RIH from 2950' to 3850'. Fill pipe and test Geopilot/MWD, Continue RIH to 9902' wI no problems. Fill pipe @ 6260' to 8630' and check Printed: 12/9/2003 3:06:17 PM .... .. ConocoPhillips Alaska Operations Summary Report GeopiloVMWD. Establish circulation @ 600 gpm, 3850 psi, 120-170 rpm, CBU and work pipe from 9902' to 9998' Drill from 9998' to 10666'. ADT=4.81, TVD= 6973'. PU=220, SO=150, Rot=185. Toque=13000 onl 15000 off, rotary=170 rpm, 10-25 WOB, 3300 psi @ 155 spm (550 gpm) Drill from 10666' to 11499' (7290' tvd) ADT = 5.49 PUW 240K SOW 150K ROT WT 185K Torque onloff 13000/11000 @ 170 rpm 600 gpm 13600 psi ECD 10.7 - 11.0 ppg 1.50 DRILL CIRC INTRM1 Pumped two 40 bbls 200+ FV sweeps - circ and cond mud 630 gpm 1 3880 psi 1170 rpm Slight increase in cuttings back with sweeps. 2.50 DRILL WIPR INTRM1 Flow check well, static - Backream from 11499' to 11043' - 600 gpm 1 3650 psi 1170 rpm - attempted to POOH on trip tank, pulled 30-40K over f/11020' to 11010'. Continue to Backream from 11043' to 10580'. Slowed rate to 500 gpm from 10761'. Backream from 10580' to 10384' - 500 gpm 1 2720 psi 1170 rpm POOH on trip tank from 10384' to 9950', hole took proper fill- flow check well, static. RIH to 11333', no problems - Precautionary wash from 11333' to 11499'. Pumped two 40 bbls sweeps 200+ FV - circ and cond mud 2 X BU 600 gpm 1 3890 psi 1170 rpm Slight increase in cuttings volume with sweeps back. Flow check well, static. POOH (pumping) from 11499' to 10311'. Lost partial returns @ 11141', spot LCM pill of 40 bbls/25 ppb. Initiallosses=160 bph POOH on trip tank from 10311' to 9580'. Established circulation @ 274 gpm, 1110 psi, 100 rpm. CBU @ 274 gpm, 1110 psi, FCP=2600 psi @ 500 gpm. Final losses 12 bph. Working pipe while circ. from 9580' to 9485' @ 150 rpm. POOH on trip tank from 9485' to 6534' Continue POOH on trip tank to shoe @ 3000'. Monitor flow, static. Resume POOH to BHA and lay down GhostReamers POOH with BHA (HW, JARS, and DCs) to MWD, flush BHA with water @ 100 spm = 400 psi Sperry-Sun download tool and clean, grease GeoPilot. Break-off bit, lay down MWD and GeoPilot, pony DCs Pull wear ring, set test plug, chang out UPRs to 7" and bails Rig up test joint and test 7" UPRs 250/500 Finish rig up on 7" csg. PJSM with crew and company man Make up shoe joint and RIH wit 7" casing to 4297' (Joint 101 of 269) Run casing to 5016' Establish circulation @ 4 BPM, 390 psi. Circulate volume equal to casing capacity. FCP=520 psi @ 6 BPM Run casing from 5016' to 8336'. Lost circulation at 8636'. Attempt to regain circulation. Attempt failed. Lay down 2 jts of casing from 8636' to 8654'. Attempt to circulate @ 2.5 BPM, 450 psi..unsuccessful Lay down casing in 2 jt increments and attempt to circulate. Unsuccessful. RIH while keeping casing full also keep annullus full with trip tank. P/U Legal Well Name: CD2-30 Common Well Name: CD2-30 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 . ! Sub' Date : From - To i Hours Code! Code. Phase 9/1/2003 00:45 - 04:00 3.25 DRILL WIPR INTRM1 04:00 - 05:00 1.00 DRILL CIRC INTRM1 05:00 - 12:00 7.00 DRILL DRLG INTRM1 12:00 - 20:00 8.00 DRILL DRLG INTRM1 20:00 - 21 :30 21 :30 - 00:00 9/212003 00:00 - 01:15 1.25 DRILL WIPR INTRM1 01:15 - 02:30 1.25 DRILL WIPR INTRM1 02:30 - 04:30 2.00 DRILL CIRC INTRM1 04:30 - 07:00 2.50 DRILL CIRC INTRM1 07:00 - 07:45 0.75 DRILL CIRC INTRM1 07:45 - 09:30 1.75 DRILL CIRC INTRM1 09:30 - 12:00 2.50 DRILL TRIP INTRM1 12:00 - 14:30 2.50 DRILL PULD INTRM1 14:30 - 15:30 1.00 DRILL PULD INTRM1 15:30 - 16:30 1.00 DRILL PULD INTRM1 16:30 - 17:30 1.00 DRILL PULD INTRM1 17:30 - 18:30 1.00 CASE NUND INTRM1 18:30 - 19:00 0.50 CASE NUND INTRM1 19:00 - 19:30 0.50 CASE NUND INTRM1 19:30 - 00:00 4.50 CASE RUNC INTRM1 9/3/2003 00:00 - 00:30 0.50 CASE RUNC INTRM1 00:30 - 01 :00 0.50 CASE CIRC INTRM1 01 :00 - 04:15 3.25 CASE RUNC INTRM1 04:15 - 04:45 0.50 CASE CIRC INTRM1 04:45 - 06:00 1.25 CASE CIRC INTRM1 06:00 - 07:45 1.75 CASE CIRC INTRM1 07:45 - 11 :00 3.25 CASE RUNC INTRM1 Page 4 of 9 Start: 8/25/2003 Rig Release: 10/30/2003 Rig Number: Spud Date: 8/26/2003 End: 10/30/2003 Group: Description of Operations .------ ... Printed: 12/9/2003 3:06:17 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/3/2003 9/4/2003 10/21/2003 .... .. Page 5 of 9 ConocoPhillips Alaska Operations Summary Report CD2-30 CD2-30 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub From - To Hours Code, Code Phase 07:45 - 11 :00 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 14:00 14:00 - 15:00 15:00 -16:30 16:30 - 19:00 19:00 - 20:00 20:00 - 20:30 20:30 - 21 :30 21 :30 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 05:00 05:00 - 05:45 05:45 - 06:00 06:00 - 06:15 06:15 - 07:30 07:30 - 09:30 09:30 - 11 :00 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 14:30 04:30 - 12:00 12:00 - 16:30 16:30 - 17:00 17:00 -19:00 19:00 - 19:30 19:30 - 20:00 20:00 - 00:00 3.25 CASE RUNC INTRM1 0.50 CASE RUNC INTRM1 0.50 CASE RUNC INTRM1 2.00 CASE RUNC INTRM1 1.00 CASE RUNC INTRM1 1.50 CASE CIRC INTRM1 2.50 CEMENT PUMP INTRM1 1.00 CASE MIT 0.50 CASE 1.00 CASE 2.50 MOVE 1.50 MOVE 1.50 MOVE 2.00 MOVE 0.75 MOVE 0.25 MOVE 0.25 MOVE 1.25 MOVE 2.00 MOVE 1.50 MOVE 0.50 MOVE 0.50 MOVE 2.50 MOVE 7.50 MOVE 4.50 MOVE INTRM1 RURD INTRM1 NUND INTRM1 MOVE SUSPEN MOVE SUSPEN MOVE SUSPEN MOVE SUSPEN MOVE SUSPEN MOVE SUSPEN MOVE SUSPEN MOVE SUSPEN MOVE SUSPEN MOVE SUSPEN MOVE SUSPEN MOVE SUSPEN MOVE SUSPEN MOVE MOVE RURD MOVE 0.50 WELCTL NUND 2.00 WELCTL NUND 0.50 WELCTL NUND 0.50 WELCTL BOPE 4.00 WELCTL BOPE DECaMP INTRM1 DECaMP INTRM1 INTRM1 Start: 8/25/2003 Rig Release: 10/30/2003 Rig Number: Spud Date: 8/26/2003 End: 10/30/2003 Group: : Description of Operations landing jt RIH to 11,480' Work casing down to 11,484' with PUW=350K SOW=150K. Need l' to land casing. Lay down Franks fill-up tool, RU cement head. Lost 245 bbl mud while running casing Unable to land casing (1' short). Work casing and circ at 2.5 BPM, 510 psi. with 100% losses for 102 bbls. Rig down casing head, POOH and UD landing jt. and UD jt. # 269 and exchange for shorter jt, RIH and P/U landing jt. S/O and land casing @ 11,481' Work casing and circulate @ 2.1 BPM, 520 psi with no returns. PJSM, Pump 40 bbl LCM pill @ 5 BPM, 710 psi, Dowell pump 5 bbl Mudpush XL Spacer, drop bottom plug, pump 34 bbls15.8# tail slurry cmt, drop top plug, pump 20 bbl water, displace with 416 bbls 8.8 ppg brine, bump plug at 970 psi pump up to 1500 psi, bleed pressure, check float OK Pressure test casing to 3500 psi and hold for 30 minutes. Good test presure steady. Rig down lines, UD casing elevators and landing jt. Pull bushing, set pack-off and test to 5K psi, set bushing change out bails. RIH with 55 stands DP to 5251'. POOH UD drillpipe (Balance derrick and make sure not overloaded for rig move) UD drill pipe to 1813' PJSM, cut 60' of drilling line, C/O rams to 3-1/2"X6", service rig. UD MH, RIU Dowell, freeze protect 7" casing with 60 bbls diesel @ 2.1 BPM, 150 psi (reversing down annulus taking returns up DP) POOH with 19 stands DP and stand back in derrick. Top of 7" casing with diesel. Pull wear ring (Dowell test annulus, injecting brine) P/U hanger, land jt, install two way check, land hanger. Unable to land, shear junk ring as hung up in stack. Pull tbg hanger free, install new shear pins, C/O TDXO while working on hanger. Attempt to land hanger unsuccessful. Push on hanger 6K with blocks, shear junk ring, pull hanger, FMC work on hanger. RIH with rebuilt hanger (sheared out). UD hanger, land jt. Install thin wall wear ring N/D BOPs, pull thin wall wear ring by hand (profile to tall for wellhead to fit), P/U landing jt. B, install tubing hanger and two way check, N/U tree and test to 5K psi. FMC test hanger seals to 5K psi OK, secure well. Rig release at 14:30 hrs on (9/4/2003) Move rig from CD2-06 to CD2-30. Spot rig, pits, motors. Make planned rig modifications. Hook up and inspect all service lines, repair hydraulic line. Take on Flo-Pro drilling fluid. RIG ACCEPTANCE: 1630 hrs, October 21,2003 ND tree. NU BOPE, set mousehole. Check wellhead pressure, pull BPV and tubing hanger. Set test plug and RU to test BOPE. Test BOPE: Pipe & Blind rams, choke line, kill line, manifold and Printed: 12/9/2003 3:06:17 PM .... .. Page 6 of 9 ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-30 Common Well Name: CD2-30 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 I Sub Date From - To Hours Code.. Code Phase 10/21/2003 20:00 - 00:00 4.00 WELCTL BOPE INTRM1 10/22/2003 00:00 - 00:30 0.50 WELCTL BOPE INTRM1 00:30 - 00:45 0.25 WELCTL BOPE INTRM1 00:45 - 02:15 1.50 DRILL PULD INTRM1 02:15 - 04:00 1.75 DRILL TRIP INTRM1 04:00 - 04:45 0.75 DRILL CIRC INTRM1 04:45 - 09:30 4.75 DRILL TRIP INTRM1 09:30 - 11 :30 2.00 DRILL TRIP INTRM1 11 :30 - 12:00 0.50 RIGMNT RSRV INTRM1 12:00 - 14:30 2.50 DRILL CIRC INTRM1 14:30 -16:00 1.50 DRILL OTHR INTRM1 16:00 - 18:30 2.50 DRILL DRLG INTRM1 18:30 - 21 :00 2.50 DRILL CIRC INTRM1 21 :00 - 22:00 1.00 DRILL FIT INTRM1 22:00 - 00:00 2.00 DRILL DRLH PROD 10/23/2003 00:00 - 07:45 7.75 DRILL DRLH PROD 07:45 - 08:45 1.00 WAlTON OTHR PROD 08:45 - 09:45 1.00 WAlTON OTHR PROD 09:45 - 15:00 5.25 WAlTON OTHR PROD 15:00 - 15:30 0.50 DRILL WIPR PROD 15:30 - 18:30 3.00 DRILL DRLH PROD Start: 8/25/2003 Rig Release: 10/30/2003 Rig Number: Spud Date: 8/26/2003 End: 10/30/2003 Group: . . . . ... .... bêscriptionof Operations . . .. ... surface safety vales to 250 / 5000 psi - Annular preventer 250 / 3500 psi. AOGCC (Lou Grimaldi) waived witnessing tests. Finish testing BOPE, pull test plug. Set wear ring, blow down choke and kill lines. PU BHA, install MWD probe, orient, upload MWD, RIH with BHA. RIH picking up DP from the pipe shed, taking flowback of diesel to the outside open top tank. PJSM. Close IBOP and pressure up surface equipment to 3,500 psi and check for leaks - okay. Fill DP with brine. Close annular BOP. Pump 8.8 ppg brine at 200 gpm, 890 psi and surface test MWD, while circulating diesel to the outside tank. Move pipe while pumping. Continue RIH picking up DP from the pipe shed, taking flowback to the outside tiger tank. Fill DP at 6,000' and 8,850' with 8.8 brine. Continue RI H and tag up on Float collar at 11 ,384'. Service TD. PJSM. Close annular preventer, displace diesel with 8.8 ppg brine at 4 BPM and 1,030 psi, to the outside tiger tank. Blow down and RD surface lines from the stack. RU and test casing to 3,500 psi for 10 minutes - okay. Drill out float equipment and shoe track, plus 20' of new hole (20' past rat hole). PJSM. Displace brine to 8.8 ppg Flo-Pro drilling fluid (re-conditioned), at 200 GPM and 1,300 psi. Flow check - well bore static. RU surface equipment. Perform FIT to 12.5 ppg EMW. RD surface equipment. Drill 6 1/8" horizontal section f/ 11,519' to 11,557' MD - 7,298' TVD ADT - 1.0 hrs. = ART - 0.2 hrs. AST - 0.8 hrs. WOB 4/6 k RPM 0/50 GPM 200 @ 1,550 psi String wt. PU 215 SO 160 Rot 185 Torque on/off btm - 10,000/9,500 ft/lbs. Average ECD 9.9 ppg Motor: 1.22 deg, 0.77 revs/gal Bit to DIR - 34.33' Bit to RES - 48.12' BittoGR -55.18' Bit to PWD - 68.38' Drill 6 1/8" horizontal section f/ 11,557' to 11,936' MD - 7,308' TVD ADT - 4.7 hrs. = ART - 1.5 hrs. AST - 3.2 hrs. WOB 4/15 k RPM 0/80 GPM 222 @ 1,980 psi String wt. PU 215 SO 150 Rot 180 Torque on/off btm - 13,000/ 12,000 ft/lbs. Average ECD 9.9 ppg Lost Hi-Line power. PU and circulate off bottom with emergency generator. Wait on Hi-line power. POOH-pump out from 11,936 to 11,433' at 155 GPM, 1,200 psi and 50 rpm. Secure DP. Monitor well with the Trip tank. De-ice the derrick. Continue waiting on Hi-line power. PJSM. RIH to 11,900', screw in TD, wash and ream to 11,936'. Drill 6 1/8" horizontal section f/ 11,936' to 12,056' MD - 7,309' TVD ADT - 2.4 hrs. = ART - 1.4 hrs. AST - 1.0 hrs. Printed: 12/9/2003 3:06:17 PM ~ .. Page 7 of 9 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-30 CD2-30 ROT - DRILLING doyon1 @ppco.com Doyon 19 Date ; From - To Hours Code Sub: Phase .--......-----.-. . .... ---~?~~j_.---"...... 10/23/2003 15:30 - 18:30 3.00 DRILL DRLH PROD 18:30 - 19:00 0.50 WAlTON OTHR PROD 19:00 - 20:30 20:30 - 00:00 1.50 WAlTON OTHR PROD 3.50 WAlTON OTHR PROD 10/24/2003 00:00 - 02:00 2.00 WAlTON OTHR PROD 02:00 - 05:30 3.50 RIGMNT RGRP PROD 05:30 - 06:00 0.50 DRILL REAM PROD 06:00 - 12:00 6.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD Start: 8/25/2003 Rig Release: 10/30/2003 Rig Number: Spud Date: 8/26/2003 End: 10/30/2003 Group: Description of Operations - ---..---... -..-.-.-..-... WOB 6/8 k RPM 50 GPM 219 @ 2,000 psi String wt. PU 215 SO 150 Rot 180 Torque on/off btm -10,500 110,000 ftllbs. Average ECD 9.9 ppg Lost Hi-Line power. PU and circulate off bottom with emergency generator. Wait on Hi-line power. POOH-pump out from 12,056' to 11,434'. Monitor well - static. Secure DP. Monitor well with the Trip tank. Continue waiting on Hi-line power. Change out 4" standpipe valve, c/o steel line to Top Drive service loop. Monitor well with the Trip tank. Continue waiting on Hi-line and changing out 4" standpipe valve, clo steel support cable to service loop. Flush standpipe, test mudlines to 3,500 psi - okay. Finish changing out standpipe valve and cable to service loop. Flush standpipe, test mudlines to 3,500 psi - okay. NOTE: RIG is on RIG REPAIR RIH to 12,011', establish circulation at 74 GPM, 830 psi, 30 RPM. Increase to 222 GPM, 1,830 psi and 80 RPM and ream to bottom. Drill 6 1/8" horizontal section fl 12,056' to 12,420' MD - 7,295' TVD ADT - 4.0 hrs. = ART - 3.4 hrs. AST" 0.6 hrs. WOB 6/15k RPMO/80 GPM222 @ 2,100 psi String wt. PU 210 SO 150 Rot 180 Torque onloff btm -12,000 110,500 ftIIbs. Average ECD 10.3 ppg Drill 6 1/8" horizontal section fl 12,420' to 13,057' MD" 7,295' TVD ADT - 6.8 hrs. = ART - 0.7 hrs. AST - 6.1 hrs. WOB 5/9 k RPM 50/80 GPM 222 @ 2,200 psi String wt. PU 215 SO 148 Rot 180 Torque onloff btm -12,000 110,500 ftllbs. Average ECD 10.4 ppg 10/25/2003 00:00 - 12:00 12.00 DRILL DRLH PROD Drill 6 1/8" horizontal section fl 13,057' to 13,866' MD - 7,291' TVD ADT - 8.4 hrs. = ART - 6.2 hrs. AST - 2.2 hrs. WOB 5/8 k RPM 0/50 GPM 229 @ 2,250 psi String wt. PU 215 SO 145 Rot 185 Torque onloff btm -12,000 111,000 ftllbs. Average ECD 10.5 ppg 12:00 - 00:00 12.00 DRILL DRLH PROD Drill 6 1/8" horizontal section fl 13,866' to 14,489' MD - 7,287' TVD ADT - 6.9 hrs. = ART - 4.0 hrs. AST - 2.9 hrs. WOB 5/10 k RPM 50/60 GPM 229 @ 2,320 psi String wt. PU 220 SO 145 Rot 180 Torque onloff btm -12,000 111,000 ftIIbs. Average ECD 10.6 ppg 10/26/2003 00:00 - 05:30 5.50 DRILL DRLH PROD Drill from 14489' to 14986' (7280' tvd) ART=4.7 AST=O NOTE: CHANGED TO DAYLIGHT STANDARD TIME @ 0200 hrs Printed: 12/9/2003 3:06:17 PM ~ - 8 of 9 ConocoPhillips Alask~¡'i¡'m";·.. Operations SummarYl11r@port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From -'Tö CD2-30 CD2-30 ROT - DRILLING doyon1 @ppco.com Doyon 19 . Hours I Code ¿;ouJe Phase 10/26/2003 00:00 - 05:30 5.50 DRILL DRLH PROD 05:30 - 09:30 4.00 WAlTON OTHR PROD 09:30 - 12:00 2.50 WAlTON OTHR PROD 12:00 - 13:30 1.50 WAlTON OTHR PROD 13:30 - 14:00 0.50 DRILL TRIP PROD 14:00 - 15:00 1.00 DRILL DRLH PROD 15:00 - 15:45 0.75 WAlTON OTHR PROD 15:45 - 00:00 8.25 WAlTON OTHR PROD 10/27/2003 00:00 - 07:30 7.50 WAlTON OTHR PROD 07:30 - 10:30 3.00 WAlTON OTHR PROD 10:30 - 18:00 7.50 WAlTON OTHR PROD 18:00 - 19:00 1.00 WAlTON OTHR PROD 19:00 - 19:30 0.50 DRILL REAM PROD 19:30 - 23:00 3.50 DRILL DRLH PROD 23:00 - 23:30 0.50 WAlTON OTHR PROD 23:30 - 00:00 0.50 WAlTON OTHR PROD 10/28/2003 00:00 - 05:00 5.00 WAlTON EOIP PROD 05:00 - 05:30 0.50 WAlTON EOIP PROD 05:30 - 06:00 0.50 WAlTON EOIP PROD 06:00 - 13:30 7.50 DRILL DRLH PROD Start: 8/25/2003 Rig Release: 10/30/2003 Rig Number: Spud Date: 8/26/2003 End: 10/30/2003 Group: Description of Operations WOB 5/8 K RPM 50/60 229 gpm @ 2300 psi Torque on/off 11,500/ 11,000 ft-Ibs PUW 215K SOW 140K ROT 178K Average ECD 10.6 ppg CBU, monitor well, static. Pump out slowly from 14489' to 13630' - 180 gpm / 1 ,340 psi / 50 rpm - no problems RIH-wash and ream at 175 GPM, 1,330 psi, 40 RPM, from 13,630'-14,202'. Continue RIH-wash and ream at 175 GPM, 1,330 psi, 40 RPM, from 14,202'-14,584'. RIH to 14,966'. Establish drilling parameters and wash and ream to bottom at 14,986'. Drill form 14,986'-15,077' (7,277' TVD) ART=0.8, AST=0.2, ADT=1.0 WOB 5/10 K RPM 60/80 225 gpm @ 2,400 psi Torque on/off 12,000/ 11,000 ft-Ibs PUW 215K SOW 143K ROT 177K Average ECD 10.6 ppg LOST HI-LINE POWER Put rig engines #1 and #4 online and establish operating parameters. Pump and backream out at one stand/hr, at 175 GPM, 1,540 psi, 40 RPM. Continue to wait on Hi-Line power. Pump out from 14400' to 13730', 175 gpm / 1480 psi / 50 rpm Set back 1 std / hr. PUW 225K SOW 150K ROTWT 175K Torgue off btm / 11,000 ft-Ib Waiting on high line power. RIH f/ 13730' to 14584' @ 20 min / std, no problems Pump out from 14584' - 13,900', set back 1 std / hr, 175 GPM, 1,540 psi, 40 RPM, TO= 10,200 ft-Ib. RIH w/o pumping, to 14,961', establish drilling parameters. Ream last stand to bottom at 15,077', 80 RPM, 230 GPM, 2,000 psi, TO=11,500 ft-Ib. Drill 6 1/8" horizontal section f/ 15,077' to 15,269' MD - 7,277' TVD ADT - 2.2 hrs. = ART - 0.4 hrs. AST - 1.8 hrs. WOB 7/10 k RPM 40/90 GPM 225 @ 2,400 psi String wt. PU 220 SO 140 Rot 175 Torque on/off btm -12,000/10,800 ft-Ibs. Average ECD 10.9 ppg LOST HI-LINE POWER Put rig engines #1 and #4 on line. PU off bottom. CBU at 225 GPM, 2,020 psi, 50 RPM. Monitor well. Continue circulating. Rack back one stand every hour from 15,250' to 14738'. Circulating @ 170 gpm, 1430 psi & 50 rpm. RIH from 14738' to 15258'. Back on highline @ 05:30 hrs Wash and ream from 15258' to 15269'. @ 230 gpm, 1990 psi 100 rpm Drill from 15260' to 15700' TVD=7268' ART=4.8, AST=.5, ADT=5.3, PU=220k, SO=140k, Rot=175k, Torque=12000 on/ 11000 off. Rotary=50-80 rpm, WOB=7-10, Pump = 2430 psi @ 230 gpm (65 spm). Hole started taking fluid @ 15,670' initial losses 60 bph / average 40 bph. Printed: 12/9/2003 3:06:17 PM ~ .. ConocoPhillips Alaska Operations Summary Report Page 9 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-30 CD2-30 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 8/25/2003 Rig Release: 10/30/2003 Rig Number: Spud Date: 8/26/2003 End: 10/30/2003 Group: Date : From - TCl Hours Code ,'Sub:": Phase COdEr' 10/28/2003 13:30 - 16:00 2.50 DRILL CIRC PROD 16:00 - 19:30 3.50 DRILL CIRC PROD ." '0·· . "»^. Description of Operations:;"'::: 19:30 - 22:30 3.00 DRILL TRIP PROD Pump 40 bbl hi-vis pill and circulate until clean. 2180 psi @ 64 spm 80 rpm, 11,200 ft-Ibs torque. Flush both pumps wI 5 bbl brine and pump 40 bbl hi-vis spacer and 500 bbl 8.8 ppg brine. Pump 40 bbl hi-vis pill and displaced into open hole wI 180 bbl brine All displacement @ 5 bpm ICP=1880 psi. FCP=1200 psi Flow check. Hole appears to be taking 2-3 bph when static. POOH from 15,700' to 11,433' on trip tank wI no problems Cut 60' of drilling line and adjusted drawworks brakes Service top drive and drawworks. Losing brine @ 18 bph while servicing rig and cutting drilling line 22:30 - 23:30 23:30 - 00:00 1.00 RIGMNT RSRV PROD 0.50 RIGMNT RSRV PROD .. Total losses to well @ midnight = 298 bbls of 8.8 ppg FloPro mud and 90 bbls of 8.8 ppg brine. 10/29/2003 00:00 - 05: 15 5.25 DRILL TRIP PROD Pump dry job and UD 243 jts 4" d.p. from 11433' to 3700' 05:15 - 07:00 1.75 DRILL TRIP PROD POOH and stand back 35 stands d.p. and 2 stands HWDP 07:00 - 08:30 1.50 DRILL PULD PROD UD NMDC"s and flush BHA wI 10 gal. concor 404 wI 40 bbl brine. Down load MWD and UD motor and MWD. 08:30 - 09:30 1.00 CMPL TN OTHR PROD Pull wearring and R/U tongs. Hold safety meeting 09:30 - 17:00 7.50 CMPL TN RUNT PROD P/U and RIH wI 249 jts 4-1/2" 12.6#, L-80 IBTN tubing. 17:00 - 17:30 0.50 CMPL TN SOHO PROD M/U tubing hanger and landing jt. "A". Land tubing wI tubing tail @ 10938.23'. Run in lock down screws 17:30 - 19:00 1.50 CMPL TN NUND PROD UD landing jt "A" and set 2 way check. M/U landing jt. "B" and test 2-way check to 5000 psi-OK. 19:00 - 20:30 1.50 CMPL TN NUND PROD NID BOPE and N/U tree and test to 5000 psi. Change dies and saver sub in top drive. 20:30 - 21 :00 0.50 CMPL TN NUND PROD R/U lubricater and pull 2-way check. R/U lines and u-tube manifold. 21 :00 - 21 :30 0.50 CMPL TN SFTY PROD Hold pre-job safety meeting prior to displacing well. Check all lines and valves. Test lines to 4000 psi wI cement unit 21 :30 - 00:00 2.50 CMPL TN FRZP PROD Displace well wI 160 bbl 9.2 ppg brine wI rig pump @ 3 bpm (ICP=190 psi, FCP=120 psi). Pump 215 bbl diesel wI cement unit @ 3 bpm. Hole took 28 bbl/hr during displacement. Lost 336 bbl brine to formation during day. .. Chuck Sheve approved BOP Test extension to run Completion. 10/30/2003 00:00 - 00:15 0.25 CMPL TN FRZP CMPL TN Finish displacing diesel for freeze protection. 00:15 - 00:45 0.50 CMPL TN PCKR CMPL TN RU and drop packer setting ball and rod. 00:45 - 02:15 1.50 CMPL TN DEQT CMPL TN Set packer and test tubing to 3500 psi for 30 min. - RU and test 7" X 4 1/2" annulus to 3500 psi for 30 min. 02:15 - 02:45 0.50 CMPL TN RURD CMPL TN Bleed down and clear lines - RD hard lines and kill manifold. 02:45 - 04:00 1.25 CMPL TN OTHR CMPL TN RU FMC lubricator and install BPV - secure wellhead. Released rig to CD2-27 @ 0400 hrs. .. Total losses to Production hole = 298 bbls of 8.8 ppg FloPro mud I 426 bbls of 8.8 ppg KCL Brine. Printed: 12/9/2003 3:06:17 PM . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-30 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 15,700.00' MD . (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~·~~fY\~ 9-03- \35 26-Nov-03 RECEIVED DEC 082003 Maska on & Gas Cons. Commie8ion Andlomge Halliburton Sperry-Sun Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-3D . Job No. AKZZ0002601675, Surveyed: 28 October, 2003 Survey Report 25 November, 2003 Your Ref: API 501032046500 Surface Coordinates: 5974492.75 N, '371712.00 E (70020'18.7632" N, 151002'27.5482" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 974492.75 N, 128288.00 W (Grid) Surface Coordinates relative to Structure: 49.74 N, 6.34 W (True) Kelly Bushing Elevation: 52. 70ft above Mean Sea Level Kelly Bushing Elevation: 52. 70ft above Project V Reference Kelly Bushing Elevation: 52. 70ft above Structure 5""-=:1 ·.....y-5UI"'1 DFUL.L.ING SElPlvu::ræs A Halliburton Company Survey Ref: svy289 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - C02-30 Your Ref: API 501032046500 Job No. AKZZ0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -52.70 0.00 O.OON O.OOE 5974492.75 N 371712.00 E 0.00 Tolerable Gyro 83.00 0.250 116.000 30.30 83.00 0.08S 0.16 E 5974492.67 N 371712.16 E 0.301 -0.17 178.00 0.750 250.000 125.30 178.00 0.38S 0.24W 5974492.37 N 371711.76 E 0.991 0.22 . 266.00 3.250 281.000 213.24 265.94 0.108 3.23W 5974492.70 N 371708.77 E 2.995 3.22 AK-6 BP _IFR-AK 302.94 3.990 270.860 250.10 302.80 0.12 N 5.54W 5974492,96 N 371706.46 E 2.642 5.54 393.43 7.340 268.910 340.14 392.84 0.05N 14.47 W 5974493.05 N 371697.53 E 3.708 14.46 484,03 9.780 252.990 429.74 482.44 2.31 S 27,62 W 5974490.91 N 371684.35 E 3.730 27.48 572.86 11 .370 252.820 517.05 569.75 7.108 43.20 W 5974486.39 N 371668.69 E 1.790 42.83 662.36 11.550 253.760 604.77 657.47 12.21 8 60.23 W 5974481.57 N 371651.57 E 0.290 59.61 752.24 12.990 251.670 692.60 745.30 17.91 S 78.46 W 5974476.19 N 371633.25 E 1.676 77.56 842.09 13.960 243.980 779.98 832.68 25.84 S 97.79 W 5974468.59 N 371613.79 E 2,265 96.50 932.63 16.110 237.400 867.42 920.12 37.40 S 118.19 W 5974457.38 N 371593.19 E 3.028 116.35 1027.34 20.180 233.630 957.40 1010.10 54.17 S 142.42 W 5974441.02 N 371568.67 E 4.470 139.80 1123.14 23.620 234.810 1046.28 1098.98 75.04 8 171.42 W 5974420.65 N 371539,32 E 3.620 167.81 1217.65 27.170 235,080 1131.64 1184.34 98.31 8 204.60 W 5974397.95 N 371505.75 E 3.758 199.89 1313.53 30.210 236.570 1215.74 1268.44 124.148 242.69 W 5974372.78 N 371467.22 E 3.257 236.76 1407.42 33.240 239.260 1295.60 1348.30 150.31 S 284.53 W 5974347.33 N 371424.94 E 3.561 277.36 1503.00 36.410 239.270 1374.05 1426.75 178.20 8 331.44 W 5974320.24 N 371377.56 E 3.317 322.95 1598.86 39.500 238.720 1449.63 1502.33 208.58 8 381.96 W 5974290.74 N 371326.52 E 3,243 372.03 1694.47 42.450 237.200 1521.81 1574.51 241.858 435.08 W 5974258.38 N 371272.84 E 3.257 423.57 . 1788.31 45.630 235.750 1589.26 1641.96 277.898 489.44 W 5974223.27 N 371217.87 E 3.555 476.23 1882.71 48.090 234.030 1653,80 1706.50 317.528 545.77 W 5974184.61 N 371160.88 E 2.925 530.69 1978.16 49.220 230.360 1716.87 1769.57 361.45 8 602.36 W 5974141.66 N 371103.55 E 3.120 585.21 2072.82 49.340 228.380 1778.62 1831.32 408.16 S 656.80 W 5974095.88 N 371048.31 E 1.590 637.46 2167.87 49.970 229.400 1840.16 1892.86 455.798 711.38 W 5974049.20 N 370992.92 E 1.053 689.81 2264.16 51.710 229.380 1900.96 1953.66 504.39 8 768.06 W 5974001.58 N 370935.42 E 1.807 744.20 2359.08 54.400 228.590 1958.01 2010.71 554.178 825.29 W 5973952.78 N 370877.35 E 2.911 799.09 2454.31 54.890 229.420 2013.11 2065.81 605.128 883,91 W 5973902.84 N 370817,87 E 0.878 855.33 2549.39 55.690 229.070 2067.25 2119.95 656,158 943.12 W 5973852.83 N 370757.80 E 0.894 912.14 2644.71 55.330 228.000 2121.23 2173.93 708.17 S 1001.99 W 5973801.83 N 370698.04 E 0.999 968.57 2740.18 53,790 227.980 2176.59 2229.29 760.22 S 1059.78 W 5973750.77 N 370639.37 E 1.613 1023.92 2835.07 54.650 227.730 2232.07 2284.77 811,88 S 1116.86 W 5973700.10 N 370581.41 E 0.931 1078.58 2928.87 55.410 229.760 2285.83 2338.53 862.55 8 1174.64W 5973650.42 N 370522.77 E 1.950 1133.99 2972.26 54.270 230.480 2310.82 2363.52 885.30 8 1201.86 W 5973628.14 N 370495.17 E 2.957 1160.14 3056.00 54.180 230.660 2359.77 2412.47 928.45 8 1254.34 W 5973585.90 N 370441.96 E 0.205 1210,59 25 November, 2003 - 16:31 Page2of7 Orll/Quest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - C02-30 Your Ref: API 501032046500 Job No. AKZZ0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) 3151.22 54.060 230.940 2415.58 2468.28 977.21 S 1314,13 W 5973538.16 N 370381.35 E 0.270 1268.08 3246.63 54.120 230.870 2471.54 2524.24 1025.94 S 1374.10 W 5973490.47 N 370320.55 E 0.087 1325.77 3341.96 54.030 231.710 2527.47 2580.17 1074.22 S 1434.34 W 5973443.23 N 370259.49 E 0.720 1383.74 3437.71 53.580 231.190 2584.02 2636.72 1122.37 S 1494.77 W 5973396.11 N 370198.25 E 0.643 1441.90 . 3533.20 53.500 232.550 2640.76 2693.46 1169.79 S 1555.18 W 5973349.74 N 370137.03 E 1.149 1500.08 3628.66 53.280 232.150 2697.69 2750.39 1216.60 S 1615.85 W 5973303.98 N 370075.57 E 0.408 1558.55 3724.07 53.020 231.650 2754.91 2807.61 1263.71 S 1675.93 W 5973257.90 N 370014.69 E 0.500 1616.41 3819.50 52.790 231.350 2812.47 2865.17 1311.09 S 1735.50 W 5973211.54 N 369954.32 E 0.348 1673.75 3915.12 52.660 231.540 2870.38 2923.08 1358.51 S 1795.00 W 5973165.14 N 369894.02 E 0.209 1731.03 4010.15 52.330 232.580 2928.24 2980.94 1404.86 S 1854.45 W 5973119.82 N 369833.78 E 0.935 1788.30 4105.48 51.960 232.510 2986.74 3039.44 1450.64 S 1914.21 W 5973075.07 N 369773.26 E 0.392 1845.89 4200.96 51.570 232.420 3045.83 3098.53 1496.33 S 1973.68 W 5973030.41 N 369713.01 E 0.415 1903.21 4296.60 51 .490 232.590 3105.33 3158.03 1541.91 S 2033.09 W 5972985.85 N 369652.83 E 0.162 1960.48 4392.71 51.180 232.960 3165.38 3218.08 1587.31 S 2092.84 W 5972941.48 N 369592.31 E 0.441 2018.10 4488.26 51.010 233.820 3225.39 3278.09 1631.65 S 2152.53 W 5972898.17 N 369531.87 E 0.723 2075.69 4583.53 51.090 233.340 3285.28 3337.98 1675.64 S 2212.15 W 5972855.20 N 369471.51 E 0.401 2133.24 4679.21 51.240 234.350 3345.28 3397.98 1719.61 S 2272.32 W 5972812.27 N 369410.59 E 0.837 2191.34 4774.64 51,160 234.350 3405.07 3457.77 1762.95 S 2332.76 W 5972769.96 N 369349.42 E 0.084 2249.73 4869.40 52.200 235.880 3463.83 3516.53 1805.47 S 2393.74 W 5972728.50 N 369287.72 E 1.676 2308.71 4964.94 52.820 235.210 3521.98 3574.68 1848.35 S 2456.25 W 5972686.69 N 369224.49 E 0.855 2369,19 5060.19 53.540 234.280 3579.06 3631.76 1892.37 S 2518.51 W 5972643.75 N 369161.48 E 1.087 2429.37 . 5155.94 53.730 234.860 3635.84 3688.54 1937,07 S 2581.34 W 5972600.13 N 369097.90 E 0.527 2490.09 5251.86 53.810 235.160 3692.53 3745.23 1981.43 S 2644.73 W 5972556.85 N 369033.76 E 0.266 2551.39 5346.99 54.550 234.640 3748.20 3800.90 2025.79 S 2707.83 W 5972513.59 N 368969.90 E 0.895 2612.40 5442.54 55.270 233.630 3803.13 3855.83 2071.60 S 2771.19 W 5972468.87 N 368905.77 E 1.147 2673.60 5538.06 55.770 232.560 3857.21 3909.91 2118.88 S 2834.15 W 5972422.67 N 368842.01 E 1.061 2734.33 5633.90 56.880 232.180 3910.35 3963.05 2167.58 S 2897.31 W 5972375.06 N 368778.03 E 1.204 2795.20 5729.22 57.550 230.550 3961.96 4014.66 2217.61 S 2959.90 W 5972326.10 N 368714.59 E 1.600 2855.44 5824.83 56.220 228.440 4014.20 4066.90 2269.61 S 3020.79 W 5972275.15 N 368652.82 E 2.313 2913.89 5920.34 55.930 228.760 4067.51 4120.21 2322.02 S 3080.24 W 5972223.77 N 368592.48 E 0.412 2970.88 6015.77 55.780 227.760 4121.07 4173.77 2374.60 S 3139.17 W 5972172.21 N 368532.66 E 0.881 3027.34 6111.22 55.450 226,590 4174.98 4227.68 2428.14 S 3196.94 W 5972119.66 N 368473.98 E 1.069 3082.61 6206.69 55.770 226.770 4228.90 4281.60 2482.19 S 3254.26 W 5972066.60 N 368415.75 E 0.370 3137.40 6302.38 55.870 226.000 4282.66 4335.36 2536.80 S 3311.57 W 5972012.98 N 368357.51 E 0.674 3192.15 6398.02 55.640 225.610 4336.48 4389.18 2591.91 S 3368.26 W 5971958.85 N 368299.89 E 0.414 3246.26 25 November, 2003 - 16:31 Page30f7 OrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Alpine CO-2· C02-30 Your Ref: API 501032046500 Job No. AKZZ0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6493.28 55.540 226.140 4390.31 4443.01 2646.63 S 3424.67 W 5971905.10 N 368242.55 E 0.471 3300.11 6588.73 55.510 226.000 4444.34 4497.04 2701.22 S 3481.34 W 5971851.49 N 368184.95 E 0.125 3354.22 6684.17 55.480 225.210 4498.41 4551,11 2756.24 S 3537.54 W 5971797.44 N 368127.82 E 0.683 3407.85 6779.59 55.490 225.760 4552.47 4605.17 2811.36 S 3593.60 W 5971743.28 N 368070.83 E 0.475 3461.33 . 6875.00 55.470 225.550 4606.54 4659.24 2866.31 S 3649.82 W 5971689.30 N 368013.68 E 0.183 3514.98 6970.26 55.340 225.630 4660.63 4713.33 2921.19 S 3705.84 W 5971635.39 N 367956.73 E 0.153 3568.43 7065.89 54.810 225.110 4715.38 4768.08 2976.27 S 3761.64 W 5971581.27 N 367899.99 E 0.711 3621.65 7161.22 54.570 225.180 4770.48 4823.18 3031.14 S 3816.78 W 5971527.36 N 367843.92 E 0.259 3674.23 7256.66 54.260 225.020 4826.01 4878.71 3085.92 S 3871. 76 W 5971473.52 N 367788.01 E 0.352 3726.65 7352.17 53.960 224.890 4882.01 4934.71 3140.68 S 3926.43 W 5971419.71 N 367732.41 E 0.333 3778.76 7447.61 53.580 225.410 4938.41 4991.11 3194,98 S 3981.01 W 5971366.35 N 367676.91 E 0.593 3830.80 7543.14 53.120 225.680 4995.44 5048.14 3248.65 S 4035.72 W 5971313.62 N 367621.29 E 0.532 3883.00 7638.67 52.670 226.940 5053.07 5105.77 3301.28 S 4090.81 W 5971261.94 N 367565.31 E 1.153 3935.62 7734.11 53.670 228.350 5110.28 5162.98 3352.74 S 4147.26 W 5971211.46 N 367507.99 E 1.580 3989.67 7829.53 54.560 229.020 5166.21 5218.91 3403.78 S 4205.33 W 5971161.42 N 367449.06 E 1.093 4045.34 7924.94 54.950 228.910 5221.27 5273.97 3454.93 S 4264.10 W 5971111.28 N 367389.41 E 0.419 4101.71 8020.83 54.580 229.350 5276.59 5329.29 3506.18 S 4323.33 W 5971061.05 N 367329.32 E 0.538 4158.54 8116.24 54.250 229.440 5332.11 5384.81 3556.68 S 4382.24 W 5971011.56 N 367269.55 E 0.354 4215.07 8211.56 54.890 229.340 5387.37 5440.07 3607.24 S 4441.20 W 5970962.02 N 367209.73 E 0.677 4271.66 8307.16 54.800 229.790 5442.42 5495.12 3657.93 S 4500.69 W 5970912.35 N 367149.38 E 0.396 4328.78 8402.38 53.730 229.890 5498.03 5550.73 3707.78 S 4559.76 W 5970863.52 N 367089.47 E 1.127 4385.51 . 8498.25 53.740 229.300 5554.74 5607.44 3757.88 S 4618.62 W 5970814.44 N 367029.76 E 0.496 4442.02 8593.83 52.970 229.590 5611.78 5664.48 3807.75 S 4676.89 W 5970765.58 N 366970.65 E 0.842 4497.94 8689.09 52.570 229.980 5669.42 5722.12 3856.72 S 4734.81 W 5970717.60 N 366911.90 E 0.532 4553.56 8784.93 53.280 230.960 5727.20 5779.90 3905.38 S 4793.78 W 5970669.96 N 366852.10 E 1.1 02 4610.25 8880.41 52.840 231.660 5784.58 5837.28 3953.09 S 4853.35 W 5970623.28 N 366791.73 E 0.745 4667.57 8975.60 52.660 233.370 5842.20 5894.90 3999.20 S 4913,47 W 5970578.20 N 366730.83 E 1.442 4725.52 9071.25 52.580 234.970 5900.27 5952.97 4043.69 S 4975.09 W 5970534.77 N 366668.46 E 1.332 4785.04 9166.81 52.830 237.620 5958.18 6010.88 4085.86 S 5038.32 W 5970493.68 N 366604.51 E 2.221 4846.28 9262.25 51.170 241.070 6016.95 6069.65 4124.22 S 5102,99 W 5970456.44 N 366539.20 E 3.337 4909.13 9357.88 50.780 245.000 6077.17 6129.87 4157.90 S 5169.18 W 5970423.90 N 366472.44 E 3.218 4973.71 9453.28 50.130 249.200 6137.93 6190.63 4186.53 S 5236.91 W 5970396.43 N 366404.23 E 3.462 5040.06 9548.58 48.620 255.390 6200.01 6252.71 4208.55 S 5305.74 W 5970375.59 N 366335.04 E 5.177 5107.81 9643.77 47.230 260.580 6263.82 6316.52 4223.28 S 5374.79 W 5970362.05 N 366265.74 E 4.302 5176.12 9739.09 47.340 265.400 6328.50 6381.20 4231.82 S 5444.27 W 5970354.70 N 366196.13 E 3.717 5245.13 25 November, 2003 . 16:31 Page 4 of 7 OrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - C02-30 Your Ref: API 501032046500 Job No. AKZZ0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 9834.61 48.330 271.230 6392.65 6445.35 4233.87 S 5514.98 W 5970353.85 N 366125.39 E 4.640 5315.68 9929.64 49.310 278.840 6455.27 6507.97 4227.57 S 5586.12 W 5970361.37 N 366054.37 E 6.113 5387.04 10025.62 47.830 284.280 6518.81 6571.51 4213.19 S 5656.58 W 5970376.95 N 365984.16 E 4.520 5458.08 10118.52 47.070 289.610 6581.66 6634.36 4193.28 S 5722.01 W 5970397.98 N 365919.09 E 4.304 5524.35 . 10216.62 48.130 295.900 6647.84 6700.54 4165.26 S 5788.74 W 5970427,14 N 365852.85 E 4.855 5592.28 10311.81 47.990 301.250 6711.49 6764.19 4131.428 5850.88 W 5970462.04 N 365791.30 E 4.183 5655.91 10407.27 50.120 305.990 6774.06 6826.76 4091.48 S 5910.86 W 5970503.00 N 365732.01 E 4.363 5717.65 10502,00 53.870 311.890 6832.41 6885.11 4044.53 S 5968.80 W 5970550.93 N 365674.88 E 6.303 5777.68 10598.10 56.890 318.800 6887.05 6939.75 3988.28 S 6024.26 W 5970608.13 N 365620.39 E 6.697 5835.65 10693.54 57.620 327.300 6938.74 6991.44 3924.20 8 6072.42 W 5970673.01 N 365573.33 E 7.528 5886.69 10788.77 61.770 330.750 6986.79 7039.49 3853.728 6114.67 W 5970744.21 N 365532.29 E 5.363 5932.12 10884.26 64.690 329.310 7029.80 7082.50 3779.888 6157.27 W 5970818.77 N 365490.96 E 3.341 5978.05 10979.65 64.890 327.530 7070.43 7123.13 3706,36 8 6202.46 W 5970893.05 N 365447.03 E 1.701 6026.55 11074.96 64.760 325.650 7110.98 7163.68 3634.36 8 6249.95 W 5970965.85 N 365400.78 E 1.790 6077.29 11170.53 67.430 325.880 7149.70 7202.40 3562.138 6299.10 W 5971038.91 N 365352.88 E 2.802 6129.69 11265.77 74.640 329.970 7180.64 7233.34 3485.84 8 6346.83 W 5971116.00 N 365306.46 E 8.589 6180.85 11361.26 74.890 330.900 7205.74 7258.44 3405.71 8 6392.29 W 5971196.91 N 365262.38 E 0.975 6229.93 11429.92 76.670 330.560 7222.60 7275.30 3347.65 8 6424.83 W 5971255.51 N 365230.84 E 2.637 6265.09 11494.49 79.820 333.040 7235.76 7288.46 3291.95 8 6454.69 W 5971311.72 N 365201.94 E 6.159 6297.46 11590.28 84.000 331.050 7249.24 7301.94 3208.20 8 6499.14 W 5971396.21 N 365158.92 E 4.824 6345.70 11685.58 88.270 330.810 7255.66 7308.36 3125.128 6545.33 W 5971480.07 N 365114.16 E 4.488 6395.63 . 11781.43 90.860 329.630 7256.39 7309.09 3041.94 S 6592.93 W 5971564.06 N 365067.99 E 2.969 6446.99 11876.76 90.250 331.080 7255.46 7308.16 2959.09 S 6640.08 W 5971647.70 N 365022.27 E 1.650 6497.87 11972.30 90.310 329.500 7255.00 7307.70 2876.11 S 6687.43 W 5971731.47 N 364976,35 E 1.655 6548.96 12067.71 91.300 330.570 7253.66 7306.36 2793.47 S 6735.08 W 5971814.92 N 364930.12 E 1.528 6600.34 12163.22 92.280 330.400 7250.67 7303.37 2710.398 6782.11 W 5971898.79 N 364884.52 E 1.041 6651.12 12258.38 92.350 329.980 7246.83 7299.53 2627.898 6829.37 W 5971982.08 N 364838.67 E 0.447 6702.11 12354.24 92.160 331.120 7243.06 7295.76 2544.48 S 6876,47 W 5972066.29 N 364793.01 E 1.205 6752.97 12449.74 91.300 331.180 7240.17 7292.87 2460.88 8 6922.53 W 5972150.67 N 364748.39 E 0.903 6802.80 12545.37 90.800 331.400 7238.42 7291.12 2377.02 S 6968.46 W 5972235.30 N 364703.90 E 0.571 6852.51 12640,94 89.510 332.150 7238.16 7290.86 2292.81 S 7013.65 W 5972320.27 N 364660.15 E 1.561 6901.51 12736.46 89.880 331,780 7238.67 7291.37 2208.50 8 7058.55 W 5972405.33 N 364616.70 E 0.548 6950.21 12831.79 90.310 331.940 7238.51 7291.21 2124.44 S 7103.51 W 5972490.15 N 364573.19 E 0.481 6998.97 12927.02 90.620 331,910 7237.74 7290.44 2040.42 S 7148.32 W 5972574.93 N 364529.81 E 0.327 7047.58 13022.40 89.880 331.950 7237.32 7290.02 1956.26 S 7193.20 W 5972659.84 N 364486.38 E 0.777 7096.26 25 November, 2003 - 16:31 Page50f7 OrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - C02-30 Your Ref: API 501032046500 Job No. AKZZ0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) 13118.18 89.140 332.650 7238.14 7290.84 1871 .46 S 7237.72 W 5972745.39 N 364443.32 E 1.063 7144.61 13213.90 89.630 332.760 7239.17 7291.87 1786.40 S 7281.62 W 5972831.19 N 364400.89 E 0.525 7192.35 13309.20 90.250 332.780 7239.27 7291.97 1701.67 S 7325.22 W 5972916.66 N 364358.74 E 0.651 7239.78 13404.63 89.380 332.840 7239.58 7292.28 1616.78 S 7368.83 W 5973002.27 N 364316.59 E 0.914 7287.22 . 13500.18 89.450 333.370 7240.55 7293.25 1531.57S 7412.05 W 5973088.21 N 364274.83 E 0.559 7334.29 13595.83 89.750 333.470 7241.22 7293.92 1446.03 S 7454.84 W 5973174.47 N 364233.51 E 0.331 7380.95 13690.67 89.380 333.740 7241.94 7294.64 1361.08 S 7497.01 W 5973260.13 N 364192.81 E 0.483 7426.95 13786.08 91.170 332.110 7241.48 7294.18 1276.14 S 7540.43 W 5973345.81 N 364150.84 E 2,537 7474.21 13881.32 91.420 331.310 7239.33 7292.03 1192.29 S 7585.55 W 5973430.41 N 364107.16 E 0.880 7523.12 13976.80 91.600 331.300 7236.82 7289.52 1108.57 S 7631.38 W 5973514.91 N 364062.77 E 0.189 7572.73 14072.17 91.670 331.340 7234.09 7286.79 1024.93 S 7677.13 W 5973599.31 N 364018.46 E 0.085 7622.26 14167.60 91.230 331.140 7231.68 7284.38 941.30 S 7723.03 W 5973683.72 N 363973.99 E 0.506 7671.93 14263.17 90.370 331.840 7230.35 7283.05 857.33 S 7768.65 W 5973768.45 N 363929.82 E 1.160 7721.33 14358.86 89.140 332.600 7230.75 7283.45 772.67 S 7813.24 W 5973853.86 N 363886.68 E 1.511 7769.75 14454.56 89.320 332.200 7232.04 7284.74 687.87 S 7857.58 W 5973939.41 N 363843.81 E 0.458 7817.92 14550.02 89.940 332.380 7232.66 7285.36 603.36 S 7901.96 W 5974024.67 N 363800.87 E 0.676 7866.12 14645.59 90.370 332.910 7232.40 7285.10 518.48 S 7945.88 W 5974110.29 N 363758.41 E 0.714 7913.87 14741.07 90.430 332.620 7231.73 7284.43 433.59 S 7989.57 W 5974195.92 N 363716.18 E 0.310 7961.40 14836.73 90.560 332.860 7230.91 7283.61 348.56 S 8033.39 W 5974281.69 N 363673.83 E 0.285 8009.05 14932.20 91.290 332.900 7229.36 7282.06 263.59 S 8076.90 W 5974367.38 N 363631.77 E 0.766 8056.41 15027.49 91.920 333,260 7226.70 7279.40 178.66 S 8120.02 W 5974453.04 N 363590.11 E 0.761 8103.37 . 15122.91 90.190 333.280 7224.94 7277.64 93.46 S 8162.93 W 5974538.96 N 363548.66 E 1.813 8150.13 15218.30 90.860 332.510 7224.06 7276.76 8.55S 8206.39 W 5974624.60 N 363506.66 E 1.070 8197.42 15313.91 91.050 333.130 7222.47 7275.17 76.49 N 8250.06 W 5974710.38 N 363464.45 E 0.678 8244.93 15408.73 91.670 332.990 7220.22 7272.92 161.00 N 8293.01 W 5974795.61 N 363422.96 E 0.670 8291.70 15505.06 91.980 333.090 7217.15 7269.85 246.81 N 8336.66 W 5974882.16 N 363380.78 E 0.338 8339.23 15600.60 90.550 333,190 7215.04 7267.74 332.02 N 8379.81 W 5974968.09 N 363339.09 E 1.500 8386.23 15661.43 89.510 334.230 7215.01 7267.71 386.56 N 8406.75 W 5975023.08 N 363313.09 E 2.418 8415.64 15700.00 89.510 334.230 7215.34 7268.04 421.29 N 8423.52 W 5975058.10 N 363296.92 E 0.000 8433.98 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB= 52.70' MSL. Northings and Eastings are relative to 1865' FNL 1527' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 1865' FNL 1527' FEL and calculated along an Azimuth of 272.620' (True). 25 November, 2003 . 16:31 Page 6 of 7 OrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - C02-30 Your Ref: API 501032046500 Job No. AKZZ0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Magnetic Declination at Surface is 24.3330 (24-Aug-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 15700.00ft., The Bottom Hole Displacement is 8434.05ft., in the Direction of 272.8630 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) . Comment 15700.00 7268.04 421.29 N 8423.52 W Projected Survey Survey tool program for Cn?-30 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 266.00 0.00 266.00 265.94 15700.00 265.94 Tolerable Gyro 7268.04 AK-6 BP _IFR-AK . 25 November, 2003 - 16:31 Page 70f7 Ori/lQuest 3.03.05.005 ConocoPhillips Alaskalc. TUBING (()'10938, 00'4.500. 10.3.958) 'ROOUCTION (34-11481. 00 7.000. 'A1:26.(0) Gas Lift andrellDummy Valve 1 (10747-10748. 00'5.984) PACKER (10861-10862, 00:5.970) NIP (1092ß.10927. 005.000) WLEG (10937·10938. 00 5.000) OPEN HOLE (11481-15700. 005125) t I r !- II I ':-'--~' ., 'I . I . I I . CD2-30 API: 501032046500 SSSV Type: NONE Well Type: Orig Completion: Last W/O: Ref Log Date: TO: Max Hole Angle: Annular Fluid: Reference Log: 36' RKB Last Tag: Last Tag Date: Casing String· ALL STRINGS Description CONDUCTOR PRODUCTION SURFACE OPEN HOLE Tubing String· TUBING Size I Top 4.500 0 Gas Lift MandrelsNalves St I MD I TVD I ~~; I Man Type I V Mfr 1 10747 7018 CAMeO KBG-2 Other (plugs, equip., etc.) . JEWELRY Depth TVD Type 33 33 HANGER 2374 2019 NIP 10861 7072 PACKER 10926 7100 NIP 10937 7105 WLEG General Notes Date ~ Note 10/29/200 TREE: FMC 41/16 5K TREE CAP CONNECTION: 7" OTIS Size 16.000 7.000 9.625 6.125 Bottom 10938 Top o 34 36 11481 .ALPINE CD2-30 SVC Anç¡le @ TS: deç¡ @. Angle @ TO: 90 deg @ 15700 Rev Reason: Change TBG top Last Update: 11/22/2003 15700 ftKB 92 deg @ 12258 Bottom TVD Wt Grade Thread 109 109 62.50 H-40 WELDED 11481 7286 26.00 L-80 BTCM 3006 2383 36.00 J-55 BTC 15700 15700 0.00 TVD 7105 I Wt I Grade I 12.60 L-80 Thread IBTM V Type I V OD I Latch I Port I TRO I Date I Vlv Run Cmnt 1.0 BK 0.000 0 10/29/2003 DMY Description ID 3.958 3.812 3.875 3.725 3.875 FMC 4.5" TUBING HANGER CAMeO 'DB' LANDING NIPPLE BAKER S-3 PACKER W/MILLOUT EXTENSION HES 'XN' NIPPLE WINO GO PROFILE BAKER WIRELlNE GUIDE . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-30 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 15,700.00' MD (if applicable) . Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager Attachment(s) ~~'ùf"\~ ()03~\3S 26-Nov-03 RECEIVED DEC 082003 Alaska 011 & G~ Con$. CQmmiøeion AoChorege Halliburton Sperry-Sun Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-3D MWD Job No. AKMW0002601675, Surveyed: 28 October, 2003 Survey Report 25 November, 2003 Your Ref: API 501032046500 Surface Coordinates: 5974492.75 N, 371712.00 E (70020'18.7632" N, 151002' 27.5482" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974492.75 N, 128288.00 W (Grid) Surface Coordinates relative to Structure: 49.74 N, 6.34 W (True) Kelly Bushing Elevation: 52. 70ft above Mean Sea Level Kelly Bushing Elevation: 52.70ft above Project V Reference Kelly Bushing Elevation: 52.70ft above Structure Sp:I!!I"""I"""Y-SUI'1 CfRILLING SERVlc::E:S A Halliburton Company ~K~'bxn~ ¿)03~-\~S . . F(ECEIVED DEC 082003 \J:;¡¡j/(¡:¡ Oi! & Gas Coni. ~n Anchomge Survey Ref: svy321 Halliburton Sperry-Sun Survey Report for A/pine CD-2 - CD2-30 MWD Your Ref: AP/501032046500 Job No. AKMW0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -52.70 0.00 0.00 N 0.00 E 5974492.75 N 371712.00 E 0.00 Tolerable Gyro 83.00 0.250 116.000 30.30 83.00 0.088 0.16 E 5974492.67 N 371712.16 E 0.301 -0.17 178.00 0.750 250.000 125.30 178.00 0.388 0.24W 5974492.37 N 371711.76 E 0.991 0.22 266.00 3.250 281.000 213.24 265.94 0.108 3.23W 5974492.70 N 371708.77 E 2.995 3.22 MWD Magnetic 302.94 3.990 271.460 250.10 302.80 0.13 N 5.54W 5974492.97 N 371706.46 E 2.576 5.54 393.43 7.340 269.610 340.14 392.84 0.17 N 14.47 W 5974493.17 N 371697.54 E 3.707 14.46 . 484.03 9.780 253.510 429.74 482.44 2.058 27.64 W 5974491.17 N 371684.33 E 3.750 27.52 572.86 11.370 253.460 517.06 569.76 6.698 43.27 W 5974486.80 N 371668.62 E 1.790 42.92 662.36 11.550 254.150 604.77 657.47 11.658 60.34 W 5974482.14 N 371651.47 E 0.253 59.75 752.24 12.990 251.940 692.60 745.30 17.24 8 78.60 W 5974476.86 N 371633.11 E 1.685 77.73 842.09 13.960 244.110 779.98 832.68 25.108 97.96 W 5974469.33 N 371613.63 E 2.297 96.71 932.63 16.110 237.700 867.42 920.12 36.58 8 118.40 W 5974458.20 N 371592.99 E 2.999 116.61 1027.34 20.180 232.380 957.41 1010.11 53.59 8 142.46 W 5974441.61 N 371568.64 E 4.636 139.86 1123.14 23.620 234.770 1046.28 1098.98 74.758 171.24 W 5974420.94 N 371539.51 E 3.709 167.64 1217.65 27.170 234.990 1131.65 1184.35 98.06 8 204.39 W 5974398.20 N 371505.97 E 3.758 199.69 1313.53 30.210 236.530 1215.75 1268.45 123.93 8 242.45 W 5974372.99 N 371467.47 E 3.263 236.53 1407.42 33.240 239.860 1295.61 1348.31 149.888 284.42 W 5974347.75 N 371425.06 E 3.726 277.27 1503.00 36.410 239.740 1374.06 1426.76 177.348 331.59 W 5974321.11 N 371377.43 E 3.317 323.13 1598.86 39.500 239.220 1449.63 1502.33 207.298 382.36 W 5974292.04 N 371326.14 E 3.241 372.49 1694.47 42.450 237.650 1521.81 1574.51 240.128 435.76 W 5974260.12 N 371272.20 E 3.268 424.33 1788.31 45.630 236.100 1589.26 1641.96 275.788 490.37 W 5974225.40 N 371216.99 E 3.578 477.25 1882.71 48.090 234.770 1653.81 1706.51 314.87 S 547.08 W 5974187.29 N 371159.62 E 2.801 532.11 . 1978.16 49.220 230.820 1716.87 1769.57 358.20 S 604.12 W 5974144.94 N 371101.84E 3.324 587.11 2072.82 49.340 228.890 1778.63 1831.33 404.45 S 658.95 W 5974099.63 N 371046.23 E 1.550 639.77 2167.87 49.970 229.780 1840.17 1892.87 451.668 713.90 W 5974053.37 N 370990.47 E 0.974 692.51 2264.16 51.710 229.750 1900.97 1953.67 499.88 S 770.90 W 5974006.13 N 370932.66 E 1.807 747.24 2359.08 54.400 228.950 1958.02 2010.72 549.30 8 828.44 W 5973957.70 N 370874.28 E 2.913 802.47 2454.31 54.890 230.040 2013.12 2065.82 599.748 887.50 W 5973908.28 N 370814.37 E 1.066 859.15 2549.39 55.690 229.570 2067.26 2119.96 650.198 947.20 W 5973858.86 N 370753.82 E 0.934 916.49 2644.71 55.330 228.770 2121.24 2173.94 701.55 S 1006.64 W 5973808.52 N 370693.50 E 0.788 973.52 2740.18 53.790 228.510 2176.59 2229.29 752.95 8 1065.02 W 5973758.13 N 370634.25 E 1.628 1029.49 2835.07 54.650 228.030 2232.07 2284.77 804.198 1122.47W 5973707.88 N 370575.93 E 0.995 1084.54 2928.87 55.410 230.010 2285.84 2338.54 854.59 8 1180.50 W 5973658.49 N 370517.05 E 1.910 1140.20 2972.26 54.270 230.410 2310.83 2363.53 877.298 1207.75 W 5973636.25 N 370489.41 E 2.733 1166.39 3056.00 54.180 229.630 2359.78 2412.48 920.94 8 1259.81 W 5973593.50 N 370436.61 E 0.763 1216.40 25 November, 2003 -16:25 Page 20f7 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-30 MWD Your Ref: API 501032046500 Job No. AKMW0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3151.22 54.060 230.400 2415.59 2468.29 970.52 5 1318.93 W 5973544.94 N 370376.66 E 0.667 1273.19 3246.63 54.120 229.640 2471.55 2524.25 1020.17 S 1378.14 W 5973496.31 N 370316.61 E 0.648 1330.07 3341.96 54.030 231.150 2527.48 2580.18 1069.385 1437.62 W 5973448.12 N 370256.30 E 1.286 1387.23 3437.71 53.580 230.280 2584.03 2636.73 1118.30 5 1497.42 W 5973400.23 N 370195.66 E 0.871 1444.74 3533.20 53.500 231.420 2640.77 2693.47 1166.795 1556.98 W 5973352.77 N 370135.29 E 0.964 1502.02 . 3628.66 53.280 232.900 2697.71 2750.41 1213.805 1617.49 W 5973306.80 N 370073.98 E 1.266 1560.31 3724.07 53.020 231.880 2754.93 2807.63 1260.39 S 1677.97 W 5973261.25 N 370012.71 E 0.898 1618.60 3819.50 52.790 231.760 2812.48 2865.18 1307.445 1737.81 W 5973215.23 N 369952.08 E 0.261 1676.22 3915.12 52.660 232.140 2870.39 2923.09 1354.34 5 1797.72 W 5973169.37 N 369891.37 E 0.344 1733.93 4010.15 52.330 233.150 2928.25 2980.95 1400.085 1857.65 W 5973124.66 N 369830.67 E 0.912 1791.70 4105.48 51.960 233.210 2986.75 3039.45 1445.195 1917.90 W 5973080.59 N 369769.66 E 0.391 1849.83 4200.96 51.570 232.860 3045.84 3098.54 1490.285 1977.82 W 5973036.52 N 369708.97 E 0.500 1907.63 4296.60 51 .490 233.200 3105.34 3158.04 1535.32 5 2037.65 W 5972992.52 N 369648.38 E 0.291 1965.34 4392.71 51.180 234.030 3165.39 3218.09 1579.83 5 2098.06 W 5972949.04 N 369587.22 E 0.747 2023.65 4488.26 51.010 234.810 3225.40 3278.10 1623.105 2158.53 W 5972906.82 N 369526.01 E 0.660 2082.08 4583.53 51.090 233.990 3285.29 3337.99 1666.23 5 2218.78 W 5972864.73 N 369465.04 E 0.675 2140.29 4679.21 51.240 234.840 3345.29 3397.99 1709.605 2279.39 W 5972822.40 N 369403.70 E 0.710 2198.86 4774.64 51.160 234.970 3405.09 3457.79 1752.35 5 2340.24 W 5972780.69 N 369342.12 E 0.135 2257.69 4869.40 52.200 236.420 3463.84 3516.54 1794.255 2401.65 W 5972739.86 N 369280.00 E 1.627 2317.12 4964.94 52.820 235.490 3521.99 3574.69 1836.695 2464.46 W 5972698.49 N 369216.48 E 1.009 2377.93 5060.19 53.540 236.000 3579.08 3631.78 1879.61 5 2527.49 W 5972656.66 N 369152.73 E 0.869 2438.92 5155.94 53.730 234.930 3635.85 3688.55 1923.32 S 2591.00 W 5972614.04 N 369088.4 7 E 0.921 2500.37 . 5251.86 53.810 235.220 3692.54 3745.24 1967.61 5 2654.44 W 5972570.84 N 369024.29 E 0.258 2561.72 5346.99 54.550 235.100 3748.21 3800.91 2011.68 5 2717.75 W 5972527.86 N 368960.23 E 0.785 2622.95 5442.54 55.270 233.830 3803.14 3855.84 2057.125 2781.37 W 5972483.52 N 368895.85 E 1.323 2684.42 5538.06 55.770 232.730 3857.22 3909.92 2104.20 5 2844.48 W 5972437.52 N 368831.94 E 1.084 2745.32 5633.90 56.880 232.550 3910.36 3963.06 2152.60 5 2907.87 W 5972390.22 N 368767.73 E 1.169 2806.43 5729.22 57.550 230.670 3961.98 4014.68 2202.36 5 2970.67 W 5972341.53 N 368704.08 E 1.801 2866.89 5824.83 56.220 228.170 4014.22 4066.92 2254.44 5 3031.49 W 5972290.51 N 368642.38 E 2.594 2925.27 5920.34 55.930 227.750 4067.52 4120.22 2307.51 5 3090.35 W 5972238.45 N 368582.62 E 0.475 2981.64 6015.77 55.780 227.340 4121.09 4173.79 2360.82 5 3148.62 W 5972186.14 N 368523.45 E 0.389 3037.42 6111.22 55.450 225.730 4174.99 4227.69 2415.005 3205.79 W 5972132.95 N 368465.36 E 1 .434 3092.05 6206.69 55.770 226.440 4228.92 4281.62 2469.65 5 3262.55 W 5972079.28 N 368407.68 E 0.699 3146.25 6302.38 55.870 226.230 4282.68 4335.38 2524.30 5 3319.81 W 5972025.61 N 368349.49 E 0.209 3200.95 6398.02 55.640 225.820 4336.50 4389.20 2579.20 5 3376.71 W 5971971.70 N 368291.66 E 0.428 3255.28 25 November, 2003 - 16:25 Page 3 of7 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-30 MWD Your Ref: API 501032046500 Job No. AKMW0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6493.28 55.540 226.340 4390.33 4443.03 2633.71 5 3433.32 W 5971918.16 N 368234.13 E 0.462 3309.34 6588.73 55.510 226.480 4444.36 4497.06 2687.975 3490.31 W 5971864.89 N 368176.21 E 0.125 3363.79 6684.17 55.480 225.730 4498.42 4551.12 2742.505 3546.98 W 5971811.34 N 368118.61 E 0.648 3417.91 6779.59 55.490 226.340 4552.49 4605.19 2797.08 5 3603.57 W 5971757.73 N 368061.10 E 0.527 3471.95 6875.00 55.470 226.090 4606.56 4659.26 2851.475 3660.33 W 5971704.32 N 368003.42 E 0.217 3526.15 6970.26 55.340 226.190 4660.64 4713.34 2905.81 5 3716.87 W 5971650.96 N 367945.96 E 0.162 3580.15 . 7065.89 54.810 225.520 4715.39 4768.09 2960.42 5 3773.13 W 5971597.32 N 367888.77 E 0.798 3633.86 7161.22 54.570 226.230 4770.49 4823.19 3014.585 3828.97 W 5971544.12 N 367832.01 E 0.658 3687.17 7256.66 54.260 224.980 4826.03 4878.73 3068.87 5 3884.43 W 5971490.78 N 367775.63 E 1.114 3740.09 7352.17 53.960 226.030 4882.03 4934.73 3123.105 3939.62 W 5971437.51 N 367719.52 E 0.944 3792.74 7447.61 53.580 225.340 4938.43 4991.13 3176.885 3994.71 W 5971384.67 N 367663.52 E 0.706 3845.31 7543.14 53.120 225.500 4995.46 5048.16 3230.68 5 4049.30 W 5971331.82 N 367608.02 E 0.500 3897.39 7638.67 52.670 226.970 5053.09 5105.79 3283.38 5 4104.31 W 5971280.07 N 367552.11 E 1.315 3949.94 7734.11 53.670 229.240 5110.31 5163.01 3334.38 5 4161.18 W 5971230.05 N 367494.38 E 2.173 4004.41 7829.53 54.560 229.150 5166.24 5218.94 3384.90 5 4219.70 W 5971180.54 N 367435.01 E 0.936 4060.55 7924.94 54.950 229.310 5221.29 5273.99 3435.785 4278.71 W 5971130.67 N 367375.14 E 0.431 4117.18 8020.83 54.580 229.830 5276.62 5329.32 3486.58 5 4338.33 W 5971080.91 N 367314.66 E 0.587 4174.41 8116.24 54.250 230.680 5332.14 5384.84 3536.19 S 4397.98 W 5971032.33 N 367254.16 E 0.803 4231.74 8211.56 54.890 229.290 5387.40 5440.10 3586.135 4457.46 W 5970983.41 N 367193.83 E 1.365 4288.88 8307.16 54.800 230.390 5442.44 5495.14 3636.53 5 4517.20 W 5970934.03 N 367133.25 E 0.945 4346.24 8402.38 53.730 230.070 5498.05 5550.75 3685.98 5 4576.61 W 5970885.61 N 367073.00 E 1.156 4403.33 8498.25 53.740 230.120 5554.76 5607.46 3735.57 5 4635.90 W 5970837.04 N 367012.87 E 0.043 4460.30 . 8593.83 52.970 230.420 5611.81 5664.51 3784.58 5 4694.88 W 5970789.04 N 366953.06 E 0.844 4516.97 8689.09 52.570 230.990 5669.45 5722.15 3832.62 S 4753.58 W 5970742.02 N 366893.55 E 0.635 4573.41 8784.93 53.280 230.560 5727.22 5779.92 3880.97 S 4812.81 W 5970694.69 N 366833.50 E 0.823 4630.37 8880.41 52.840 230.750 5784.60 5837.30 3929.36 5 4871.83 W 5970647.32 N 366773.66 E 0.488 4687.12 8975.60 52.660 232.730 5842.23 5894.93 3976.27 S 4931.32 W 5970601.43 N 366713.38 E 1.666 4744.40 9071.25 52.580 234.800 5900.30 5953.00 4021.20 5 4992.62 W 5970557.56 N 366651.32 E 1.722 4803.58 9166.81 52.830 236.880 5958.20 6010.90 4063.88 5 5055.52 W 5970515.96 N 366587.69 E 1.751 4864.47 9262.25 51.170 241.310 6016.98 6069.68 4102.515 5120.00 W 5970478.43 N 366522.56 E 4.050 4927.12 9357.88 50.780 244.040 6077.20 6129.90 4136.625 5185.99 W 5970445.47 N 366456.00 E 2.255 4991.48 9453.28 50.130 249.430 6137.97 6190.67 4165.675 5253.52 W 5970417.57 N 366387.98 E 4.409 5057.61 9548.58 48.620 254.590 6200.04 6252.74 4188.035 5322.26 W 5970396.39 N 366318.87 E 4.403 5125.25 9643.77 47.230 261.730 6263.87 6316.57 4202.55 5 5391.32 W 5970383.05 N 366249.57 E 5.754 5193.57 9739.09 47.340 265.060 6328.54 6381.24 4210.61 S 5460.87 W 5970376.19 N 366179.89 E 2.569 5262.69 25 November, 2003 - 16:25 Page 4 of7 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-30 MWD Your Ref: API 501032046500 Job No. AKMW0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/1OOft) 9834.61 48.330 271.180 6392.69 6445.39 4212.90 S 5531.57 W 5970375.11 N 366109.17 E 4.860 5333.21 9929.64 49.310 279.440 6455.32 6508.02 4206.25 S 5602.66 W 5970382.97 N 366038.19 E 6.620 5404.53 10025.62 47.830 285.260 6518.86 6571.56 4190.91 S 5672.91 W 5970399.51 N 365968.22 E 4.800 5475.41 10118.52 47.070 290.800 6581.71 6634.41 4169.77 S 5737.95 W 5970421.76 N 365903.55 E 4.468 5541.34 10216.62 48.130 295.500 6647.88 6700.58 4141.28 S 5804.51 W 5970451.39 N 365837.49 E 3.699 5609.14 . 10311.81 47.990 301.820 6711.54 6764.24 4107.35 S 5866.58 W 5970486.37 N 365776.00 E 4.940 5672.70 10407.27 50.120 306.840 6774.11 6826.81 4066.67 S 5926.06 W 5970528.06 N 365717.23 E 4.555 5733.97 10502.00 53.870 312.730 6832.46 6885.16 4018.88 S 5983.30 W 5970576.82 N 365660.82 E 6.296 5793.34 10598.10 56.890 320.220 6887.11 6939.81 3961.55 S 6037.63 W 5970635.08 N 365607.48 E 7.139 5850.23 10693.54 57.620 329.000 6938.80 6991.50 3896.19 S 6084.02 W 5970701.22 N 365562.21 E 7.773 5899.56 10788.77 61.770 332.720 6986.86 7039.56 3824.39 S 6123.99 W 5970773.69 N 365523.48 E 5.509 5942.77 10884.26 64.690 330.940 7029.86 7082.56 3749.25 S 6164.25 W 5970849.51 N 365484.51 E 3.481 5986.42 10979.65 64.890 329.090 7070.50 7123.20 3674.51 S 6207.38 W 5970924.98 N 365442.67 E 1.767 6032.92 11074.96 64.760 327.090 7111.04 7163.74 3601.29 S 6252.97 W 5970998.97 N 365398.33 E 1.904 6081.81 11170.53 67.430 327.200 7149.77 7202.47 3527.90 S 6300.36 W 5971073.16 N 365352.20 E 2.796 6132.51 11265.77 74.640 331.790 7180.71 7233.41 3450.33 S 6345.97 W 5971151.49 N 365307.93 E 8.834 6181.62 11361.26 74.890 332.340 7205.81 7258.51 3368.93 S 6389.13 W 5971233.62 N 365266.16 E 0.614 6228.45 11429.92 76.670 330.780 7222.67 7275.37 3310.42 S 6420.83 W 5971292.67 N 365235.47 E 3.402 6262.79 11494.49 79.820 333.650 7235.83 7288.53 3254.50 S 6450.28 W 5971349.09 N 365206.98 E 6.537 6294.77 11590.28 84.000 331.640 7249.31 7302.01 3170.29 S 6493.86 W 5971434.02 N 365164.85 E 4.833 6342.15 11685.58 88.270 331 .440 7255.73 7308.43 3086.72 S 6539.16 W 5971518.36 N 365120.99 E 4.485 6391.22 11781.43 90.860 330.170 7256.46 7309.16 3003.06 S 6585.91 W 5971602.81 N 365075.68 E 3.009 6441.75 . 11876.76 90.250 331.760 7255.53 7308.23 2919.72 S 6632.17 W 5971686.93 N 365030.85 E 1.786 6491.77 11972.30 90.310 330.090 7255.07 7307.77 2836.22 S 6678.60 W 5971771.21 N 364985.86 E 1.749 6541.97 12067.71 91.300 330.130 7253.73 7306.43 2753.51 S 6726.14 W 5971854.72 N 364939.74 E 1.038 6593.24 12163.22 92.280 335.390 7250.74 7303.44 2668.66 S 6769.82 W 5971940.30 N 364897.52 E 5.599 6640.75 12258.38 92.350 331.550 7246.90 7299.60 2583.61 S 6812.28 W 5972026.07 N 364856.52 E 4.033 6687.06 12354.24 92.160 330.480 7243.12 7295.82 2499.82 S 6858.69 W 5972110.64 N 364811.54 E 1.133 6737.25 12449.74 91.300 331.360 7240.24 7292.94 2416.40 S 6905.09 W 5972194.84 N 364766.58 E 1.288 6787.41 12545.37 90.800 332.420 7238.49 7291.19 2332.07 S 6950.14 W 5972279.93 N 364722.98 E 1.225 6836.27 12640.94 89.510 332.540 7238.23 7290.93 2247.31 S 6994.30 W 5972365.43 N 364680.28 E 1.356 6884.26 12736.46 89.880 331.780 7238.74 7291.44 2162.85 S 7038.90 W 5972450.64 N 364637.12 E 0.885 6932.68 12831.79 90.310 332.460 7238.58 7291.28 2078.59 S 7083.48 W 5972535.66 N 364593.99 E 0.844 6981.06 12927.02 90.620 332.760 7237.81 7290.51 1994.04 S 7127.29 W 5972620.95 N 364551.64 E 0.453 7028.69 13022.40 89.880 332.580 7237.39 7290.09 1909.30 S 7171.08 W 5972706.41 N 364509.31 E 0.798 7076.30 25 November, 2003 - 16:25 Page 50f7 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-30 MWD Your Ref: API 501032046500 Job No. AKMW0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13118.18 89.140 332.800 7238.21 7290.91 1824.20 8 7215.02 W 5972792.25 N 364466.83 E 0.806 7124.09 13213.90 89.630 332.930 7239.24 7291.94 1739.02 S 7258.68 W 5972878.17 N 364424.63 E 0.530 7171.59 13309.20 90.250 333.200 7239.34 7292.04 1654.06 8 7301.84 W 5972963.86 N 364382.93 E 0.710 7218.60 13404.63 89.380 333.820 7239.65 7292.35 1568.658 7344.41 W 5973049.98 N 364341.83 E 1.119 7265.03 13500.18 89.450 330.840 7240.62 7293.32 1484.048 7388.77 W 5973135.34 N 364298.92 E 3.119 7313.21 13595.83 89.750 334.020 7241.29 7293.99 1399.27 8 7433.04 W 5973220.86 N 364256.11 E 3.339 7361.30 . 13690.67 89.380 334.130 7242.01 7294.71 1313.988 7474.50 W 5973306.85 N 364216.12 E 0.407 7406.62 13786.08 91.170 332.910 7241.55 7294.25 1228.58 8 7517.04 W 5973392.96 N 364175.04 E 2.270 7453.02 13881.32 91.420 332.090 7239.40 7292.10 1144.128 7561.00 W 5973478.15 N 364132.53 E 0.900 7500.80 13976.80 91.600 331.900 7236.88 7289.58 1059.858 7605.82 W 5973563.18 N 364089.16 E 0.274 7549.42 14072.17 91.670 332.050 7234.16 7286.86 975.708 7650.61 W 5973648.08 N 364045.82 E 0.174 7598.01 14167.60 91.230 331.410 7231.75 7284.45 891.688 7695.79 W 5973732.87 N 364002.08 E 0.814 7646.99 14263.17 90.370 332.490 7230.41 7283.11 807.358 7740.73 W 5973817.96 N 363958.59 E 1 .444 7695.73 14358.86 89.140 333.140 7230.82 7283.52 722.23 8 7784.45 W 5973903.81 N 363916.34 E 1 .454 7743.29 14454.56 89.320 332.230 7232.11 7284.81 637.21 8 7828.36 W 5973989.57 N 363873.89 E 0.969 7791.05 14550.02 89.940 332.500 7232.72 7285.42 552.64 8 7872.63 W 5974074.88 N 363831.06 E 0.708 7839.14 14645.59 90.370 333.120 7232.47 7285.17 467.63 8 7916.30 W 5974160.62 N 363788.86 E 0.789 7886.65 14741.07 90.430 333.220 7231.80 7284.50 382.43 8 7959.40 W 5974246.55 N 363747.23 E 0.122 7933.59 14836.73 90.560 332.840 7230.97 7283.67 297.188 8002.78 W 5974332.53 N 363705.31 E 0.420 7980.83 14932.20 91.290 333.400 7229.43 7282.13 212.04 8 8045.94 W 5974418.40 N 363663.61 E 0.964 8027.83 15027.49 91.920 333.390 7226.76 7279.46 126.87 8 8088.59 W 5974504.28 N 363622.42 E 0.661 8074.34 15122.91 90.190 333.990 7225.01 7277.71 41.35 S 8130.88 W 5974590.51 N 363581.60 E 1.919 8120.49 . 15218.30 90.860 336.030 7224.13 7276.83 45.10 N 8171.17 W 5974677.64 N 363542.80 E 2.251 8164.69 15313.91 91.050 334.970 7222.54 7275.24 132.08 N 8210.81 W 5974765.29 N 363504.65 E 1.126 8208.27 15408.73 91.670 336.010 7220.29 7272.99 218.33 N 8250.14 W 5974852.20 N 363466.80 E 1.277 8251.50 15505.06 91.980 335.000 7217.22 7269.92 305.95 N 8290.06 W 5974940.49 N 363428.39 E 1.096 8295.38 15600.60 90.550 334.320 7215.11 7267.81 392.27 N 8330.94 W 5975027.50 N 363388.99 E 1.657 8340.16 15661.43 89.510 332.610 7215.08 7267.78 446.69 N 8358.11 W 5975082.37 N 363362.75 E 3.290 8369.79 15700.00 89.510 332.610 7215.41 7268.11 480.94 N 8375.85 W 5975116.92 N 363345.60 E 0.000 8389.08 Projected 8urvey All data is in Feet (U8 Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB= 52.70' M8L. Northings and Eastings are relative to 1865' FNL 1521' FEL. Global Northings and Eastings are relative to NAD27 Alaska 8tate Planes, Zone 4. The Dogleg 8everity is in Degrees per 100 feet (U8 8urvey). Vertical 8ection is from 1865' FNL 1521' FEL and calculated along an Azimuth of 272.620° (True). 25 November, 2003.16:25 Page 60f7 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-30 MWD Your Ref: API 501032046500 Job No. AKMW0002601675, Surveyed: 28 October, 2003 North Slope, Alaska Alaska North Slope Magnetic Declination at Surface is 24.332° (24-Aug-03) Based upon Minimum Curvature type calculations, at a Mèasured Depth of 15700.00ft., The Bottom Hole Displacement is 8389.65ft., in the Direction of 273.286° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment . 15700.00 7268.11 480.94 N 8375.85 W Projected Survey Survey tool program for CD2-30 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 266.00 0.00 265.94 266.00 15700.00 265.94 Tolerable Gyro 7268.11 MWD Magnetic . 25 November, 2003 - 16:25 Page 70f7 DrillQuest 3.03.05.005 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to;Tom_Maunder@admin.state.ak.usandBob_Fleckenstein@admin.state.ak.us OPERATOR: ConocoPhllllps Alaska Inc. PERMIT NUMBER & WELL NUMBER PTD: 203·135 Well #: CD2·30 COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: FIELD I UNIT I PAD: Alpine PRETEST START 15 MIN TBG TYPE PACKER REQ TBG TIME TIME INJ TEST ANN. TVD CASING TBG TEST CSG TBG TBG FLUID TYP. FLUID MD SIZE I WT I GRADE SIZE PRESS PRESS CSG CSG PRESS PRESS N P Diesel 7,071 1,500 1,500 KCL brine 10,861 4.5 3500 3,525 3,445 o o o o TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: P.P.G. DIESEL 6.8 GLYCOL SALTWATER 9.2 DRILLING MUD OTHER Distribution: orig - Well File c - Operator c - Database c - Trip Rpt File c - Inspector OPERATOR REP SIGNATURE: Don Mickey . AOGCC REP SIGNATURE: CD2-30 MIT .xls Grad. 0.35 0.00 0.48 0.00 0.00 DATE: 30 MIN TIME TBG CSG PRESS 1,500 3,412 10/30/2003 START P F TIME 1:42 am xe I I I I I I ~ WELL TEST: Initial X 4 - Year Workover Other (Rev 9/23/99) Re: CD2-30 (203-135) Request for approval to commenc... e , Subject: Re: CD2-30 (203-135) Request for approval to commence injection From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 01 Mar 2004 10:27:12 -0900 To: "Crabtree, C L" <C.L.Crabtree@conocophillips.com> Cliff, This note acknowledges receipt of the warmback temperature survey for the subject well. I have examined the log and I do not find any evidence of water movement out of the Alpine. When you have a chance, I do have a couple of questions about the presentation. In particular, I would like to understand what/how the differential temperature curve information is presented. The scale used for the delta T doesn't seem to "relate" to the temperature differences I calculate. Tom Maunder, PE AOGCC Crabtree, C L wrote: 'b-~è, ~~~ è, '\. c;~ 'b-~ ~~ ~~ ~~~ :;;,~ ~. a\. Tom 30 days of injection would be sufficient. Aft- ~ei :;;,~'S ~~'bi ~~.~~ would simply be waiting on timing of rig moves - 'b-,,<:>ei .<9'bi~.::;s$ ~~è,ei.~~9o'V~~\~c;\.~ equipment. We hope to do this and the CD2-5t: è,~\#:~~ei ~ei~'b-~ ~~o~~~ package. I don't believe inj ection pressu~ :;;,-<>'<..~ è,~9o<ç '!,.'b-,,<:>ei o-<>~ ~~ ~¿...\-o ~c;~~~.} Alpine wells tend to inject at very low . ~~'bi tI..." -<y¡}. ~~~~'<..~ ~~~..:s.-~O o-4ei t c:..'. '!,. . '!,.. '!,.~ ~. ~ '\.~ ~ par . ~'?) 1 ';S;)o~. è,~~ '1->0~ . ^~~'Ç \.0 '!,.~'<.. / \::¡'?" ~~ ~ ~-4~ ~o~ ~~'<.. . '\- è,-<>~ ~ ~ Cliff ~ \)\Y :;;,-<>'Ç ~o\. .~ó.o c$ð~ ,,\-o~' "<:>~ :\.~. :V'? ~~'bi ¿\-~ :V-~ 'b-'<..~ ~~c; 'J>.'<.. \.0 \\.'b-~ '\) ~~ o. ~ ~ ~~ ~~ ei ei -----Original Message----- "G è..c;~ ð_~ ~'V ~~ ~o 'b-~'Ç. ~'Ç. / \.0'" >J . ~'O ~,~ ~~ ~ ei 'I. \.ei From: Thomas Maunder [mai 1 ,,;ì ...l~' 'J>.~~ ~ "-r' ,,~c; ,,~^"^~~ .;..,\-'b-.... . -.....l'" ~1 c; .::;s$ :V-'" ~\.> . '\-V ~ Sent: Frlday, December/;' ~-<>'" ~~ ~~ ~ ei'<..'b-~ '!,.~'Ç ~'. \-~'<..ei To: Crabtree, C L ~'<..~ ;($> ~ c-4~ .:s.-0~ ~'Ç. ~ ~~ ~~ei è,\-~ Cc: Alonzo, Chris; .(\,~'<..~ ""~o ""\. ~ " ~. ~ \.ei ,,'S.~'bi »9-~ ,,'J>.\.~'<.. ~'" . OV ~v ei"" '!,.\.'" '!,.\J . 0 Ã'" Subj ect: Re: CD2 \.~vA~~ ~~ è,~~'Ç. \\.~~ ~~ :\.~-4~ ~ ~ inj ect ion ",,'b-~ ~o"\.v ~0-4 ei~ '&\-\.\.~ .,.c...o'<..~ 'J>.~ ~..:s.-.::;s$ .æ'V ~. è, 900 ~ ...l V ~ ~~ ~'b-v'4Y <ç'\.-<>~ ~~ ~,.::;s$. -4~1 '!,.6 ~.} '!,.. ~~ '!,.ei <\" ~~. 'b-~ 0 ~~ ;:;.~'\. c$ð~~ ¿\-~ .\-è,~~ ~~ ,,'<..~ .(\,'bi <O..~~ ei~ '!,. 'Ç 'I. .\-~ o\-~ ~-4 -ô--1'" ~v ~ ~ 'J>." ~ ~~ . 'b-'" c; A\. v.~c;o ';S;)'b-c;.~c;'<..ei ~~o ;:;.~~ ei.}\: 0\.\.6 .\-~~ _uding the notes and logs ~ ~'b-~ ~~~ .;,~. "\.~ ,&-&-\.ei'Ç ei\.~ ~~ The history of the well and ~\-~ ~o~ .~\-~~~ ei~~·\-.}ei n By copy of this email, you O~c; ei~' ~'<..ei 8:- è,0 è,~è, ~nto service. Please make 'b-~ øð'!,.~~ ~~0.#~~ /~íspectors for a witnessed MIT when ~'\.~ c;~ ~ ~~ ~~ šei ';S;)o ~ ~o commence . ure survey, what is a "sufficient 01ish differentials?? Is 30 days expect that since there are a number of ,er at Alpine that operations should be able ûehavior that might be indicative of water zone. Please keep me advised. , PE to 10f3 3/1/2004 10:27 AM . . ~C)3 -. /3.::5 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 December 18, 2003 RE: MWD Formation Evaluation Logs: CD2-30, AK-MW-2601675 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-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ~', ~t~ _v-,-~ ,,0 ~ _~~ 1 LDWG formatted Disc with verification listing.--#Jd3/3 API#: 50-103-20465-00. RECEIVED DEC 2 2 2003 Alask.a QìI & Gas Cons, CornmÎS8iQn Anchorege ~~~v~'-~ Re: CD2-30 (203-135) Request for apPial to commenc... e Subject: Re: CD2-30 (203-135) Request for approval to commence injection From: Thomas Maunder <tom_maunder(4J.admin.statc.ak.us> Date: Fri, 12 Dec 2003 15:06:52 -0900 To: "Crabtree, C L" <C.L.Crabtree(4dconocophll1ips.com> CC: "Alonzo, Chris" <Chris.^lonzoª~conocophillips.com>, "Hanson, Kelli L" <Ke 11 i. L. Hanson(@conocophillips.com> Cliff, Chris and Kelli, I have reviewed the file for CD2-30 including the notes and logs that Cliff refers to in his message. The history of the well and isolation determination is accurate. By copy of this email, you have approval to place the well into service. Please make arrangements with one of the Inspectors for a witnessed MIT when one is next out to Alpine. With regard to the temperature survey, what is a "sufficient period of time'! to establish differentials?? Is 30 days sufficient?? I would expect that since there are a number of wells injecting water at Alpine that operations should be able to detect anomalous behavior that might be indicative of water moving out of zone. Please keep me advised. Tom Maunder, PE AOGCC a-CY-:S- \ ~ S- Crabtree, C L wrote: Tom CPAI hereby requests clearance to intiate injection into CD2-30. As you will recall, we've had several conversations about the cement job during which circulation was lost and subsequent bond logs that have been done across the isolation interval. To summarize those discussions: The CBL/USITsuite indicated there was cement placed across and above the Alpine, although it had not developed full class G strength due to mud contamination. The log also suggested there was no continuous channeling though the cement sheath. We reviewed the CBL/USIT and the interpretations of said logs in considerable detail in a meeting in at the CPAI office several weeks ago. At the end of the meeting, we concluded that it was likely that zonal isolation from the primary cement job did exist and that a coil assisted block squeeze would probably not improve upon what was observed using the CBL/USIT log suite. The conclusions from this meeting were documented by CPAI in the sundry submitted to AOGCC that was required for Doyon 19 to return to and complete drilling the well. Our plan forward is to conduct a post completion temperature survey to confirm the above interpretations after the well has been on injection for a sufficient period of time to create some lof2 12/12/20033:07 PM Re: CD2-30 (203-135) Request for app¡al to commenc... e temperature differentials due to injection. Based on those results, we will make a final determination on whether or not adequate zonal isolation has been achieved. I've attached futher back up documents below. Tha casing was MIT'd during the completion. Cliff Crabtree Alpine Subsurface Development - ConocoPhillips Alaska, Inc. Office Telephone: (907) 265-6842 Mobile Telephone: (907) 240 - 53 57 «CD2-30 1320 Disposal.pdf» «2-30 OH log.doc» Tubing Detail Well: CD2-30 4 1/2" Tbg Detail Date: 10/29/2003 DEPTH COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS FMC 4 1/2" Tbg hanger. 4 1/2" 12.6# L-80 IBTM Tbg Camco 4 1/2" DB nipple ID 1.53 2374.09 4 1/2" 12.6# L-80 IBTMTbg 8361.39 2375.62 Pup - 4 1/2" 12.6# L-80 IBTM Tbg 9.65 10737.01 Camco 4 1/2" KBG-2 GLM w/dummy 5.984" OD x 3.938" ID 10746.66 Pup - 4 1/2" 12.6# L-80 IBTM Tbg 10.20 10753.18 4 1/2" 12.6# L-80 IBTM Tbg 87.94 10763.38 Pup - 4 1/2" 12.6# L-80 IBTM Tbg 9.85 10851.32 4.5" X 7" BAKER S-3 PACKER w/ Millout ext. 5.97" OD X ID 11.02 10861.17 Pup - 4 1/2" 12.6# L-80 IBTM Tbg 4 1/2" 12.6# L-80 IBTM Tbg 43.90 4.5" "XN" NIPPLE "ID 1.20 10925.89 Pup - 4 1/2" 12.6# L-80 IBTM Tbg 4 1/2" WLEG 5" OD ID 1.34 10936.89 4 1/2" tbg tail @ 32.84 3.80 32.84 2337.45 36.64 5.62" OD x 3.812" 6.52 3.875" 9.80 10872.19 10881.99 5" OD x 3.725 9.80 10927.09 5" OD x 3.875" 10938.23 20f2 12/12/20033:07 PM LAT: 70.338545 LONG: -151.040985 ZONE: ASP 4 X: 371712.07 Y: 5974492.63 ALPINE 11499 52 ~I ~I .,; a. (/) (/) OHRPS_MWO_R_1 :J: uJ Ü u.. 02 QHMM 200 I-- Z <.) a:: a. ¡¡: a. w w .J .J a. a .,; .,; OH.GR_CORR_ GAPt 1õO OH.GR_MWD_R_1 1 -6000- - ~ ~ VO Plan: Prelim: West-l (wpOI) V2 fÇD2-43 V4 Plan: CD2-43 (wp02) Vl9 K:D2-33Ai Alpine CD2, CD2-40, CD2-40 V7 I I I I I I I I I - I I I t I I I I I I· I I I I I I I I I I -10000 -9000 -8000 -7000 -6000 -5000 West(-)/East(+) [IOOOft/in] Name 'N/·S -E!·W Northing bmÜ¡g Laùt,K!e lADgitud¡;: Slot CW.30-148.63 HUt 5974492,750 371712.000: 70""ZO'¡8.763N 15\,'01'1:7-548W NIA Plan: CD2-3 t (ST Core) VO Plan: CD2-31 2000-- 100(}--- +' i c ~ -.!., "5 -2000- c CIJ -3000- z5)û3-- /35 11/07/03 Sc~lum~epgeP NO. 3032 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Well Job# Log Description Date BL Color Prints . CD CD2-30 CD2-30 10484312 USIT 10684330 US IT 09/08/03 10/05/03 1 1 . SIGNE~n\..;~jV"~~~ DATE: R[CCIVC~ NOV 24 2003 Alaska 011 & G8i Con6- CommIeiDn Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank~ ·j ConocoPhillips Alaska, Inc.. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 . .~ ConocoPhillips October 15,2003 Alaska Oil and Gas Conservation Commission 333 West th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval - Resume operations after Temporary Shutdown of Drilling Operations CD2-30 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for Sundry Approval to resume drilling operations after a temporary shutdown of drilling operations on well CD2-30. The well encountered drilling fluid losses at 11141 ft. MD while backreaming after reaching TD of the intermediate hole section. The losses were controlled and 7" casing was set at 11841 ft. MD. Due to fluid losses and lack of pressure differential observed during cementing operations, the rig was moved off so that eline and coil tubing operations could obtain a cement bond log per regulation 20 AAC 25.30 (5). See the attached email from Cliff Crabtree regarding the evaluation of the bond log. It is planned to move Doyon 19 back to CD2-30 to drill the production interval on +/- October 21 , 2003. Please find attached Form 10-403, Application for Sundry Approvals, and the proposed program for returning to the well, a proposed completion schematic, cement bond log and an email from Cliff Crabtree regarding zonal isolation. If a copy of the cement bond log is required and it is not already at the AOGCC, please call and one will be sent. If you have any questions or require further information, please contact Vern Johnson 265-6081 or Chip Alvord at 265-6120. . ~IY') Vern Johnson Drilling Engineer ¡c//G/o 7 r-"-' ¡ .- f \Ve 1;__ ~. ? . ì '- 16 :'> Attachments cc: CD2-30 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Steve Moothart ATO 1530 A TO 868 A TO 848 ATO 844 Nancy Lambert Lanston Chin Anadarko - Houston Kuukpik Corporation STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~fwI1 Operational shutdow~ Perforate D D Stimulate D D . [J Repair well D o 1. Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (It): 36.9' RKB, 52.8' AMSL Suspend Pull Tubing 8. Property Designation: ADL 380075,387207/ ALK N/A 11. Total Depth MD (It): Total Depth TVD (It): Effective Depth MD (It): 11499' 7290' 11499' Casing Length Size Structural Conductor 80' 16" Surface 2979' 9.625" I ntermed iate Production 11444' 7" Liner Perforation Depth MD (It): None Packers and SSSV Type: None 12. Attachments: Description Summary of Proposal 2] Detailed Operations Program 2] BOP Sketch 0 . Plug Perforations D Time Extension D Variance .4-'01 I/(o Annuiar Dispos.D Perforate New Pool Other ~ D ~ '!Þù,,^,-( Re-enter Suspended Well ~ 5. Permit to Drill Number: Q~ .'at-; ~ 4. Current Well Class: Development D Stratigraphic D Exploratory D Service 2] 203-135 6. API Number: 50-103-20465-00 9. Well Name and Number: CD2-30 10. FieldlPools(s): Colville River Field / Alpine River Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (It): Plugs (measured) Junk (measured): 7290' MD TVD Burst Collapse 114' 114' 3016' 2389' 3520 psi 11481' 7290' 7240 psi Perforation Depth TVD (It): None Packers and SSSV MD (It): Tubing Size: None Tubing Grade: None 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 10/21/2003 Date: Printed Name C. Alvord Signature A c. ()(. None 13. Well Class alter proposed work: Exploratory D Development D 15. Well Status alter proposed work: Oil D Gas D WAG 2] GINJ D Plugged D WINJ D Contact Vem Johnson @ 265-6081 Title Alpine Drilling Team Leader Phone 265-6120 COMMISSION USE ONLY Date 10/ fú (03 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D Mechanical Integrity Test D BOP Test D Other: 1"\.0 \'-. (! Location Clearance D C--· f--;~ ~ 9'~ ':_ lVt:[) t'tl")""r" ' Ul. ¡ i 6 Subsequent Form Required: \....l (:) \. CA.,...\- Q~~"'-'fiA¡~Jka ~ ¡\.:; G3;; GrH1S. Ant~ OF THE COMMISSION Approved by: ~~COMMISSIONER 1717psi 5410 psi Tubing MD (It): None Service 2] Abandoned D WDSPL D .303-3.:2.1 Date: /Ø~DJ OCT 2 0 200'j ORIGINAL RBDNtS SF L . . Drilling Program: 1. Move on Doyon 19. 2. ND tree. 3. NU and Test BOP to 5000 psi. 4. Pick up and run in hole with 6-1/8" drilling BHA. 5. Clean out float equipment, and drill 20 ft of new hole. 6. Perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off to drill ahead is 11.0 ppg EMW. 7. Displace well to Flo-Pro drill in fluid. 8. Drill 6-1/8" horizontal section to well TD at 17685' MD 1 7370' TVD. 9. Displace well to brine (plan to use seawater for makeup water) and pull out to casing shoe. 10. Continue to pull out of hole and lay down BHA. 11. Run 4-W', 12.6 #, L-80 tubing with XN nipple, permanent packer, gas lift mandrel with dummy valve, and Cameo DB Nipple (3.812" ID). Land hanger. Back out landing joint. Install 2-way check with rods. M/U landing joint and test hanger seals to 5000 psi. 12. Nipple down BOP. 13. Install wellhead adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2-way check with lubricator. 14. Circulate in 9.2 ppg inhibited brine and sufficient diesel to fill the tubing plus provide 2000' TVD of diesel freeze protection on the annulus. 15. Pressure up on tubing to 4000 psi to set Baker Premier packers. Test tubing to 3500 psi./30min. Test casing annulus to 3500 psi 1 30 min. 16. Set BPV and secure well. Move rig off . Completion Schematic CD2-30 16" Conductor to 114' II 4-1/2" Camco DB Nipple (3.812') at 2000' TVD =2341' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3006' MD / 2383' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" DRIFT ID) wI dummy . Updated 10/16/03 Actual depths to 7" casing point Packer Fluid mix: 9.2 ppg KCI Brine with 2000' TVD diesel cap TubinQ suspended with diesel Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco DS6 nipple 2341' 2000' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco KSG2- GLM (3.909" ID) 1 0730' 7010' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) Baker SAB3 Packer w/ millout extension 10830' 7059' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) HES "XN" (3.725")-64.8 inc 1 0930' 7102' 4-1/2", 12.6#/ft, 1ST-Mod 10' pup joint WEG 10942' 7107' Baker SAB3 Packer WI millout extension at +1- 1083G MD I 7059' TVD <200' TVD from top of Alpine Top Alpine at 11363' MD / 7259' TVD Well TD at 16045' MD I 7272' TVD . . Clifford L Crabtree 10/16/200312:28 PM To: Vernon T Johnson/PPCO@Phillips cc: Christopher J. Alonzo/PPCO@Phillips. Michael Kasecky/PPCO. Hai L HuntlPPCO, Chip AlvordlPPCO@ Phillips Subject: C02-30 Primary Cement Job Evaluation. Vern As previously discussed, we have reviewed the most recent bond log results for the 7" casing with Tom Maunder of the AOGCC and have concluded that a block squeeze is not required for isolation of injected seawater to the Alpine Sand. While pumping the primary cement job for the 7" casing on CD2-30 we were unable to establish circulated returns to surface. Based on similar indications and logging that subsequently showed inadequate isolation in C02-55, it was concluded that zonal isolation was not assured. We elected to move the drilling rig off the well to provide the time and resources to more fully evaluate the outcome of the primary cement job. The initial SCMT bond log did not show adequate cement for two reasons. The SCMT is limited in it's ability to detect lower strength cement, and second, we were unable to convey the logging tools deep enough to log a cement top, We made another coil assisted cleanout attempt and were subsequently able to convey logging tools slightly deeper in the well. Following this cleanout, we ran a combination tool suite composed of a cement bond log/US IT tool across the interval of interest. Schlumberger considers this combination to be the most accurate technology available for determining the condition and placement of cement in the casing-borehole annulus. The CBUUSITsuite indicated there was cement placed across and above the Alpine, although it had not developed full class G strength due to mud contamination. The log also suggested there was no continuous channeling though the cement sheath. We reviewed the CBUUSIT and our interpretation in detail with Tom Maunder of AOGCC in a recent meeting. At the end of the meeting, it was concluded that it was likely that zonal isolation from the primary cement job did exist and that a coil assisted block squeeze would probably not improve upon what was observed using the CBUUSIT log suite. It was agree the conclusions from this meeting would be documented by CPAI in the sundry submitted to AOGCC that was required for Doyon 19 to return to and complete drilling the well. Our intent at this time is that CPAI will conduct a post completion temperature survey to confirm the above interpretations after the well has been on injection for a sufficient period of time to create some temperature differentials due to injection. Based on those results, we will make a final determination on whether or not adequate zonal isolation has been achieved. Cliff Crabtree ConocoPhillips Alaska Inc.- Alpine Subsurface Development Office: (907) 265-6842; Cell: (907) 240-5357 Email: c.l.crabtree@conocophillips.com; Fax:: (907) 265-1515 • Alpine CD2-30 Figure 1: Logs for interval between the top HRZ and TD in the Alpine C sands: 0 032 -lbsoo ConocoPhi l l i ~s LOCATION FIELD Alaska, If1C. LAT: 70.338545 ALPINE LONG:-t5t040985 DRILLED DEPTH ~ \.Z ._ \ ~.j ZONE: ASP 4 11499 ~ \ J J X: 371712.07 ELEVATION KB `/ Y: 5974492.63 52 OH.GR_CORR_1 U ~'~ ~~ OH CAL1_DAS S_1 - - - - - - - - OH.SP DAS_5_1 ~~~~ ~~~~~ OH E ~ ~4b.,ln g ~ ~ - -. ' OH.GR_MWD_R_1 S EET A ~ W d pth FEET GH IZPU MVJCJ_F UT t ~~ ALPIN E.KMAIR t nz mu r.i OH.RP$ MWD R_t o.z ow,w - aao OH.RPM MWD_.R_1 ~ dry _ Z O ~= Q ~ O LL S F d W O Q d W d J Q •- `I y U d J Q ww r-n ~cu"s ' ~'~e ~ PC C VGLP.UC -. ,:, pCC.VCL GR 1 - - o cnP~ isn i.m cra zss o wv 6800 - 10450 - - I 10500 6850 - _- 10550 10600 6900 10650 6950 10700 ~ '-:; -- - _ _- ~ 1 - - -f -- 10800 ! 700Q - - ___ _- __._.- _"~= -- - 10850 __ 7 klauH . _ ~ _ __ _ _ ~_. QBbQ: - __ ___._ .__ - _ 10900 ~ ~ -___ __ - t _ ~ D91d -__ - -___. .. _.. -.-_.-. - -. ~_ _ _ 087. _. - KRU SS -. ---- - - ~ S3:- -- 11000 7100 11050 '' 11100 ~ ~ _ 11150 ~ 7150 11200 ~ MILUVEACW _- -' __ _ _ _ 11250 __- _ - __. __. I _ ~ _.-_ _ 7200 113 ____ _ - - u< _ _ 1L _ _ _ o- -_ - 11a dn~ i - --- • • Maunder, Thomas E (DOA From: Clifford L Crabtree [C.L.Crabtree@conocophiliips.com] Sent: Thursday, September 18, 200310:47 AM To: Tom Maunder Cc: Christopher J. Alaizo; Hai L Hunt; Chip,4lvord Subject: SCMT from CD2-30 Attachments: 2-30 OH log.doc; CD2-30~1.ZIP 200? ~. ~~ `' r ~ `~ `~ ~~~~~~ NO`S ~- 2-30 OH bg.doc (Z CD2-30~i.ZIP (2 KB) KB) Tom Attached is a no pressure / pressure bod log pass on CD2-30. We've concluded the primary cement job does not offer adequate zonal isolation and are planning at coil assisted isolation squeeze similar to the ane recently completed on CD2-55. We've been unable to obtain a bond log to the top of the Alpine in CD2-30. The E-line tractor encountered an obstruction about 11,270' MD, well above the float collar at 11,392'. The top of the Alpine D is at 11,290' and the top of the C is at 11,361' MD. We are now trying to decide where to place the deepest squeeze perfs. From the character of the log, we are fairly confident that we could perforate at 11,290' MD and expect to circulate cement up to 11,160' or so. Our question is, would this be a satisfactory design to AOGCC? Attached below are the bond log and a ward file with a picture of the open hole log. Best Regards ~ ~4~~T'~ ( ~ Cliff Crabtree \~r ~l ConocoPhillips Alaska Inc.- Alpine Subsurface Development ~ `4-~ Office: (907) 265-6842; Cell: (907) 240-5357 y~(~ Email: c.l.crabtree@conocophillips.com; Fax:: (907) 265-1515 ~7- (See attached file: 2-30 OH log.doc) ----- Forwarded by Clifford L CrabtreelPPCO on 09/18/2003 10:23 AM ----- Nina M Woods 09/17/2003 10:54 AM To: Hai L Hunt/PPCO@Phillips, Michael Kasecky/PPCO@Phillips, Clifford L Crabtree/PPCO@Phillips cc: Subject: SCMT from CD2-30 (See attached file: CD2-30~1.2IP) Nina Woods Well Supervisor ConocoPhillips Alaska Inc. (907) 670-4555, 448-1986 1 .,!"'UtI THDH THDL THNO UMAO USTO USUB UWKM VCAS WLEN ZCAS ZINI ZMUD ZTCM ZTGS CWEI DO PP DEFAULT DEFAULT I is t"roçesslßg Level Maximum Search Thickness (percentage of nominal) Minim.arch Thickness (percenfase of. nOminal). Nomin ckness of Casing "\, . USIT Me urement Angular Offset "'s. Ultrasonic Time Offset' Ultrasonic Subassembly Identifier Ultrasonic Working Mode Ultrasonic Transversal Velocity in Casing T^3 Processing Length Acoustic Impedance of Casing Initial Estimate of Cement Impedance Acoustic Impedance of Mud Acoustic Impedance Threshold for Cement Acoustic Impedance Threshold for Gas System and Miscellaneous Casing Weight Depth Offset for Playback Playback Processing VilA_I.""" 130 70 0.362 -10 -2 Sub 7 inch 10DEG-6IÑ LF - 51.4 21.7078 46.25 1.85 1.48 2.6 0.3 26.00 16.0 RECOMPUTE USt SONIC _01 OLUP Input DLIS Files FN:9 PRODUCER 05-0ct-200313:49 11328.5 FT USt SONIC _110PUP Output DLIS Files FN:54 PRODUCER 0S-Oct-2003 20:11 SGbll.~.PIIP CEMENT / VDL COMBINED LOG REPEAT PASS MAXIS Field Log Company: CONOCOPHILLlPS ALASKA, INC. DEFAULT DEFAULT US IT-A DSL T-H DTC-H USI_SONIC_014LUP Input DUS Files FN:13 PRODUCER 05-0ct-200314:49 11322.5 FT USI_SONIC_111 PUP Output DLlS 'Files FN:55 PRODUCER 05-0ct-2003 20:21 11346.5 FT OP System Version: 11 CO-305 MCM 11 CO-305 OP11-KP1 11 CO-305 DTA-A SGT-N CAL-Y OP11-KP1 11 CO-305 11 CG-305 Zoning of Mud Parameters Depth Fluid Velocity (DFVL) Acoustic Impedance (ZMUD) 11320.00 191.31 1.79 11250.00 191.31 1.79 IN DEG US US/F US MBAY MRAY MRAY MRAY MRAY LB/F FT 10907.0FT Well: CD2-30 10830.5 FT 10792.5 FT . 11200.00 191.81 1.79 11100.00 191.30 . 1.79 . 10900.00 191.30 1.79 10700.00 191.77 1.80 10400.00 191.27 1.80 10300.00 190.76 1.81 10200.00 190.76 1.81 10100.00 190.76 1.81 External Gamma R (GR radius ay ) Average (GAP!) (ERA V) 150 4.5 (IN) Internal radius Maximum (lRMX) 3 3 (iN> 4.5 Maximum of AI (AIMX) o (MRAY) 10 Min of Internal Mln of Internal radius (IRMN) radius (IRMN) 4.5 (IN) 3 3 (IN) 4.5 Cable Internal radius Internal radius peed (CS) Maximum Average J~Ltf_~L.. (IRMX) (IRAV). 5000 4.5 (IN) 3 3 (IN) 4.5 Average of AI {AlA V) o (MRAY) 10 - -500.0000 - 0.5000 - 1.0000 - 1.5000 2.0000 I 2.5000 3.0000 3.5000 4.0000 4.5000 5.0000 5.5000 6.0000 6.5000 7.0000 7.5000 8.0000 i., 1000.??oo -500.0000 0.3000 ",,' 2.6000 H 3.0000 3.5000 4.??oo 4.5000 5.??oo 5.5000 6.??oo 6.5000 7.0000 7.5000 8.??oo Sonlc_Wl_Curve (VOL) 200 (US) 1200 CCl Internal radius External radius (CClU) Average Average (_) (IRAV) (ERAV) !O 20 4.5 (IN) 3 3 (IN) 4.5 1 <1.300 · · · · · · · · · · l- · · · · · · · · · · · · ... ... ... ... · · · · · · Mln Amplitude Max Minimum of AI <A~~J." ," o (MnHY) 10 Bonded Raw Acoustic Imped. (AIBI<) (.--- ) Cement Map with Impedance Classification (AI MICRO OEBONOING IMAGE) - (--) · > . · · · · · · · · · · · · · · · · · , .. l >. · j ~ LAST READING o . ':':::f ~~.~ -.- ; ~·i"";··: . ....' '.. ".: '\11.' ¡. ." .:".¡, " '. ;~, ~ ~~ :~ .t ft, ¡:.; ~'"'' t· .. ~ l ~ .?' AoJ · ~.. " , ';)::' ':I. .. · ,: iIoo ,~-~;~-~~~ ..... '-.I' . ~~ I :: t :~. ':-~ ;¡¡~' :,},.: ,". '. ,. ~f { ~. · .. . "/r~~" ~,. , " .".¡; ~~ :. :' ~~ :.- " " ".t ~ '" ...., .. .. . '"..';i , ,. !' ~ II ~ j, . . . ( : 'i j rraR . PRJ.tV~· A ..OC _U ~.. ~s ~ .. .' .". ~ ~~;. ',.:~ .' '. ·o'!:" .: " .J:.: . ".' . f I' . i . ~.", " :. " . . ..,' .. ~ ':2.'J1 ..' .... .. \_.' . ). , ~:' i¡I ~~ '. :1 '~ :~ " ~ ~, '. ,'. . , . . ~II ,. ,.:;. If I~;: -" .'" . , . .- , ......~ · " " ., ~ I 1 ~:~OO . , '. !,' ;, .. '.. · " " ::".¡ .' \- ~ I ~ . ,. , ,. '.' , &1 I ,ii...;.' !.... " '" 1\. ,II '" ~ . · , .. __. ,..._. ...... _ n__..". _. .. CCL Internal radius External radius (CCLU) Average Average (___) (IRAV) (ERAV) () 20 4.5 (IN) 3 3 (IN) 4.5 Cable Internal radius Internal radius ,eed (CS) Maximum Average {~tl.:'.F~L..J (IRMX) (IRAV) 5000 4.5 (IN) 3 3 (IN) 4.5 External ~amma radius :ó¡~~) ~:::.:~e 1504.5 (IN) Internal radius Maximum (IRMX) 3 3 (IN) 4.5 Min of Internal Min of Internal radius (IRMN) radius (IRMN) 4.5 (IN) 3 3 (IN) 4.5 rmat: USt VOLCement ""/' ," '.. .Jiri·~" ~.~ ~',~.. ..:', j',;, ~~. . '~:'"'' . ._~. .:'....{,;:1. .::: ~. ---. -. . ."\ ·}·t ,~S1·.~~~·'-.~ . i :~ f-.) !.>¿ -r=..~.~-, ..:. ~'t.~ ~_ )~.~ ----=.~ :._ ~, ._.t: .. \.L....... .-- .-;M~i - -500.0000 0.5000 1.0000 1.5000 2.0000 J¡¡f 2.5000 3.0000 3.5000 4.0000 4.5000 5.0000 5.5000 6.0000 6.5000 7.0000 7.5000 8.0000 Raw Acoustic Imped. (AIBI<) (-) Vertical Scale: 5" per 100' "T -A aT_H 11 CO-305 nø.. 1.Ii"Ø1 Minimum of AI (AIMN) o (MRAV) 10 ;1000.??oo -500.??oo 0.3000 ~,R!a ~= 3.5000 4.??oo 4.5000 5.0000 5.5000 6.??oo 6.5000 7.??oo 7.5000 8.??oo Min Amplitude Max Cement Map with Impedance Classification (AtMICRO_ DEBONDlNG_ IMAGE) (--) Average of AI (AIAV) o (MRAV) 10 Maximum of AI (AIMX) o (MRAY) 10 , ¡¡¿~ :11[11IIII"" Bonded Sonic_VOL_Curve (VDl) 200 (US) 1200 Graphics File Created: 05-0ct·2003 20:21 OP System Version: 11Co-305 MCM DTA-A O:~'T" ..I OP11-KP1 ..."^ ....AfI!I!'r 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 36.9' RKB, 52.8' AMSL 8. Property Designation: ADL 380075, 387207/ ALK N/A 1. Type of Request: D ARer casing D D Abandon Change approved program 11. Total Depth MD (ft): 11499' Casing Structural . fltlO/1 '1ßI ~~6 D Annular Dispos.D " D . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown D D D D Repair well D D Perforate D D Other 0. Suspend Variance Plug Perforations Stimulate Time Extension Re-enter Suspended Well D 5. Permit to Drill Number: 203-135 / 303-268 6. API Number. Pull Tubing Perforate New Pool 4. Current Well Class: Development D Stratigraphic D Exploratory D Service 0 50-103-20465-00 9. Well Name and Number: CD2-30 10. Field/Pools(s): Colville River Field / Alpine River Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 7290' MD TVD Burst Collapse Total Depth TVD (ft): Effective Depth MD (It): 7290' 11499' Length Size Intermediate Production Liner Perforation Depth MD (ft): None Packers and SSSV Type: None 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Conductor 80' Surface 2979' 11444' 16" 114' 114' 9.625" 3016' 2389' 3520 psi 1717 psi 7" 11481' 7290' 7240 psi 5410 psi Perforation Depth TVD (ft): i Tubing Size: Tubing Grade: Tubing MD (ft): None None None None Packers and SSSV MD (ft): None 1 0/3/2003 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas D WAG 0 GINJ D Abandoned D WDSPL D Service 0 Plugged D WINJ D Date: Contact Hai Hunt @ 265-6912 Printed Nam: I--L fA' Mooney Title Wells Team Leader SignatllfB/ir I Ò ~ ¡.Jlfl "'~Nr 1Þt M.I4DONlrlhone 263-4574 COMMISSION USE ONLY Date ? II !ð3 Conditions of approval: Notify Commission so that a representative may witness Othe, ,,5 cO \'.. \ ,...:,,,,\ _-> M. '&\ ~ +"'., \- \ C. ~ ",,-fc" \- 'ÿ'''- \~~ \ O~ß3$Ý!\Í\~ Subsequent Form Required: "-\0,,-\ w ( \~ cf;~ \~'-J~~..:~.....Ç:: ~ COMMISSIONER Plug IntegrityD BOP Test D Approved by: fk-1 Form 10-403 Revised 2/2003 Sundry Number: ~\:) ~- ~aD Mechanical Integrity Test D Location Clearance D BY ORDER OF THE COMMISSION Date/c(J/03 OC'1f U¿ÜUJ ORIGINAL SUBMIT IN DUPLICATE . Conocó'Phillips . Hai Hunt Wells Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6912 CD2-30 Remedial Cement Job Procedure Outline Background Drilling suspended operations on CD2-30 after getting indications of a poor cement job on the 7" casing string. The rig installed the tree and moved off the well on 9/4/03 to allow for diagnostics and a remedial cement job if warranted. A cement bond log (USIT) done on 9/8/03 was inconclusive so another bond log was done. The second cement bond log (SCMT) was done on 9/16/03 and showed a lack of cement behind the 7" down to 11,270', where the tool tagged bottom. The top of the Alpine D is at 11290' and the top of the Alpine C is at 11361'. Although unlikely, it is still possible that the un logged portion of the well above the Alpine C has cement behind pipe. The current plan of action is to mill out cement in the 7" casing to log the unlogged section above the Alpine C sand. If the new bond log shows lack of cement above the Alpine C then a cement squeeze will be done. - , Remedial Cement Job Scope · CT (coiled tubing) will mill down and clean out the 7" casing and E-line will do a cement bond log across the interval between the Alpine C sand and 11270'. · If there is a lack of cement in this interval, the well will be perforated slightly above the Alpine C (exact depth will be determined after the bond log is completed). An injectivity test will be done to decide how to squeeze the well. · The most likely case is that injectivity test will show low injection rates. If this is the case, a second set of perforations will be added -130' above the first and a cement retainer will be run between the two sets of perforations (exact spacing will be determined after the bond log is completed). CT will stab into the cement retainer and pump cement through the lower perforations, out and around the 7" casing, and back into the 7" casing through the upper perforations. · The cement job will be pressure tested after a sufficient curing time has passed. · The cement and retainer will be milled out by CT. · A follow-up cement bond log will be run by Eline. · Drilling operations will resume. ~ Wells Engineer CPAI Drilling and Wells HH/skad t--_· -.- ,.......-~ ,....,<.. "'''' ,..",..-;y ".. " . ..... (\f"T 0 1 ,",vI ... .~. -', .~f '.. *" ') ;'" -" :\ OR\G\NAL Scblln~epgeP NO. 2974 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job# Log Description Date BL Prints CD 809 -~' CD2-30 23438 SCMT 09/16/03 1 fl4D2-55 23424 SCMT 07/27/03 1 ~C8-- \ CD2-55 23425 USIT 07/26/03 1 f~.ECt:IVED SIGNE~"\_~ jy\' ~ \. Q c"t ~ Ó'/~ DATE: ,....,........ 2'" "",,,7 ...... - ".J ,', /' .V.J '-'L."J v ...V þ)juska û~,~ [it Conl=TIi~~Qn Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank~J~Oi!ge ~~~W\-b 09/25/03 . . ConocoPhillips Alaska, Inc. . Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 e ConocJPhillips ~ September 4, 2003 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval - Temporary Shutdown of Drilling Operations CD2-30 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for Sundry Approval to temporarily shutdown drilling operations on well CD2-30. The well encountered drilling fluid losses at 11 141 ft. MD while backreaming out of the hole. The losses were controlled and 7" casing was set at 11481 ft. MD. Due to lost circulation and lack of pressure differential observed during cementing operations, it is planned to move the rig to another well and run a cement quality log on CD2-30 off rig. The results of the log will determine remedial action. It is requested that dispensation be granted for suspension of this well, to allow non-rig evaluation and possibly remediation. Doyon rig 19 would then move to CD2-18 and commence drilling the horizontal injector. It is planned to return to CD2-30 and finish drilling the well after all isolation issues have been addressed. Please find attached Form 10-403, Application for Sundry Approvals, and the proposed program for securing the well. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~~~ Vern Johnson Drilling Engineer Attachments 7' /<7/ /a .? RECEIVED SEP 0 J 2003 Alaska Oil & Gas COns. eommilion Andø:age cc: CD2-30 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Steve Moothart ATO 1530 A TO 868 A TO 848 A TO 844 Nancy Lambert Lanston Chin Anadarko - Houston Kuukpik Corporation G P.' \ ,.. t\ 1. Type of Request: .. STATE OF ALASKA .. ALA~ OIL AND GAS CONSERVATION COMM1!!mION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown 0 D Perforate New Pool D D Alter casing D D Abandon Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: D Repair well D D Suspend Pull Tubing P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 36.9' RKB, 52.8' AMSL 8. Property Designation: ADL 380075, 3872071 ALK N/A 11. Total Depth MD (ft): 11499' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): None Packers and SSSV Type: None Total Depth TVD (ft): Effective Depth MD (It): 7290' 11499' Length Size 80' 2979' 11444' Plug Perforations Perforate D D Variance D Annular Dispos.D Time Extension D Other D Re-enter Suspended Well D 5. Permit to Drill Number: 203-135 6. API Number: Stimulate 4. Current Well Class: Development D Stratigraphic D Exploratory D Service 0 50-103-20465-00 9. Well Name and Number: C02-30 10. Field/Pools(s): Colville River Field / Alpine River Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 7290' MD TVD Burst Collapse 16" 114' 114' 9.625" 3016' 2389' 3520 psi 1717psi 7" 11481' 7290' 7240 psi 5410 psi Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None Packers and SSSV MD (ft): f{[C[IVLO 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch D 14, Estimated Date for Commencing Operations: 9/4/2003 16. Verbal Approval: Date: 9/4/03 Commission Representative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name. C. Alvord ~7 Signature 3 . ,)... 'rJ--Z Title Alpine Drilling Team Leader Phone 265-6120 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug IntegrityD BOP Test D Mechanical Integrity Test D 13. Well Class after proposed work: Exploratory D Developmen,..g.... r: Service 0 15. Well Status after proposed work: ':>Lf-" 0 :.) 200J Oil D Gas Ou' . ~I~_g~ D Abandoned D WAG 0 GINJ~aOiI&G~~ommissiOßvDSPL D Anchorage Contact Vern Johnson @ 265-6081 Date 91'(/03 Location Clearance D Sundry Number: 0()1'~U& Other: V'\O-\\~'tc.\-~" ~ t"'~~ ()~c~\-\e.~~ ~>\)'+-'.~~~'f\ 50"'..""" Foon Req"'<ed, ~'f ",,,,,J)'ïc.. \ e~tQ...I,.\-0"'" '::. II-^o.:>S -\ '.:>~ 0. ~~~ \)'\C< L{()">. Approved by: ~~~ RBDMS BFl SEP8~ COMMISSIONER BY ORDER OF THE COMMISSION Date: 7/1DJ CR\G't\~AI e e 'Temporarv Halt to DrilIinp' Operations Proe:ram: 1. POOH, lay down 4" drillpipe. 2. Displace with 8.8 ppg brine and sufficient diesel for 2000' MD freeze protection. 3. Nipple up tree, and pressure test to 2500 psi. 4. RDMO Doyon 19. 5. Change out tree with 7-1116" fully opening valve, to allow access for non-rig remediation. 6. Return to CD2-55 when all zonal isolation issues have been resolved. Re: CD2-30 . Subject: Re: CD2-30 Date: Thu, 21 Aug 200316:18:19 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Vernon T Johnson <Vern.Johnson@conocophillips.com> CC: Chip Alvord <Chip.Alvord@conocophillips.com>, Zane A Kuenzler <Zane.A.Kuenzler@conocophillips.com> Vern, et ai, The change you describe in the casing setting depth and location is really insignificant. No further notice will be necessary. With regard to the need for a diverter. Sorry for not specifically noting that on the permit or in the letter. A diverter has not been required on the CD2 wells for some time and that same exception applies to CD2-30. Good luck with the well. Hopefully, changing the casing setting point will help avoid the lost circulation problems recently encountered. Tom Maunder, PE AOGCC Vernon T Johnson wrote: . > Tom, > > As discussed, we have made a small change (+/- 173 fl) to the landing point > for the intermediate hole on C02-30, as compared to what was permitted. > The permit indicated landing the well at: 431 FNL 2471 FWL sec 10 T11N R4E > UM. We are now planning to land at 270. 18FNL 2535.65FEL T11N R4E Section > 10. > > The change was made because we want to minimize the amount of Alpine > reservoir exposed while drilling intermediate hole, thus reducing the risk > of differential sticking. > > Also, the permit for C02-30 does not indicate a waiver for drilling without > a diverter, as has been granted on all of the recent C02 wells. Please > advise. > > Thanks, > > Vern Johnson > 907-265-6081 (w) > 907-265-1515 (fax) > 907-748-3906 (Cell) > Vern.Johnson@conocophillips.com ,-- dO~-\~ 'J . _ n.., .,... "....., . ___........ ..., ..__". ___ ...__ ". _._ ._.,.. _._ .,__.".. .."_ ,.__. _,,_._.~.________ Tom .~;Í1ª~IJJ~?~ <tom_cn_ª!-!nci.ºL@adrr]jD:.?t.a!e.a~,us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1of2 8/22/20037:39 AM ~~!Æ~ . . lID f !Æ ~!Æ ~ ~ ~ !Æ II FRANK H. MURKOWSKJ, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION / Chip Alvord Alpine Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99510 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Alpine River Pool CD2-30 ConocoPhillips (Alaska), Inc. Permit No: 203-135 Surface Location: 1865' FNL, 1527' FEL, Sec. 2, TIIN, R4E, UM Bottomhole Location: 1482' FNL, 566' FWL, Sec. 3, TlIN, R4E, UM 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 approvals required . by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). SinC~erelY' .., {2'} Il . , ~J./{~ j ~- Sar alin Chair BY ORDER OJ THE COMMISSION DATED this.2)E day of July, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section Drill~ Re-enby 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1 a. Type of Work: '} A/~, ) STATE OF ALASKA ALASKA OIL & GAS COMMISSION PERMIT TO DRILL ExploratoryU Development Oil U Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket [J Single Well 11. Well Name and Number: Bond No. 59-52-180 CD2-30 6. Proposed Depth: 12. FieldlPool(s): MD: 16066' ( TVD: 7272' Colville River Field 7. Property Designation: RedrillU 1b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AI< 99510-0360 4a. Lcx::ation of Well (Governmental Section): Surface: 1865' FNL, 1527' FEL, Sec. 2, T11 N, R4E, UM I Top of Productive Horizon: 431' FNL, 2471' FEL, Sec. 10, T11N, R4E, UM Total Depth: ,:vJL. "J1í 1482' FNL, 566' ~ Sec. 3, T11 N, R4E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371712' 16. Deviated wells: Kickoff depth: 300 ft. 18. Casing Program Size Hole Casing 16" 9.625" 7" 4.5" 42" 12.25" 8.5" NIA 19 Total Depth MD (ft): Casing Structural Conductor Detailed Operations Intennediate Production Uner Perforation Depth MD (ft): 20. Attachments: Filing Fee 0 Property Plat D Weight 62.5# 36# 26# 12.6# ,. Alpine River Pool 13. Approximate Spud Date: 8116/2003 ALK 380075, 387207 8. Land Use Permit: ADL NIA 9. Acres in Property: 2560 14. Distance to Nearest Property: 431' FNL, Sec. 10 15. Distance to Nearest 10. KB Elevation y- 5974493 / Zone- 4 52 feet Well within Pool: CD2-40 I 1004' ./ (Height above GL): 17. Anticipated Pressure (see 20 Me 25.035) ./ ~ Maximum Hole Angle: 90.60 Max. Downhole Pressure: 3291 psig / Max. Surface Pressure: 2564 psig Setting Depth Quantity of Cement Specifications Top Bottom c. f. or sacks Grade Coupling Length MD TVD MD TVD (including stage data) H-4Q Weld 77' 37' 37' 114' 114' J-SS BTC 2654' 37' 37' 3024' 2390' 543 sx AS Ute & 230 sx UteCrete L-80 BTG-M , 9146' 37' 37' 11584' 7302' 167 sx Class G L-80 IBT-mod 10930' 32' 32' 10962' 7136' PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) (fa be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Length Cement Volume MD 1VD Size Perforation Depth ND (ft): BOP SketchD Diverter Sketd1 D Shallow Hazard Analysis 0 20 MC 25.050 requirements 0 Drilling programliJ Seabed Report 0 Time v. Depth Plot U Drilling Ruid Program 0 Date: 21. Verbal Approval: Corrmission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowtedge. Printed Name Signature 7? Permit to Drill Contact Zane Kuenz/er @ 265-1308 Title Alpine Drilling Team Leader Phone Date 7/Z~/Os Preoared bv Zane Kuenzler c. Alvord by · (J /)-.,{ Conditions of approval : Nurroer. ;2.D"3 - / 3 S- API Nurrber: 50- /ð3-2D~S--ø o Yes ~No o Yes J8! No Other: """\,~ C!L~~~~....::o.((~ \0' Original Signed By S:lr"'h Pelin Approved by: Samples required Hydrogen sulfide measures Commission Use Only Pern1t Approval . Date: 1 JI O? Mud log required Directional survey required See roIer letter for other requirements 0/. .... ,-.~~,g.rtl.. ¡'.~"'~o. ~,Yes . U'··~':. ~i t .~ L. ~? IJ! ') C !] 3 COMMISSIONER BY ORDER OF THE COMMISSION Dare, 1/1;1 6' Form 10-401 Revised 3/2003, Submit in Duplicate G \ N A. L OR\ CD2-30 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detêliled Risk Information for further discussion of these risks) .12-1/411 Hole /9-5/8" CasinQ Interval Event Risk Level Conductor Broach Low Well Collision medium Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVD Lost Circulation Low Low ~ 8-1/2" Hole /7" CasinQ Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVD Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low - Mitigation Strategy Monitor cellar continuously during interval. Gyro single shots, traveling cylinder diagrams Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries Mitigation Strategy BOPE drills, Keep mud weight above 9.6 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers .6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation moderate Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low Mitiqation Strategy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 8.8 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers Alpine: CD2-30 ') ') Procedure 1. Move on Doyon 19. 2. Drill 12-1,4" hole to the surface casing point as per the directional plan. 3. Run and cement 9-5/8" surface casing. 4. Install and test BOPE to 5000 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Pick up and run in hole with 8-1/2" drilling BHA. 8. Drill 8-%" hole to intermediate casing point in the Alpine Sands. (LWD Program: GR/RES/PWD) 9. Run and cement 7" casing as per program. Top of cement> 670 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" 'x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 10. BOPE test to 5000 psi. 11. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. 12. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 16. Circulate the hole clean and pull out of hole. 17. Run 4-%,12.6#, L-80 tubing with D~ nipple, gas lift mandrel(s), and packer. Land hanger. 18. Install 2.way check and pressure tes.t hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Circulate tubing to diesel and.install freeze protection in the annulus. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 22. Set SPV and secure well. Move rig off. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-29 will be the closest well to C02-30. Well separation is 10.7 ft at 300 ft MD. Accounting for survey uncertainty, the ellipse-to-ellipse separation is 5.3 ft at 300 ft MD. Drillinq Area Risks: - There are no high-risk events (e.g. over-pressures zones) anticipated. -. Lost circulation: Faulting within the Alpine reservoir section is considered the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. 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 Pumpinq Operations: Incidental fluids developed from drilling operations on well CD2-30 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The CD2-30 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVO. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. ..-. Upon completion of C02-30 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring as a result of 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. ReferËmce the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the below the base of the Schrader Bluff Formation (C-40). These 300-400' thick shales are part of the COiViTìê'" Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: . Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2390') + 1,500 psi = 2,990 psi Pore Pressure = 1,081 psi Therefore Differential = 2991 -1081 = 1910 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Bu rst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1 ,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC.:.Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi " CD2-30 DRILLING FLUID PROGRAM ) ) SPU D to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 V2" Section - 6 1/8" point - 12 "A" 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 m in 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 60/0 Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel/polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is. potential for lost circulation, particularly after the Alpine 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 well bore stability. Production Hole Section : The horizontal production interval will be drilled with aM-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. C02-3D 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 : Csg Setting Fracture Pore Casing Size Depth Gradient pressure (in) MOrrVD(ft) (Ibs. I gal) (psi) 16 114 I 114 10.9 52 53 9 5/8 3024 I 2390 14.5 1081 1563 7" 11584 I 7302 16.0 3304 - 2564 N/A 16066/7272 16.0 3291 ~ NOTE: The Doyon 195000 psi BOP equipment is adequate. Test BOP's to 5000 pSI. ASP Drilling (psi) . ~ '6 ~E \-\\J~ PROCEDURE FOR CALCULATING ANTICPATEO 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]0 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 : 0= true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] 0 = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1081 - (0.1 x 2390') = 842 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] 0 = [(14.5 x 0.052) - 0.1] x 2390 = 1563 psi OR ASP = FPP - (0.1 x D) = 3304 - (0.1 x 7302') :.:: 2574 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3291 - (0.1 x 7272') == 2564 psi ./ ") Colville River Field ) C02-3D Injection Well Completion Plan 16" Conductor to 114' II - 4-1/2" Camco DB Nipple (3.812') at 2000' TVD = 2360' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3024' MD / 2390' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" DRIFT ID) wI dummy Updated 07/29/03 Packer Fluid mix: 9.? PPCJ KCI Brine with ?OOO' TVD diesel cap Tubing suspended with diesel Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Cameo DB6 nipple 2360' 2000' 4-1/2", 12.6#/ft, IBT-Mod Tubing Cameo KBG2- GLM (3.909" 10) 10750' 7027' 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) Baker 53 Packer wI millout extension 10850' 7082' 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725")-62.5° ¡nc 10950' 7131' 4-1/2", 12.6#/ft, IBT-Mod 10' pup joint WEG 10962' 7136' Baker S3 Packer WI millout extension at +1- 10850' MDI 7082' TVD <200' TVD from top of Alpine TOC @ +1- 10600' MD 16936' TVD (>570' MD above top Alpine) Top Alpine at 11270' MD /7254' TVD Well TD at 16066' MD I 7272' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 11584/7302' TVD @+/- 89.2º Alpine, CD2-30 Well CementinÇJ Requirements 95/8" Surface Casin~ run to 3024' MD 12390' TVD Cement from 3024' MD to 2524' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2503' to surface with Arctic Set Lite 3. Assume 300 % execs's annular volume in permafrost and 50 % excess below the permafrost (1561' MD). Lead slurry: System: Tail slurry: System: (2524'-1561') X 0.3132 felft X 1.5 (50% excess) = 452.4 fe below permafrost 1561' X 0.3132 fe/ft X 4 (300% excess) = 1955.6 fe above permafrost Total volume = 452.4 + 1955.6 = 2408.0 ft3 => 543 Sx @ 4.44 ft3/sk 543 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fe/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% SOOI accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant 500' X 0.3132 fe/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 ft3/ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 felsk 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % SOOI accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casin~ run to 11584' MD 17272' TVD Cement from 11584' MD to +1- 10700' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (11584' - 10600') X 0.1268 ft3/ft X 1.4 (40% excess) = 174.7ft3 annular vol. 80' X 0.2148 fe/ft = 17.2 fe shoe joint volume Total volume = 174.7 + 17.2 = 191.9 fe => 167 Sx @ 1.15 fe/sk 167 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 1.15 fel 1 By Weight Of mix Water, all other additives are BWOCement ~ Sperry-Sun Drilling Services Alaska North 510 North Slope, AJ¡ C~~~.(I ~._-.:.--". . WfÌ~,~i~~' 2 . "'~-" .-,:. ", .....,I' pro277 Proposal Ref: W) Report Surface Coordinates: 5974492.75 N1 371712.00 E (70020' 18.7632" N, 151002' 27.5482" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 52.00ft above Mean Sea Level I ·~1 ,..w 'V ~ ...... :~_::~çaa= ';'_···~-"1'~--"".-. - ~ 'RláfJ(;:&JJIm::1iJe!il1~U AI!Ü~ àm:pllrt;r . ;::.~ Proposal 21 July~ 2003 DrillQues! 3.03_02.002 ¡Approved: i fhecked: IDateITime: 21 July, 2003 - 13:20 prepared by: GAndrews r~~()rt*-l) Vertical Section (1865' FNL 1527' FEL) sper-I',:/-5iun D FU L. [-iN G 5 @ R V', c:e-s I 10000 I 8000 I 6000 I 4000 I 2000 o I -2000 Scale: 1 A thU.ì'MkTÙ'i fl;1Mj'-,\.S~ Qj - 8000 ~ (f) CU2-30 (Rev Toej Point Target 7272.00 lTD. 387..17 N. 8465.87 H' 7" Csg Pt 11583.71' MD (11)2-30 (Hed) 7302.00' TVD 1 ectangle, Sides: 223.61 x 45S2,5fHl /1.W2.00 ,['l/D, 3S60.81 S. 6344JJ! HI Qj -æ (,) (/) 52_00h above Mean Sea Level True Nor1h Feet (US Survey) 1100.00 w;;1šflk, Jõ5'Fj'V[)--~o~ti;;;;-Dï; @îõOõ°ïtï5õft ~ 2ÕÕÕ:ÕO"ftM'iî17Š4,24ftTVD- - - - - - - - - - - - ~End Dir, Start Sall@54,OOOo:2187.49ttM-D,1898.43ftTVD ----,--:----, -_...._--------------------~ Pennaì-osl J (¡Ú2' TH) 2000 - !/, 2500.00 9·518" Csg Pt ... Drill out 8·1/2" Hole: 3024 ft M Dr 2390 ft TVD - 2000 ~ ~~0~·Tru:l-:~:~:~:~:~:~:~:~:~:~:~:~: ~ 2 ('-30. 2410' TVD ~ ~ -...,.-- - 4JOO':ð09..5L8.:.G.s~ EL- - - -- -- - - - - - - - - - - - - - - - -- ~ C-2l1, 2786' TV/) l' 3023.80 . N l[) 2390,00 L() II I II ~ ~ ::s:::: -:--- - --:-.~ . .r- - - - - - - - - - - - -Á"4~ - - - - - - - - - - - ::¿a: a: 4000 -fï.·1 " ,., r .,J' 'III ., - 4000 ........., .............:-----. ----_....._-----~------------- '-'" ..c: J{.] .1tarii.o, 4UfO I \-) I ~~" """ . 0' ø ..c: ...... .. <:¡ 1.<~ I'}..,! ...... 0. o~\ ~...Q,.....' ~" 0. Q) ~? .<",~<;;i' t>,,<ç....... \\."",' \;)c§ ,,-" Q) o 7600.00.~ @ :Q rj.~" r§:- ~~ ~'ò~ ~t¡... -::.. 0 -æ I ~~ <)~ "\~ o\"~ ~<) '"!;.ç9-'iS ,!\,'\ o\è'~ r:>~fJ.. ¿:.Jf>J -æ .2 ___ I-s>.;~~<;>~~~-~----~----------- .2 æ .1lbítm fJ7. 5413"'H) ~'\,~,6t-· Ï\~ @ ~~~~~,,~~~eC tt:r"'rS fO'þ~~\<V'v ã5 > -- S!~~...~=-~-~------IÄ:!.~------------- 6000 > 6000 -11bÙm Y6. SfJ47 ¡VD ~ n: \~v~.~..,---.....~ ~~.- ç;,<;:,)-.....'\ - nolO;) ~\.' 'ò~ ..... 1;>0 , . ~ '^ =:: ..... 0 'V'" ~.. r¡;. AI.. .' «. . .::",'v' 0 "r¡;. <1;0 ~V ~ r "f «,,- 0 fIRZ, 6849'n~" ¿"'è\. ,« ,\v~ ~ 1- ~ - - - ',0" /"""~- - - - - - - --:S.::..,f - - - - - - - - - - - - - - II if - 'I) ~2 i6' ITl) /.00 13000.00 14100 00 15200.00/ ..r: __ ~ "- ~ .. .. ~ - - - -:......... ......... .....-.. tI!ft ....... _ ......... .. ............. __ ......- g 'J!. CD2·30 (wp05) ~ ¢: o o o C\I \I ..c 8000 - (,) ,£ Nor1h Reference: RK8 Elevation: Horizomal Coordinates: Ref. Gbbal Coordinates: 5974492.75 N, 371712.00 E Ref. S!nx:!txe : 49.74 N, 6.34 W Ref. Geographical Coordinates: 70' 20' 187632" N, 151' 02' 27.5482"1'1 1865' Ffo.\.. & 1527' FEL, SEe 2 - T11 N - R.4E eD2-30 I I /"5HL (1865' FNL & 1527' FEL, SEC 2 . T11 N . R4E) o - - - - --~gTn Dir @3òffi5õ'ft(iri'12'=1/4" Hole) :3õõtrMb, 300ft T~ - - - - - - - - - - - 0 Reference is True North Current Well Properties 10000 I 8000 I 6000 I 4000 I 2000 I o ¡ I -2000 I ~s ,L- j----T---· '. . . -~.:.., ,- . ..~. '-QI1~t'II!llllpS ConocoPhillips Alaska, Inc. Colville River Unit Alpine (CD2 Pad) North)CD2-30 (wp05) Ji:\,Z i rn t~ 'ill: = 2000ft P:XNE == o o o II .c o .~ êònÕêt11hiUiös .. ConocoPhillips Alaska, nc. Colville Fliver Unit Alpine (CD2 Pad) Scale: 1inch = 1000ft CD2-30 (wp05) -8000 -7000 -6000 -5000 -4000 I I I I I Target: 16066.3OftMD,727.2.00ftTVD; 1482' FNL, 4714' FEL (Sec 3-T11N-R4E) .~ ! ..., . (,[)l-J() (Rev Toc) ....-··-··....·....POíllt Target 7272.00 TVD. 387.47 N. 8465.87 W Q) 0-- (ij o (f) ::J ·1000' W u.. r-... C\I L{) ....J Z u.. -2000 - í.o (0 CO ,- C;; 0) c:: E t ~ -3000 - -4000 - DrillQuest 3.03.02.002 -3000 I -2000 I Scale: 1 inch = 1000ft o I I I -1000 I SHL (1865' FNL & 1527' FEL, SEe.2 - T11N - R4E.} Begin Dlr @3°110Oft (in 12-1/4" Hole) : 300ft MD, 300ft T .~, ------------------------------------ 7" Csg Pt ... Begin 6-1/8" Hole: 9183 ft MD, 7117 ft TVD 7"Csg Pt 11583.71' MD 7302.00' TVD I -8000 I -7000 5p.E!r'r'~ '.'. ...~un..... ð--r--¡- G ~-,'. '. .~r~-~ ~ , J .IN .. .. '~..Fi rJ;,V{"".:: .. ^ H*lIIbW'tol! CØtfflf}lJiW Continue Dlr @ 3.000°/1000 : 2000.0OftM D,1784.24ftTVD I End Dir, Start Sail @ 54.000° : 2187.49ftMD,1898.43ftTV \ 1600.00 , I permafro1 2100.00 I C-:40 9-5/8" Csg Pt... Drill out 8-1/2" Hole: 3024 ft MD, 2390 ft TVDC¡-30 ¡ ~~Q ~ ~~~~ ~ ~~ ~,(f. ~<¿.: ~~~ (\~ K-3 Marker ~~ ,," ,,\1; ~'). ¡ ~t't;.f:.$~ ~\ ~Q' ~Q' K-2 Marker ¡ '\" ,,\\\ < ~,~ ~, ~~ "1..- ~ ~~.. ~ I ~ ~ ~<-:'b"~~\ ~~". . 0;~":J ,,\<5«~ i< '!J~ ,,"- ~. !ò':l'~ b\ ~ I.~ ~" ,,($ ....~ ~Oj ,,'þ~' :\. v'~' ~'\ ~::' '}.: ¡;.' s·;'> ~'j> o\~ ~. ~<t~V ~\~ c..\Q.t ,~~ ~~ ~~ @ ,,"Ii- ~ '\~ ;..~,y~, @to· Q 7 .66 "t; (,\>1-:&~'l~ ~ Q~ ~e~~ ! ,/ ~\~'i;..~~e~, Albian 97 : '\ ~ bC;; i cP «,,~ ¡ 6600.00 I -6000 I -5000 -4000 Eastings(1865' FNL 1521' FEL) I -3000 ¡Prepared by: GAndrews ~. .~~.~- 9 5/8" Csg Pt 3023.80' MD 2390.00' TVD :Yf ~*,; ....' ReferAn~A i~ TnJA North Current Well Properties We/I: CD2-30 Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure: Ref. Geographical Coordinates : 5974492.75 N, 371712.00 E 49.74 N, 6.34 W 700 20' 18.7632' N, 151002' 27.5482' W I -1865' FNL & 1527' FEL, SEC 2 - T11N - TE 52.00ft above Mean Sea Level I True North Feet (US Survey) I RKB Elevation: North Reference : Units: I -2000 I -1000 IDatelTime: 21 July, 2003 - 12:43 reeked: ¡ApprOVed: == o o o II .c o .~ Q) (ij o (f) --0 .~ - -lOCe·-::; W u.. r--.. C\I L{) ..- ....J Z - -200C L.1.. í.o (0 CO ,- Cñ o c:: :..ë t _ _?r~,: ~ ~ - -400C o DrillQuest 3.03.02.002 Page 2 of 15 21 July, 2003 - 12:29 Sperry-Sun Drilling Services Proposal Report for CD2-30 (wp05) RevIsed: 21 July, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical· )::<:~ Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs _ Rate_ Sectlo·n d6mment (ft) (ft) (ft) (ft) (ft) (ft) (ft) . cc(al1bOft)- ':::' 0.00 0.000 0.000 -52.00 0.00 0.00 N 0.00 E 5974492.75 N 0.00 SHL (1865' FNL & 1527' FEL, SEC - T11 N - R4E) 50.00 0.000 0.000 -2.00 50.00 0,00 N 0.00 E 5974492.75 N 0.00 100.00 0.000 0.000 48.00 100.00 0.00 N 0.00 E 5974492.75 N 0,000 0.00 150.00 0.000 0.000 98.00 150.00 0.00 N 0.00 E 597A492'.75 N 0.000 0.00 200.00 0.000 0.000 148.00 200.00 0.00 N 0.00 E 5~~49Y2~~,5 N 0,000 0.00 250.00 0.000 0.000 198.00 250.00 0.00 N ~~~"º'90 ¡tl¡::;;~~¡$~~~~~2~1~t N 371712.00 E 0.000 0.00 , 300.00 0.000 0.000 248.00 300.00 0.00 N 'öIÚO È:c¡f'j" '¡5974~'92.75 N 371712.00 E 0.000 0,00 Begin Oir @3°/100ft(in 12-1/4" Hoi : 300ft MO, 300ft TVO 350.GC 1,500'" 236,000 297.89 349.99 O.34;1~V 5974492.39 N 371711.45 E 3.CCO 0.53 400,00 3.000 236.000 347.95 399.95 2.17W 5974491.32 N 371709.81 E 3.000 2,10 450.00 4.500 236.000 397.85 449.85 4.88 W 5974489.54 N .371707.06 E 3.000 4.73 500.00 6.000 236.000 447.63 8.67W 5974487.05 N 371703.23 E 3.000 8.40 550.00 7.500 236.000 497.29 13.55 W 5974483.85 N 371698.30 E 3,000 13.11 600.00 9.000 236.000 546,77 19.49 W 5974479.94 N 371692.28 E 3.000 18.87 650.00 1 0.500 236.000 596.0~~,," 26.51 W 5974475.32 N 371685.18 E 3.000 25.67 700.00 12.000 236.000 645.08·-:\~'. 34.60 W 5974470.01 N 371677.01 E 3.000 33.50 750.00 13.500 236.000.~~;':-'69'3.85.. .... 745.85 29.51 S 43.75 W 5974463.99 N 371667.75 E 3.000 42.35 800.00 15.000 23f?OO.0 "1tii42:31~'!\/ 794.31 36.39 S 53.95 W 5974457.29 N 371657.43 E 3.000 52.23 850.00 16.500 236'..000 . ".i~0.43 842.43 43.98 S 65.20 W 5974449.89 N 371646.05 E 3.000 63.12 900.00 18 .000~~~236.000 . "838.18 890.18 52.27 S 77.49 W 5974441.81 N 371633.62 E 3.000 75.02 950,00 19.500 236:ÒOOc, 885.52 937.52 61.26 S 90.82 W 5974433.06 N 371620.15 E 3.000 87.92 1000.00 21.000 '236.000 932.43 984.43 70.93 S 105.17 W 5974423.62 N 371605.64 E 3.000 101.81 1 050. 02E,~-;~."_~22"êP 0'-:;;,\ 2 36.000 978,87 1030.87 81.30 S 120.52 W 5974413,53 N 371590.10 E 3.000 116.68 .. 1 072.9~4¡( 23.188 \:~-;236.000 1000.00 1052.00 86.27 S 127,90 W 5974408.68 N 371582.64 E 3.000 123.83 West Sak 1100.0ÓJ:1s" 24.000 236.000 1024.81 1076.81 92.33 S 136.89 W 5974402.77 N 371573.55 E 3.000 132.52 1150.00 25.500 236.000 1070.22 1122.22 104.04 S 154.24 W 5974391.37 N 371556.00 E 3.000 149.32 1200.00 27.000 236.000 1115.06 1167.06 116.40 S 172.57 W 5974379,32 N 371537.46 E 3.000 167.07 1250.00 28.500 236.000 1159.31 1211.31 129.42 S 191.87 W 5974366,63 N 371517.94 E 3.000 185.76 .... 1300.00 30.000 236.000 1202.93 1254.93 143.08 S 212.13W 5974353.32 N 371497.46 E 3.000 205.36 1350.00 31 .500 236.000 1245.90 1297.90 157.38 S 233.32 W 5974339.39 N 371476.02 E 3.000 225.88 1400.00 33.000 236.000 1288.18 1340.18 172.30 S 255.44 W 5974324.85 N 371453.65 E 3.000 247.30 21 July, 2003 - 12:29 Page 3 of 15 DrillQuest 3.03.02.002 2600.00 2650.00 2700.00 2722.67 2750.00 54.000 54.000 54.000 54.000 54.000 230.000 230.000 230.000 230.000 230.000 2088.90 2118.29 2147.67 2161.00 2177.06 2140.90 2170.29 2199.67 2213.00 2229.06 699.96 S 725.96 S 751.96 S 763.75 S 777.96 S 961.16 W 992.14 W 1023.13 W 1037.18 W 1054.12 W 5973809.34 N 5973783.87 N 5973758.41 N 5973746.86 N 5973732.94 N 370739.01 E 370707.58 E 370676.16 E 370661 .91 E 370644.73 E 928.15 957.91 987.68 1001.18 C-40 1017.45 0.000 0.000 0.000 0.000 0.000 2150.00 53.376 231.161 '? 2187.49 54.000 230.000 .~' 2200.00 54.000 23bl!õðb::~1Î:. 2250.00 54.000~':~~2jÔ~000 ,~:~ 2300.QO,1';. 54:000· ·412'3d:óOo:s';·:· .;¡';, ¡.;~ .~ 2350.Q'Q\·~?§.~..OÒ'Ó~~2-30.odéf· 2400.dq-\,!,:1tf5a!lô00~.A. 230.000 2450.0Ø~t~f"" 54:0'00 9230.000 2500.0Ó}U' 54.000 230.000 2550.00 54.000 230.000 1941.95 1971.34 2000.73 2030.12 2059.51 1993.95 2023.34 2052.73 2082.12 2111.51 569.95 S 595.95 S 621 .95 S 647.95 S 673.95 S 806.22 W 837.21 W 868.19 W 899.18 W 930.17 W 5973936.68 N 5973911.21 N 5973885.74 N 5973860.28 N 5973834.81 N 370896.15 E 370864.72 E 370833.29 E 370801.86 E 370770.44 E 0.000 0.000 0.000 0.000 0.000 779.32 809.08 838.85 868.62 898.38 -" 1905.78 1935.17 1964.56 491 .94 S 517.95 S 543.95 S 370990.43 E 370959.00 E 370927.57 E 5974013.08 N 5973987.61 N 5973962.15 N 713.26 W 744.25 W 775.23 W 690.02 719.79 749.55 0.000 0.000 0.000 End Dir, Start Sail @ 54.000° : 2187.49ftMD,1898.43ftTVD 1719.30 1752.27 1784.24 'I;'. :..:. ~.J . . ."- -"J _..181:k:44··"':. .;'J 418.19 S -';::-184'~~11 '. ,-"'::'- '.- 441.65 S ""~ 466.26 S 485.44 S 660.14 682.57 371021.95 E 370998.29 E 682.17 W 705.50 W 3.000 3.000 5974038.23 N 5974019.45 N 2050.00 2100.00 51.770 52.562 234.352 232.740 618.98 W 650.74 W 599.21 629.87 3.000 3.000 371085.95 E 371053.80 E 5974148.40 N 5974127.92 N 5974106.97 N 5974085.21 N 5974062.29 N Continue Dir @ 3.0000/100ft : 2000.00ftMD,1784.24ftTVD 1900.00 1950.00 -, 2000.00 48.000 49.500 51.000 236.000 236.000 236.000 1667.30 1700.27 1732.24 507.18 537.35 568.20 3.000 3.000 3.000 371182.15 E 371150.63 E 371118.40 E -r 1700.00 1732.62 1750.00 1800.00 185Û.OO 42.000 42.979 43.500 45.000 46.500 236.000 236.000 236.000 236.000 236.0ae 1525.95 1550.00 1562.66 1598.47 1633;3ô . 1577.95 1602.00 1614.66 1650.47 , 1685.36- 274.32 S 286.64 S 293.29 S .; 312.80 S'~; "'.83 8~: 393.72 411.41 420.96 448;96 477.71 3.000 3.000 3.000 3.000 -3.aOO 371300.68 E 371282.20 E 371272.22 E 371242.97 E 371212,;94 E ' Permafrost ~ 5974309.71 N 5974293.99 N 5974277.69 N 5974260.82 N 5~7A;~~~~0 N 1450.00 - 1500.00 1550.00 1600.00 1650.00 34.500 36~00 37.500 39~00 40.500 236.000 236.000 236.000 236.000 236.000 1329.76 1370.59 1410.65 1449.91 1488.35 1381.76 1422.59 1462.65 1501.91 1540.35 .,' ,. .' "'~' ,~- " J :.' /,:t"'~>;'" , ~.' '., . .;;~F"" .~:':' ',,', Dogf.~g è; ::': '.yér;ti?af :' "'if\i1~"1!..$~eiit'ôn . ";l,$~boo 269.59 .000 292.75 .000 316.76 3.000 341.60 3.000 367.26 187.83 S 203.97 S 220.69 S 238.00 S 255.88 S 278.47 W 302.39 W 327.19 W 352.85 W 379.36 W Measured Depth (ft) Sub-Sea Depth (ft) Local Coordinates Northlngs Eastlngs (ft) (ft) . Vertical Depth (ft) Global Coordinates Northlngs Eastlngs (ft) (ft) Incl. Azlm. Alaska North Slope North Slope, Alaska Sperry-Sun Drilling Services Proposal Report for CD2-30 (wp05) Revised: 21 July, 2003 DrillQuest 3.03.02.002 Page 4 of 15 21 July, 2003 - 12:29 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg --.<Vertlcal Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs ··,Rate· . Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) ~ (á11 OOft) ~ ~ì ,. 2800.00 54.000 230.000 2206.45 2258.45 803.96 S 1085.10 W 5973707.47 Nt~370~~tì.3tl~ ~};\º:OOO 1047.21 2850.00 54.000 230.000 2235.84 2287.84 829.968 1116.09 W 5973682.00 N ~l '~(!S~5'tt~~~i~ ;~J;~*:10.000 1076.98 2900.00 54,000 230.000 2265.23 2317.23 855.968 1147.08 W 5973656.54 N ~tt4, 37Q~QA'5IE' if¡;b.ooo 1106.74 2950.00 54.000 230.000 2294.62 2346.62 881.96 S 1178.07 W 5973631.07 N \~~+_ 37Ò&~9:^02'E 0.000 1136.51 3000.00 54.000 230.000 2324.01 2376.01 907,978 1209.05 W 59?3S05~60 N <{~tßZ048'7,59 E 0.000 1166.28 ... 3023.80 54.000 230.000 2338.00 2390.00 920.348 1223.80 W- "5973593:48,N 370472.63 E 0.000 1180.44 9-5/8" Csg Pt... Drill out 8-1i2" Hole r-::~ 3024 ft MD, 2390 ft TVD -' ..:.j\ -. -.~- 5973580.14 N 9 5/8" Csg Pt 3050.00 54.000 230.000 2353.40 2405,.40 933.978 . 1240.'o4W- 370456.16 E 0.000 1196.04 3057.83' . 54.000 230.00e - - 2353:CO . 241 O~Gg... .- a ~~!::'!:: 5873576.15 N 370451.24 E ... 0.000 . 1Z00 .70 Cø-3û--> 3100.00 54.000 230.000 2382.79 2434.79 5973554.67 N 370424.74 E 0.000 1225.81 3150,00 54.000 230.000 2412.18 2464.18 5973529.20 N 370393.31 E 0.000 1255.57 3200.00 54.000 230,000 2441 .57 2493.5?:.~:;';:.~ . 5973503.73 N 370361.88 E 0.000 1285.34 3250.00 54.000 230.000 2470.96 2522.9EE:; 1'03c'î!f97 S 1363.99 W 5973478.27 N 370330.45 E 0.000 1315.11 3300.00 54.000 230.000 2500.35 _.2552~355~c- 1063.97 S 1394.98 W 5973452.80 N 370299.03 E 0.000 1344.87 3350.00 54.000 230.000 2529.79."". .' <~25ßf;73 . 1089.97 S 1425.96 W 5973427.33 N 370267.60 E 0.000 1374.64 3400.00 54.000 230.000 2559;fi~~~", 2'sliÙ2 1115.98 S 1456.95 W 5973401.86 N 370236.17 E 0.000 1404.40 . ~~~~~. ~':~;:.~{ " ~~~~ <.,~¥* 3450.00 54.000 230.000 :'::~"258&~·5J~~¿,.K~ 2640.51 1141.98 S 1487.94 W 5973376.40 N 370204.74 E 0.000 1434.17 3500.00 54.000 230.007o-:.-~.. \1~.61i:WÒ;;W<Y 2669.90 1167.988 1518.92W 5973350,93 N 370173.32 E 0.000 1463.94 3550.00 54.000 23b.ooö<';'(2ß~7.29 2699.29 1193.98 8 1549,91 W 5973325.46 N 370141.89 E 0.000 1493.70 3600,00 54.000.' - 23'0;000\2 2'676.68 2728.68 1219.988 1580.90 W 5973299.99 N 370110.46 E 0.000 1523.47 3650.00 54.000 230.000"; - 2706.07 2758.07 1245.98 S 1611.89 W 5973274.53 N 370079,03 E 0.000 1553.23 - - 3697.52 54.000 230.000 2734.00 2786.00 1270.69 8 1 641 .33 W 5973250.32 N 370049.17 E 0.000 1581.52 C-20 3700.08¡!f' '54.0PO \.:~230.000 2735.46 2787.46 1271.988 1642.87 W 5973249,06 N 370047.61 E 0.000 1583.00 3750.00)j:i:¡" 54.600 \>'230.000 2764.85 2816.85 1297.99 S 1673.86 W 5973223.59 N 370016.18 E 0.000 1612.77 3800.0Q'{: 54.000 230.000 2794.24 2846.24 1323.99 8 1704.85 W 5973198,12 N 369984.75 E 0,000 1642.53 3850.00 54.000 230.000 2823.63 2875.63 1349.99 8 1735.83 W 5973172.66 N 369953.32 E 0.000 1672.30 3900,00 54.000 230.000 2853.02 2905.02 1375.998 1766.82 W 5973147,19 N 369921.90 E 0.000 1702.06 3950.00 54.000 230.000 2882.41 2934.41 1401.998 1797.81 W 5973121.72 N 369890.47 E 0.000 1731.83 4000.00 54.000 230.000 2911 .80 2963.80 1427.998 1828.80 W 5973096.26 N 369859.04 E 0.000 1761.59 4050.00 54.000 230.000 2941 .1 8 2993.18 1453.99 S 1859.78 W 5973070.79 N 369827.61 E 0.000 1791 .36 4100.00 54.000 230.000 2970.57 3022.57 1479.99 8 1890,77 W 5973045,32 N 369796,19 E 0.000 1821.13 Sperry-Sun Drilling Services Proposal Report for CD2-30 (wp05) Revised: 21 July, 2003 21 July, 2003 - 12:29 Page 5 of 15 Dri/lQuest 3.03.02.002 2714.11 2743.87 2773.64 2803.40 2833.17 0.000 0.000 0.000 0.000 0.000 368853.36 E 368821.93 E 368790.51 E 368759.08 E 368727.65 E 5972281.30 N 5972255.83 N 5972230.37 N 5972204.90 N 5972179.43 N 5600.00 5650.00 5700.00 5750.00 5800.00 2820.38 W 2851.37 W 2882.36 W 2913.35 W 2944.33 W 3852.25 3881.64 3911 .03 3940.42 3969.81 230.000 230.000 230.000 230.000 230.000 54.000 54.000 54.000 54.000 54.000 2260.03 S 2286.03 S 2312.04 S 2338.04 S 2364.04 S 3904.25 3933.64 3963.03 3992.42 4021.81 2595.04 2624.81 2654.57 2657.13 K-3 Marker 2684.34 0.000 0.000 0.000 0.000 0.000 368979.07 E 368947.64 E 368916.22 E 368913.52 E 368884.79 E 5972383.17 N 5972357.70 N 5972332.24 N 5972330.05 N 5972306.77 N 2696.44 W 2727.42 W 2758.41 W 2761.07 W 2789.40 W 2156.03 S 2182.03 S 2208.03 S 2210.27 S 2234.03 S 3786.69 3816.08 3845.47 3848.00 3874.86 3734.69 3764.08 3793.47 3796.00 3822.86 54.000 54.000 54.000 54.000 54.000 5400.00 5450.00 5500.00 5504.30 5550.00 230.000 230.000 230.000 230.000 230.000 54.000 230.000 54.000 230.000 54.000 230.000 54.000 230.000: 54.000 2Sêt:ÕOÒ ,.; :~:;¡>~h ~~" .<'. 5150.00 54:00'6 <230':OOó"5.' 5200.00:':. ,54.ÒOO". .230.00Q 5250.0'0 :54.oM:.',:. ~230.odO' 5300.00.: '54.000': '-;":. 230,000 5350.0(j~f:--· 54.000Yii"230.000 ~~r;. 2446.21 2475.98 2505.74 2535.51 2565.28 0.000 0.000 0.000 0.000 0.000 369136.21 E 369104.78 E 369073.35 E 369041.93 E 369010.50 E 5972510.51 N 5972485.04 N 5972459.57 N 5972434.10 N 5972408.64 N 2541.50 W 2572.49 W 2603.47 W 2634.46 W 2665.45 W 2026.02 S 2052.02 S 2078.02 S 2104.03 S 2130.03 S 3639.75 3669.14 3698.53 3727.92 3757.31 3587.75 3617.14 3646.53 3675.92 3705.31 '~ 2297.38 2327.15 2356.91 2386.68 2416.45 0.000 0.000 0.000 0.000 0.000 369293.35 E 369261 .92 E 369230.49 E 369199.06 E 369167.64 E 5972637.84 N 5972612.38 N 5972586.91 N 5972561.44 N 5972535.97 N 2386.56 W 2417.55 W 2448.54 W 2479.53 W 2510.51 W 1896.02 S 1922.02 S 1948.02 S 1974.02 S 2000.02 S 3345.86 3375.25 3404.63···., 3434,02:"" .~46.~.!~ t . ,Jlo 352"2:1'9 ;V 3551.58 3580.97 3610.36 4900.00 4950.00 5000.00 5050.00 5100.00 2148.55 2178.32 2208.08 2237.85 2267.62 0.000 0.000 0.000 0.000 0.000 369450.48 E 369419.06 E 369387.63 E 369356.20 E 369324.77 E 5972765.18 N 5972739.71 N 5972714.25 N 5972688.78 N 5972663.31 N 231.63 W 2262.62 W 2293.60 W 2324.59 W 2355.58 W 3293.86 3323.25 3352.63 3382.02 3411.41 230.000 230.000 230.000 230.000 230.000 54.000 54.000 54.000 54.000 54.000 4650.00 4700.00 4750.00 4800.00 4850.00 2076.69 W 2101:68 W '..:~fl3tÜì7 W ' 2tß9.6~·W . .. ; ~2ÖO.64'}V 1999.72 2029.49 2059.25 2089.02 2116.79' .... 0.000 0.000 0.000 0.000 uO.ace· 369607.62 E 369576.19 E 369544.77 E 369513.34 E 359481,S1 E ..~: . - - 59'i.289is.2 N . 5972867.05 N . 5~72841.58 N "5972816.11 N 5972790 .65 ~ ~ . ~ 1636.00 S 1662.00 S 1688.00 S 1.714.01 S', , '·17AO.013 3146.91 3198.91 3176.30 3228.30 3205.69 3257.69 3235.08 3287.08 3264.47' '. 33'1G.47· 230.000 230.000 230.000 230.000 230.000 54.000 54.000 54.000 54.000 54.aOC 4400.00 4450.00 4500.00 4550.00 460a.Ov·· ~ :', "...~ {¡~~;-,.\ '~~\:;: '~',' Global Coordinates Dogt~g <,,vertical./ Northlngs Eastings:,.·";~~t~} '{~e'êtlo¡'" (ft) (ft) . ~:~:g f·/l~tt)"\:;).·';:::" '·f91000 1850.89 .000 1880.66 J.OOO 1910.42 0.000 1940.19 0.000 1969.96 5973019.85 N 5972994.39 N 5972968.92 N 5972943.45 N 597,2917.98 N 1921.76 W 1952.74 W 1983.73 W 2014.72 W 2045.71 W 1506.00 S 1532.00 S 1558.00 S 1584.00 S 1610.00 S 3051.96 3081.35 3110.74 3140.13 3169.52 2999.96 3029.35 3058.74 3088.13 3117.52 230.000 230.000 230.000 230.000 230.000 54.000 54.000 54.000 54.000 54.000 4150.00 4200.00 4250.00 4300.00 4350.00 Local Coordinates Northlngs Eastings (ft) (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Measured Depth (ft) Comment Azlm. Incf. Alaska North Slope North Slope, Alaska Sperry-Sun Drilling Services Proposal Report for CD2~O (wp05) Revised: 21 July, 2003 DrillQuest 3.03.02.002 Page 6 of 15 21 July, 2003 - 12:29 Sperry-Sun Drilling Services Proposal Report for CD2-30 (wp05) Revised: 21 July, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg . Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastings or Rate - :Sectlon (ft) (ft) (ft) (ft) (ft) (ft) (ft) ,,; (Q/1b~ftr \1ft - 5850.00 54.000 230.000 3999.20 4051 .20 2390.04 8 2975.32 W 5972153.96 N ,;:' .. ~685t6,ti~~ '1.;;;,:0.000 2862.94 - 5892.20 54.000 230.000 4024.00 4076.00 2411 .98 8 3001.47 W ;~;~~ ~~:~b ~ i~l:} '~~l:gK~i~i, ':~~~;~:~~~ 2888.06 K-2 Marker 5900.00 54.000 230.000 4028.59 4080.59 2416.04 S 3006.31 W 2892.70 5950.00 54.000 230.000 4057.98 4109.98 2442.048 3037.29 W 5972103.03 N ":~~:Lii,368~~~37 E 0.000 2922.47 6000,00 54.000 230.000 4087.37 4139.37 2468.048 3068.28 W 5:~~07'Z~56 N '1¡:.?fßp8601 .94 E 0.000 2952.23 ·_~-:*'ß~%~,,~. ~·~~~f~· 6050.00 54.000 230.000 4116.76 4168.76 2494.05 8 30~9.27 W·,;c'~9~2052.Ö9N 368570.52 E 0.000 2982.00 6100.00 54.000 230.000 4146.14 4198.14 2520.058 3130:26 W: . ;'59120"26.63 N 368539.09 E 0.000 3011.77 6150.00 54.000 230.000 4175.53 4227.53 2546.05 S":'7r~:~:::'3161~24 Wi: '5972001.16 N 368507.66 E 0.000 3041 .53 6200.00 54.000 230.000 4204.92 4256.92 2572.05 S'I¡ì\~1Ø2.¿~~:þ';;'~)i~,,5971975.69 N 368476.23 E ,0.000 3071.30 6250.00 . '54:000 230.000' 4234;31 4286.31 . 2598.05 8 >~<{i~j'13223:22';:\V 5971950,22 N' P 36G444.Z1 E "'0.000 . ·Sí'01'.06 ~6 ·~ìl;~ ~. . 6300.00 54,000 230,000 4263.70 4315.70<f!ß~~i¡n5 8 "'i~19254.20 W 5971924.76 N 368413.38 E 0.000 3130.83 6350.00 54.000 230.000 4293.09 4345.09 'Zã5õ'tQ~ 8"'3285.19 W 5971899.29 N 368381.95 E 0.000 3160.60 6400.00 54,000 230.000 4322.48 4374.481~~'~cV~~'q76.~~'is 3316.18 W 5971873.82 N 368350.52 E 0.000 3190.36 6450.00 54.000 230.000 4351.87 44Q3.81·~~?~"·~1í'Q'Øô~f8 3347.17 W 5971848.36 N 368319.10 E 0.000 3220.13 6500.00 54.000 230.000 4381 .26 .,A433~28"·>:~u.-;i2728.06 8 3378.15 W 5971822.89 N 368287.67 E 0.000 3249.89 ,~ -"" - . 6550,00 54.000 230.000 4410.i5Š?'=c·4·462:S5 2754.068 3409.14 W 5971797.42 N 368256.24 E 0.000 3279.66 6600.00 54.000 230.000 4440:04 . 4492.04 2780.06 8 3440.13 W 5971771.95 N 368224.81 E 0.000 3309.42 6650.00 54.000 230.000 '-~,'~469~43 ..."'~~ 4521.43 2806.06 8 3471.11 W 5971746.49 N 368193.39 E 0.000 3339.19 6700,00 54.000 2~p,.OO'O~ ·\'JIª498.'a'2'su· 4550.82 2832.068 3502.10 W 5971721.02 N 368161.96 E 0.000 3368.96 6750.00 54.000 230~000· '~28.20 4580.20 2858.068 3533.09 W 5971695.55 N 368130.53 E 0.000 3398.72 :,..- "j'f"¡' -- 54.DOC 230.000 4557.59 4609.59 2884.06 S 3564.08 W 5971670.08 N 368099.10 E 0.000 3428.49 .54.0002jO.ÒOÖ 4586.98 4638.98 2910.078 3595.06 W 5971644.62 N 368067.68 E 0.000 3458.25 4.0ÖQ,... '230.000 4616.37 4668.37 2936.078 3626.05 W 5971619.15 N 368036.25 E 0.000 3488.02 o"'\i_~h\230.000 4645.76 4697.76 2962.07 8 3657.04 W 5971593.68 N 368004.82 E 0.000 3517.79 54.000 230.000 4675.15 4727.15 2988.078 3688.02 W 5971568.21 N 367973.39 E 0.000 3547,55 7050.00 54.000 230.000 4704.54 4756.54 3014.07 8 3719.01 W 5971542.75 N 367941 .97 E 0.000 3577.32 7100.00 54,000 230.000 4733.93 4785.93 3040.078 3750,00 W 5971517.28 N 367910.54 E 0.000 3607.08 7150.00 54.000 230.000 4763.32 4815.32 3066.07 S 3780.99 W 5971491.81 N 367879.11 E 0.000 3636.85 7200.00 54.000 230.000 4792.71 4844.71 3092.08 8 3811.97W 5971466.35 N 367847.68 E 0.000 3666.62 7250.00 54.000 230.000 4822.10 4874.10 3118.088 3842.96 W 5971440.88 N 367816.26 E 0.000 3696.38 7300.00 54.000 230.000 4851.49 4903.49 3144.088 3873.95 W 5971415.41 N 367784.83 E 0.000 3726.15 7350.00 54.000 230.000 4880.88 4932.88 3170.088 3904.93 W 5971389.94 N 367753.40 E 0.000 3755.91 7400.00 54.000 230.000 4910.27 4962.27 3196.088 3935.92 W 5971364.48 N 367721 .97 E 0.000 3785.68 7450.00 54.000 230.000 4939.65 4991.65 3222.08 8 3966.91 W 5971339.01 N 367690.55 E 0.000 3815.45 7500.00 54.000 230.000 4969.04 5021.04 3248.088 3997.90 W 5971313.54 N 367659.12 E 0.000 3845,21 21 July, 2003 - 12:29 Page 7 of 15 DriJ/Quest 3.03.02.002 8750.00 54.000 230.000 5703.78 5755.78 3898.12 S 8800.00 54.000 230.000 5733.16 5785.16 3924.12 S 8850.00 54.000 230.000 5762.55 5814.55 3950.12 S 8900.00 54.000 230.000 5791.94 5843.94 3976.12 S 8950.00 54.000 230.000 5821.33 5873.33 4002.12 S 9000.00 54.000 230.000 5850.72 5902.72 4028.12 S 9050.00 54.000 230.000 5880.11 5932.11 4054.12 S 9075.33 54.000 230.000 5895.00 5947.00 4067.30 S 9100.00 54.000 230.000 5909.50 5961.50 4080.12 S 9150.00 54.000 230.000 5938.89 5990.89 4106.13 S 41 ~i.82 ¥'{~t~:,¥~§g1l.û 60:7.~N 367470.55 E 0.000 4023.81 42~4!a 1 tJj). 4~~,5.~71tt,?5.27 N 367439.13 E 0.000 4053.57 ~~~',.µ.;j?~1109.80 N. _ 367407.70 E 0.000 4083.34 ,,,,~ . 6. \'~ '$;¡~/}/5971 084.33 N 367376.27 E 0.000 4113.11 ,·:;'3f:,7·.7::;:~V 5971 058Æ7 N'''' 3673:44;tH E -." O.COO '41·42;07 5971 033.40 N 367313.42 E 0.000 4172.64 5971007.93 N 367281.99 E 0.000 4202.40 5970982.47 N 367250.56 E 0.000 4232.17 5970973.89 N 367239.98 E 0.000 4242.19 Albian 97 5970957.00 N 367219.13 E 0.000 4261.94 4462.70 W 5970931.53 N 367187.71 E 0.000 4291.70 4493.69 W 5970906.06 N 367156.28 E 0.000 4321.47 4524.68 W 5970880.60 N 367124.85 E 0.000 4351.23 4555.66 W 5970855.13 N 367093.42 E 0.000 4381.00 4586.65 W 5970829.66 N 367062.00 E 0.000 4410.77 4617.64 W 5970804.19 N 367030.57 E 0.000 4440.53 4648.63 W 5970778.73 N 366999.14 E 0.000 4470.30 4679.61.W 5970753.26 N 366967.71 E 0.000 4500.06 4710.60 W 5970727.79 N 366936.29 E 0.000 4529.83 4741.59 W 5970702.32 N 366904.86 E 0.000 4559.60 4772.57 W 5970676.86 N 366873.43 E 0.000 4589.36 4803.56 W 5970651.39 N 366842.00 E 0.000 4619.13 4834.55 W 5970625.92 N 366810.58 E 0.000 4648.89 4865.54 W 5970600.46 N 366779.15 E 0.000 4678.66 4896.52 W 5970574.99 N 366747.72 E 0.000 4708.42 4927.51 W 5970549.52 N 366716.29 E 0.000 4738.19 4958.50 W 5970524.05 N 366684.87 E 0.000 4767.96 4974.20 W 5970511.15 N 366668.95 E 0.000 4783.04 Albian 96 4989.48 W 5970498.59 N 366653.44 E 0.000 4797.72 5020.47 W 5970473.12 N 366622.01 E 0.000 4827.49 5344.33 5373.71 ;:~;;6~~:~:;~~.;~ 3ãØ86 S .",,543~49.,.¡r-.;.,.... ..',m~~ 3612.1 0 S ...W'~ "'~ "">,.."~'.' 54.000 230.000 540~~~t4.,i~:-]~~'\8~<l:~;';;'- 3638.10 S 54.000 230.000 ,5~3~@7,.~ 5491':27 3664.10 S 54.000 230.000 ·(~~fŠ46~à6..,1i¥ 5520.66 3690.11 S 54.000 23,O,«1<ri\. ~98:ð'~'; 5550.05 3716.11 S 54.000 23.9pOO~~~fl \\~7 .44 5579.44 3742.11 S ~'.,: "~';_- : '. x.rØ> ~j~~'fi:¡ 8500.00~, 54:()bg~'::' ::~~3Ò~~~:;~.' 8550.b(f!~¡:;...54.ÒÓÔ.. 2~0.óóð.:; 8600.ÒÕ:¡ ·"1:54.0ób·~r~230.0ÒÔ'" ...~ ,,';'~Ij;~ ~,' 8650.0Q"":£t1v~\q90 ¿~ 230.000 8700.0~'r 54.ÕOO ·v230.000 5556.83 5586.22 5615.61 5645.00 5674.39 5608.83 5638.22 5667.61 5697.00 5726.39 3768.11 S 3794.11 S 3820.11 S 3846.11 S 3872.11 S - 8250.00 8300.00 8350.00 8400.00 8450.00 8050.00 8100.00 8150.00 , 8166.84 8200.00 54.000 54.000 54.000 54.000 54.000 230.000 230.000 230.000 230.000 230.000 5292.33 5321.71 5351.10 5361.00 5380.49 Alaska North Slope Measured Sub-Sea Vertical Depth Inel. Azlm. Depth Depth (ft) (ft) (ft) 7550.00 54.000 230.000 4998.43 5050.43 7600.00 54.000 230.000 5027.82 5079.82 7650.00 54.000 230.000 5057.21 5109.21 7700.00 54.000 230.000 5086.60 5138.60 7750.00 54.000 230.000 5115.99 5167.99 7800.00 54.000 230.000 5145.38 5197.38 7850.00 54.000 230.000 5174.77 5226.77 7900.00 54.000 230,000 5204.16 5256.16 7950.00 54.000 230.000 5233.55 5285.55 8000.06 . -54.000'" 230:.000 .... 526:Z.B4·-"· -~GS~'4;94 .--- 5971288.07 N 5971262.61 N 5971237.14 N 5971211.67 N 59?.J.it8ß~0 N 3274.08 S 3300.09 S 3326.09 S 3352.09 S 3378.09 S 4028.88 W 4059.87 W 4090.86 W 4121.84 W 4152.83 W )>" ,,,,,<. r{t:~tq!:: ....' {i!¡i~,~$~¿~g~~ Global Coordinates Dogl~g '~:,}{er~~eJ~t( Northlngs Eastlngs "":?GR,å'~1~. <.t,Seêtlori (ft) (ft) ~ l:;{f~ß ·("Î\~~fi):~~~.~~r >~~º:'ooo 3874.98 3904.74 3934.51 3964.28 3994.04 Local Coordinates Northlngs Eastings (ft) (ft) North Slope, Alaska Sperry-Sun Drilling Services Proposal Report for CD2-30 (wp05) Revised: 21 July, 2003 DríllQuest 3.03.02.002 5753.37 5782.34 5809.74 Base HRZ 5810.17 5836.78 E:nd Sail; Beg:n Dir @-65°/100ft : 9633 ft MD,6275 ft TVD st:~,.,. + \Ñ / GeD P; 10-1 I fQ (( S"'" (.. ø.,. :3 S-o ~ I ~.~ -\t Í1 ~ ~ . 'S' Q Á \)0 { COmment North Slope, Alaska 5628.12 5660.64 5672.89 HRZ 5692.43 5723.37 5458.10 5492.73 5527.15 5561.26 5594.96 5285.88 5319.83 5354.14 5388.70 5423.39 5125.20 5155.78 5187.23 5219.47 5252.39 5006,08 5035.85 5065.62 5095.38 511'3.2-1 ' 4857.25 4887.02 4916.79 4946.55 4976.32 6.500 6.500 6.500 6.500 6.500 6,500 6,500 6.500 6.500 6,500 6.500 6.500 6.500 6.500 6.500 6.500 6,500 6.500 6.500 6.500 6ßOO 6ßOO 6ßOO 6ßOO 6ßOO 0.000 0.000 0.000 0.000 0.000 . 365679.48 E 365652.21 E 365626.60 E 365626.21 E 365601 .57 E 365799.58 E 365768.10 E 365756.30 E 365737.53 E 365707.95 E 365966.96 E 365932.51 E 365898.44 E 365864.86 E 365831.87 E 366140.96 E 366106.30 E 366071.46 E 366036.54 E 366001.67 E 366307.69 E 366275.58 E 366242.75 E 366209.30 E 366175.33 E ..._0 E 6464.88 E }'~~i' 366433.45 E 366402.02 E 366370.59 E 366339.17 E 3$631e.20 E 5970237.75 N 5970265.41 N 5970294.88 N 5970295.37 N 5970327.54 N 5970151.84 N 5970169.47 N 5970176.90 N 5970189.70 N 5970212.49 N 5970104.60 N 5970108.48 N 5970115.17N 5970124.65 N 5970136.88 N 5970127.45 N 5970117.28 N 5970109.89 N 5970105.30 N 5970103.54 N 5970218.58 N 5970195.17 N 5970174.28 N 5970156.00 N 5970140.37 N . 5970226.82' N .5étð320·:l~... N ··S970294.ä5 N 5970269.38 N c5970243.91 N Dogleg ~Vertical 7~.ate:," SectIon (~I~OOft)· 5970447.65 N~0 5970422.18 N ~#¡ 5970396.72 Ni 5970371.25 N 597.034528 N .- ~= .~-..;; Global Coordinates Northlngs Eastlngs (ft) (ft) Page 8 of 15 5958.84 W 5986.58 W 6012.69 W 6013.09 W 6038.28 W 5837.29 W 5869.06 W 5880.99 W 5899.98 W 5929.94 W 5669.12 W 5703.63 W 5737.81 W 5771.55 W 5804.75 W 5495.54 W 5530.02 W 5564.73 W 5599.56 W 5634.40 W . 5330.39 W 5362.09 W 5394.56 W 5427.70 W 5461.39 W 5206.39 '!k~' _ c523?~38 W ~268~37 W', 5299.3SW . . -: ~t320~0~\V 5051.46 W 5082.45 W 5113.43 W 5144.42 W 5175.41 W 4357.588 4330.408 4301.368 4300.88 8 4269.148 4441.43 S 4424.34 8 4417.11 8 4404.63 8 4382.35 8 4485.80 8 4482.51 8 4476.408 4467.50 8 4455.83 S 6935.57 6967.04 6997.00 6997.47 7026.75 6801.32 6835.93 6849.00 6869.91 6903.16 6622.90 6658.92 6694.89 6730.69 6766.20 6883.57 6915.04 6945.00 6945.47 6974.75 6749.32 6783.93 6797.00 6817.91 6851.16 6570.90 6606.92 6642.89 6678.69 6714.20 312.527 316.260 319.785 319,839 323,270 296.083 300.409 302.028 304.598 308.640 50.271 51.737 53.291 53.316 54.999 45.765 46.665 47.052 47.724 48.929 21 July, 2003 - 12:29 10600.00 10650.00 10699.22 10700.00 10750.00 10400.00 10450.00 10469.12 ... 10500.00 10550.00 10150.00 43.929 273.106, 10200.00 '43.921: "277.792' 1 0250.0Q..~44;i05 :·~;282 .462 1 0300.0~it~·~ 44:477 ii0}f287,087 10350.0Qj)4ò 45.032 291.635 6232.85 6284.85 6263,18 6315.184~_-:?-~~. 6294.57 6346.5l_, ,.;,-:~Y" 44lTI1Ñ41 S 6326,91 ~~631?ì9h:'?..."(? 4430.268 6360.1~q< -~_?}\r?;'10 ~.<'. - 4446.478 .F~~~·-·"~;~;~ -.:~th~ .. ß3g4~'Ò3>: 644'6:03 4459.97 S ";'1--6428;~J)._j.;.:' 6480.59 4470.74 S -. "6463:61,"" 6515.67 4478.728 6551.16 4483.91 8 6586.94 4486.278 4262.138 4288.148 4314.148. 4340.148 ····4ßZ7.498 4132.13 S 4158,138 4184.138 4210.13 S 4236.13 8 Local Coordinates Northlngs Eastlngs (ft) (ft) Sperry-Sun Drilling Services Proposal Report for CD2-30 (wp05) RevIsed: 21 July, 2003 6167.22 6196.61 6226.00 6255.39 '.' 3275:00 . -- 6020.28 6049.67 6079.06 6108.45 6137.84 Vertical Depth (ft) 6115.22 6144.61 6174.00 6203.39 6223;.Ca . , 5968.28 5997.67 6027.06 6056.45 6085.84 Sub-Sea Depth (ft) 231,154 234.721 238.441 242.317 246.346 230.000 230.000 230.000 230.000 230.080· 230.000 230.000 230,000 230.000 230.000 Azlm. ~- . 46.745 45.831 45.085 44.515 44.128 . 53.448 51.860 50.384 49.032 47.815 54.000 54.000 54.000 54.000 54.aOe· 54.000 54.000 54.000 54.000 54.000 Incl. 9900.00 9950.00 ~ 10000.00 10050.00 10100.00 9650.00 9700.00 9750.00 9800.00 9850.00 9450.00 9500.00 9550.00 9600.00 . 9633:36'" 9200.00 9250.00 9300.00 9350.00 9400.00 Measured Depth (ft) Alaska North Slope Alaska North Slope Measured Depth (ft) 10794.91 10800.00 10850.00 -10874.31 10900.00 10950.00 10968.38 11000.00 11050.00 ·-11079.8~ 11100.00 11150.00 11170.72 11200.00 11201 .80 11216.38 11250.00 11270.09 11300.00 11350.00 11400.00 :. 11450.00 11500.00' 11550.00 11562.73;"-\ Incl. 56.589 56.773 58.631 59.562 60.563 62.561 63.311 64.618 66.726 . Sa.COB 68.005 68.005 68.005 68.005 68.005 326.231 326.559 329.714 331 .202 332.745 335.660 336.705 338.470 341.185 . 24~·..763 .... 342.763 342.763 342.763 342.763 342.763 68.852 70.811 71.983 73.733 76:~~~_\~~, "\\'~','i; " 79.6Q'?;.. ~,·3.~6.g1à . 82.55'..ty;:·c335.53l . 85;505 'i; :::. 334.162 88.459 .. '332.804 89.211 332.459 11583.71 89.211 332.459 -- 11583.75 89.211 332.459 11584.00 89.211 332.459 11600.00 89.228 332.449 11650.00 89.280 332.417 21 July, 2003 - 12:29 Azlm. Sub-Sea Depth eft} 7000.00 7002.80 7029.52 7042.00 7054.82 7078.64 7087.00 7100.88 7121.48 7132·.a,e,~ . Sperry-Sun Drilling Services Proposal Report for CD2-30 (wp05) Revised: 21 July, 2003 North Slope, Alaska ~'W~;"> " ",'" c, ,; Vertical Local Coordinates Global Coordinates Dogr~g··::yér.tica¡ :' Depth Northlngs Eastings Northings Eastlngs, .~+:~ijåié;~\ ';'$e~J6rt Comment eft} eft} eft} . eft} eft} s:::,:~f~' (O~~:~ftb ¡,;::),' 7052.00 4238.81 S 6059.70 W 5970358.23 N:¡.i:p';Soo 5859.56 K-1 Marker 7054.80 4235.27 S 6062.05 W 5970361.82 N .500 5862.08 7081.52 4199.38 S 6084.35 W 5970398.08 N .500 5885.99 7094.00 4181.23 S 6094.63 W 5970416.40 N 6.500 5897.09 Kuparuk Fm 7106.82 4161.58 S 6105.09 W 597~.23 N 6.500 5908.44 7130.64 4122.00 S 21 'I;!!i,;t:' ?"~~1;¿~1å"N 365518.16 E 6.500 5929.35 7139.00 4107.02 S 2 W . 97Ö~91.22 N 365511.81 E 6.500 5936.64 LCU- Miluveach 7152.88 4080.76 S 5 W;~{, ; ~705<17.66 N 365501.43 E 6.500 5948.65 7173.48 4038.00 ~:':'?~:S970560.69 N 365486.47 E 6.500 5966.29 -7184.~$.· .... . -4"~ ~ .83 S· 5970537~'()O N365478.4C ES;500 5975.99 ," 7192.51 7211.24 7219.00~~· 722.9.97~:l, ,.â·;} 0 S 72~£4ri:C' 'f'~< 3903.80 S .,~..;.; ''': i"lf~~~>'~' )1¡:~£~} ~~~ùg \:tI202X"O':~;" 7254.00 \fAit 0.82 7262.82 7223.59 7275.59 7140.51 7159.24 7167.00 7177.97 7178.64 7233.87 7241.62 7246.82 7249.45 7249.71 ' 7250.00 7250.00 7250.00 7250.22 7250.87 3890.87 S 3860.90 S 3842.90 S 3816.00 S 3770.86 S 7285.87 7293.62 7298.82 7301.45 7301.71 3725.62 S 3680.43 S 3635.42 S 3590.75 S 3579.44 S 7302.00 7302.00 3560.84 S 3560.81 S 7302.00 3560.59 S 7302.22 7302.87 3546.40 S 3502.08 S 6203.45 W 6213.31 W 6219.52 W 6229.19 W 6246.47 W 6265.10 W 6285.01 W 6306.15 W 6328.44 W 6334.29 W 6343.99 W 6344.01 W 6344.12 W 6351.52 W 6374.66 W Page 9 of 15 5970604.96 N 5970649.47 N 5970667.91 N 5970693.98 N 5970695.58 N 5970708.58 N 5970738.72 N 5970756.82 N 5970783.88 N 5970829.31 N 5970874.86 N 5970920.39 N 5970965.75 N 5971010.80 N 5971022.20 N 5971040.96 N 5971041.00 N 5971041 .22 N 5971055.53 N 5971100.24 N 365473.16 E 365460.19 E 365454.81 E 365447.21 E 365446.74 E 365442.89 E 365433.54 E 365427.64 E 365418.43 E 365401.93 E 365384.08 E 365364.94 E 365344.58 E 365323.06 E 365317.40 E 365308.02 E 365308.00 E 365307.89 E 365300.73 E 365278.36 E 0.000 0.000 0.000 0.000 0.000 6.500 6.500 6.500 6.500 6.500 6.500 6.500 6.500 6.500 6.500 5982.35 5998.10 6004.62 6013.85 6014.41 6019.07 6030.29 6037.32 6048.21 6067.53 6088.21 6110.17 6133.34 6157.65 6164.01 --' Miluveach A Continue Dir @ 6.500°/1 o Oft : 11201.80ftMD,7230.64ftTVD Alpine 0 Alpine C -~ 0.000 6174.55 ~ 0.000 6174.57 Target: 11583.75ftMD,7302.00ftTVD; 149' FNL, 2595' FEL (See 10-T11 N-R4E Target - CD2-30 (Heel), Current Target 0.122 6174.70 7" Csg Pt... Begin 6-1/8" Hole: 918: ftMD,7117ftTVD 0.122 6182.74 0.122 6207.88 DrillQuest 3.03.02.002 DrillQuest 3.03.02.002 Page 10 of 15 21 July, 2003 - 12:29 Sperry-Sun Drilling Services Proposal Repolt for CD2-30 (wp05) Revised: 21 July, 2003 Alaska Nolth Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azlm. Depth Depth Northings Eastings Northings Eastlngs (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11700.00 89.333 332.385 7251.48 7303.48 3457.788 6397.82 W 5971144.94 Nd! 365~~~.9Q¡¡~ "ii;;;p:wQA 22 6233.04 11750.00 89.385 332.353 7252.04 7304.04 3413.488 6421.01W 5971189.62Ni~\ 'i3~9Z«~~~ ':i~,~~,Ò.122 6258.23 11800.00 89.437 332.321 7252.55 7304.55 3369.20 S 6444.22 W 5971234.30 N ~~if\ 36~gÌtÞì~Ó8~JìE' '1'i¡;TfO.122 6283.44 11850.00 89.489 332.289 7253.02 7305.02 3324.93 S 6467.46 W 5971278.96 N'~~;àh365tfffât60 E 0.122 6308.68 11900.00 89.542 332.258 7253.44 7305.44 3280.67 S 6J90.72 W 5971323.61 r~ '<¡t~,95166.10 E 0.122 6333.94 . - ~¡J.f~ft~- 11950.00 89.594 332.226 7253.82 7305.82 3236.438 6514.01 W "5971368.24 N 365143.58 E 0.122 6359.22 ., 12000.00 89.646 332.194 7254.15 7306.15 3192.198 6537.32 W 597141287 N 365121.02 E 0.122 6384.53 12050.00 89.699 332.162 7254.44 7306.44 3147.988~~ 6560.65W 5971~57.48N 365098A5E 0.122 6409.87 12100.00 89.751 332.130 7254.68 7306.68 3103.77 S~~.."'. Ej§ß4.0.t,'N 5971502.08 r.J 365075.85 E 0.122 6435.22 - ~2~,::0,00 ,~9.803 337..1)99 "- 72E<1.87.. 7306.87, 3i£,t57 S \i~'j.11~¡~1)7.4ã~'\t. 59?15~6.?7f\! 855053,22 E 0.122· 6~.60.61 12200.00 89.856 332,067 7255.02 7307.02,&91?9 8 ~t¡\?630.81 W 5971591.24 N 365030.57 E 0.122 6486.01 12250.00 89.908 332.035' 7255.12 7307.12 ,,', ~~~~7§71'¡~~.8 <'6654.24W 5971635.80N 365007.90E 0.122 6511.44 12300.00 89.960 332.003 7255.18 7307.18'=-::::'"'" ~f:~'g27~g~tS 6677.70 W 5971680.35 N 364985.20 E 0.122 6536.89 12350.00 90.013 331.971 7255.19 7307, 1 ~.;C:c:-·~'Z'gâ~93 8 6701.19 W 5971724.89 N 364962.47 E 0.122 6562.37 12400.00 90.065 331.940 7255.16 .730?:~.16£=--:..'~-12838.808 6724.69W 5971769.42N 364939.72E 0.122 6587.87 '- ..;', - .-"....~~,' -, - '., 12450.00 90.117 331.908 7255.08 i'3QZ.Q8 2794.688 6748.23W 5971813.93N 364916.95E 0.122 6613.40 ... 12500.00 90.170 331.876 7254.95 73dß~95 2750.588 6771.78W 5971858.43N 364894.15E 0.122 6638.94 12550.00 90.222 331.844 7254.'78 7306.78 2706.498 6795.36W 5971902.92N 364871.33E 0.122 6664.52 12600.00 90.274 33,J¡f§jf;~¡¡Rk '~¡i?~54:5'P'cic'" 7306.57 2662.41 8 6818.97 W 5971947.39 N 364848.48 E 0.122 6690.11 12650.00 90.326 3~¡1~78Ó\jf~~ \ts54.30 7306.30 2618.358 6842.60 W 5971991.85 N 364825.61 E 0.122 6715.73 ,,_'1~-:\::"?;*·'-. ~~~~-. lli ,/~ 12700,00 90.379' 331'¡Ø't~ß' 7254.00 7306.00 2574.308 6866.25 W 5972036.30 N 364802.71 E 0.122 6741.38 12750.0-0 90.431 331.7t~h. 7253.64 7305.64 2530.278 6889.93 W 5972080.73 N 364779.79 E 0.122 6767.04 12800,00 90.483:' 331.6s'~f" 7253.24 7305.24 2486.24 S 6913.64 W 5972125.15 N 364756.84 E 0.122 6792.73 12850.0Qev.·;·".90,5P6'\.",331.653 7252.80 7304.80 2442.238 6937.36W 5972169,56N 364733.87E 0.122 6818.45 ...12896.7~J;!!> 90.585 ""331.623 7252.34 7304.34 2401.09S 6959.57W 5972211.08N 364712.37E 0.122 6842.52 12900.00 90.585 331.623 7252.31 7304.31 2398.248 6961.11 W 5972213.96 N 364710.87 E 0.000 6844.19 12950.00 90.585 331.623 7251.80 7303.80 2354.258 6984.88 W 5972258.35 N 364687.87 E 0.000 6869.94 13000.00 90.585 331,623 7251.29 7303.29 2310.268 7008.64 W 5972302.74 N 364664.86 E 0.000 6895.68 13050.00 90.585 331.623 7250.78 7302.78 2266.278 7032.40 W 5972347.13 N 364641.86 E 0.000 6921.43 13100.00 90.585 331.623 7250.27 7302.27 2222.288 7056.16W 5972391.52N 364618.85E 0.000 6947.18 13150.00 90.585 331.623 7249.76 7301.76 2178.29 8 7079.92 W 5972435.91 N 364595.84 E 0.000 6972.93 13200.00 90.585 331.623 7249.25 7301.25 2134.308 7103.69 W 5972480.30 N 364572.84 E 0.000 6998.68 13250.00 90.585 331.623 7248.74 7300.74 2090.31 8 7127.45 W 5972524.69 N 364549.83 E 0.000 7024.43 13300.00 90.585 331.623 7248.23 7300.23 2046.328 7151.21W 5972569.08N 364526.83E 0.000 7050.17 13350.00 90.585 331.623 7247.72 7299.72 2002.338 7174.97 W 5972613.47 N 364503.82 E 0.000 7075.92 DrillQuest 3.03.02.002 ~ .......,.. .. .'~' ,. - - -'" 7874.12 7899.87 7925.62 7951.37 7977.12 7745.38 7771.13 7796.88 7822.63 7848.37 7616.64 7642.39 7668.14 7693.88 7719.63 7487.90 7513.64 7539.39 7565.14 7590.89 7359.15 7384.90 7410.65 7436.40 7462.15 7230.41 7256.16 7281.91 7307..66 , 73~3At..:.. '... '., ", .~ 7101.67 7127.42 7153.17 7178.92 7204.66 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 o~oo O~OO O~OO O~OO O~OO 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ,0.000 ,}¿p.OOO '." .000 .000 0.000 0.000 363790.64 E 363767.63 E 363744.63 E 363721.62 E 363698.61 E 363905.67 E 363882.66 E 363859.66 E 363836.65 E 363813.64 E 364020.70 E 363997.69 E 363974.68 E 363951.68 E 363928.67 E 364135.73 E 364112.72 E 364089.71 E 364066.71 E 364043.70 E 364250.76 E 364227.75 E 364204.74 E 364181.74 E 364158.73 E 364365.79 E 364~42.78 E 364319.77 E 364296.77 E . 364273.76 5 . 5973989.56 N 5974033.95 N 5974078.34 N 5974122.73 N 5974167.12 N 5973767.61 N 5973812.00 N 5973856.39 N 5973900.78 N 5973945.17 N 5973545.66 N 5973590.05 N 5973634.44 N 5973678.83 N 5973723.22 N 5973323.71 N 5973368.10 N 5973412.49 N 5973456.88 N 5973501.27 N 5973101.76 N 5973146.15 N 5973190.54 N 5973234.93 N 5973279.32 N Page 11 of 15 7911.59 W 7935.36 W 7959.12 W 7982.88 W 8006.64 W 7792.78 W 7816.55 W 7840.31 W 7864.07 W 7887.83 W 7673.97 W 7697.74 W 7721.50 W 7745.26 W 7769.02 W 7555.16 W 7578.93 W 7602.69 W 7626.45 W 7650.21 W . 436.35 W 7460.12 W 7483.88 W 7507.64 W 7531.40 W 73.1.7.'.54 W ':"{ß97:2879.81 iN 7341'.31 W ":':5972924.20 N 136Š:Ó:Z: W~ ' 59729'68.59 N 73å8.S'3'W '.'5973012.98 N ?~\2.!"Q~',!\f 5973057.:'7,N" " 5972657.86 N 5972702.25 N 5972746.64 N 5972791.03 N 5972835.42 N ",."c· ;':'., , 1:~':;{:'!:'.rs;~> . Global Coordinates DoSi~g'.v~·~i.ea't;,:' Northlngs Eastings;""lRàt~;:,.. :!Settiôn (ft) (ft), ~:;;/t;:'~Fí~boft:r"· ' ".~.. . \~.\~ North Slope, Alaska 7198.73 W 7222.50 W 7246.26 W 7270.02 W 7293.78 W 638.64 S 594.65 S 550.66 S 506.67 S 462.68 S 858.59 S 814.60 S 770.61 S 726.62 S 682.63 S 1078.54 S 1034.55 S 990.56 S 946.57 S 902.58 S 1298.49 S 1254.50 S 1210.51 S 1166.52 S 1122.53 S 7283.90 7283.39 7282.88 7282.37 7281 .86 7286.45 7285.94 7285.43 7284.92 7284.41 7289.00 7288.49 7287.98 7287.47 7286.96 7231.90 7231.39 7230.88 7230.37 7229.86 7234.45 7233.94 7233.43 7232.92 7232.41 331 .623 331.623 331.623 331.623 331.623 331 .623 331.623 331 .623 331 .623 331.623 90.585 90.585 90.585 90.585 90.585 90.585 90.585 90.585 90.585 90.585 21 July, 2003 - 12:29 14900.00 14950.00 15000.00 15050.00 15100.00 14650.00 14700.00 14750.00 14800.00 14850.00 7237.00 7236.49 7235.98 7235.47 7234.96 7239~5~'f-;. ~5 :7239~04 ^'::'.~~ 72~4 '::i~723äSS3,<{~¡ 7290.53 - ~~38~~' 7290.02 7.51 7289.51 ~~''fþ:-%,:.' 7294.'10 7293.59 ;~~~:~~:f ~.-;._~~~ .' -~_47 S 72d2jo6f~·." 1342.48 S . ;"J ~. ". '))~. 1738.39 S 1694.40 S 1650.41 S 1606.42 S -: ':'. 15,62.43 S ,"<'¡.- 1958.34 S 1914.35 S 1870.36 S 1826.37 S 1782.38 S Local Coordinates Northings Eastlngs (ft) (ft) Sperry-Sun Drilling Services Proposal Report for CD2-30 (wp05) Revised: 21 July, 2003 7296.66 7296.15 7295.64 7295.13 ,:.72.91.62, 7299.21 7298.70 7298.19 7297.68 7297.17 Vertical Depth (ft) 7242..1 0 7241 .59 7241 .08 7240.57 7240.06 331.623 331 .623 331.623 331.623 331.623 90.585 90.585 90.585 90.585 90.585 90.585 90.585 90.585 90.585 90.585 14150.00 14200.00 14250.00 14300.00 14350.00 13900.00 13950.00 14000.00 14050.00 14100.00 13650.00 90.585 331.623 7244.66 13700.00 90.585 331.623 7244.15 13750.00 90.585 331.623 7243.64 13800.00 90.585 331.623 7243.13 13E50.00 -., ·90..585, . 33:L62~· - .·7242·.62 7247.21 7246.70 7246.19 7245.68 7245.17 Sub-Sea Depth (ft) 331 .623 331.623 331.623 331.623 331.623 Azlm. 90.585 90.585 90.585 90.585 90.585 Inel. 13400.00 13450.00 13500.00 13550.00 13600.00 Measured Depth (ft) Alaska North Slope Dri/lQuest 3.03.02.002 Page 12 of 15 21 July, 2003 - 12:29 Based upon Minimum Curvature type calculations, at a Measured Depth of 16066.30ft., The Bottom Hole Displacement is 8474.73ft., in the Direction of 272.620° (True). The Along Hole Displacement is 12959.71 ft, the Planned Tortuosity is 1.489°/1 OOft and the Directional Difficulty Index is 6.3. Magnetic Declination at Suriace is 24.534°(21-Jul-03) The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 1865' FNL 1527' FEL and calculated along an Azimuth of 272.620° (True). All data is in'¡g~êt (US survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical deptHS'are relative to RKB= 52' MSL. Northings and Eastings are relative to 1865' FNL 1527' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. 5974211.51 N ;¡ß3,,63~~~p'~;~t7~Q,ÕOO 8002.86 5974255.90 N t~i ~q55~~9~ '¡W~~;~.OOO 8028.61 5974300.29 N ~t} 3"6ã\g~,,6'Ô!Ë; <;i:'o.ooo 8054.36 5974344.68 N "i'1;¡',36i~ù~59 E 0.000 8080.11 5~!4~89:~~.7 N:4t!$§3583.58 E 0.000 8105.86 ~'5974433Aé~ 363560.58 E 0.000 8131.61 .;5~7~~?7.85 N 363537.57 E 0.000 8157.35 5974522.24 N 363514.57 E 0.000 8183.10 -59'74566.~3 N 363491.56 E 0.000 8208.85 ./39?.<i611-.02 t'oJ. .. ·~B3468.55 E 0.000 .8234.60. 5974655.41 N 363445.55 E 0.000 8260.35 5974699.80 N 363422.54 E 0.000 8286.10 5974744.19N 363399.54 E 0.000 8311.84 5974788.58 N 363376.53 E 0.000 8337.59 5974832.97 N 363353.53 E 0.000 8363.34 5974877.36 N 363330.52 E 0.000 8389.09 5974921.75 N 363307.51 E 0.000 8414,84 5974966.14 N 363284.51 E 0.000 8440.59 5975010.53 N 363261.50 E 0.000 8466.33 5975025.00 N 363254.00 E 0.000 8474.73 Target: 16066.30ftMD,7272.00ftTVD; 1482 FNL, 4714' FEL (See 3-T11 N-R4E) Target - CD2-30 (Rev Toe) Curren1 Target 8386.83 W 8410.60 W 8434.36 W 8458.12 W 8465.87 W 268.02 W 8291.79 W 8315.55 W 8339.31 W 8363.07 W 241 .15 N 285.14N 329.13 N 373.12 N 387.47 N 198.74S 8149.21 Wee: 154.76 S 8172:98 W 11 0.77 8"",,-~:a-196.14 W-- 'é'~;:~~" ~;~~·gÆ-B¡(!i~~ :~~¿~ Global Coordinates Northlngs Eastlngs (ft) 8030.40 W 8054.17 W 8077.93 W 8101.69W 8125.45 W 418.698 374.70 S 330.71 S 286.72 S 242.73 S Local Coordinates Northlngs Eastlngs (ft) (ft) Sperry-Sun Drilling Services Proposal Report for CD2-30 (wpOS) Revised: 21 July, 2003 722J:i?Ô~~~:~,. 7S~rZO . }22l~1 9 '~~'j 7213:1 9 ;J~~~~~~~%~~? ~~~~:~~ ·~~20.00 7272.00 7276.25 7275.74 7275.23-'> - 72'l.5.. 72'" 7274':21;::': ~'..,~-;:' ·~*,~þ~:P 7224.25 7223,74 7223.23 7222.72 7222.21 331 .623 331.623 331.623 331.623 331.623 Sub-Sea Vertical Azlm. Depth Depth (ft) (ft) 331.623 7229.35 7281 .35 331.623 7228.84 7280.84 331.623 7228.33 7280.33 331.623 7227.82 7279.82 331.623 7227.31 7279.31 331.623 7226.80 7278.80 331.623 7226,29 7278.29 331.623 7225.78 7277.78 331 .623 7225.27 7277.27 33~ .523- L 722~,.76. .. , 7276·,76. Alaska North Slope Measured Depth Incl. (ft) 15150.00 90.585 15200.00 90.585 15250,00 90.585 15300.00 90.585 15350.00 90.585 15400.00 90.585 15450.00 :90.585 15500.00 90.585 15550.00 90.585 ~ 5600;00 90 5?5 15650.00 90.585 15700.00 90.585 15750.00 90,585 15800.00 90.585 15850.00 90.585 15900.00 90.585 15950.00 90.585 16000.00 90.585 /16050.00 90.585 16066.30 90.585 Alaska North Slope Comments Measured Depth (ft) 0.00 300.00 2000.00 2187.49 3023.80 Sperry-Sun Drilling Services Proposal Report for CD2-30 (wp05) Revised: 21 July, 2003 Station Coordinates TVD Norttílngs Eastings (ft) (ft) (ft) Comment -~ 0.00 300.00 1784.24 1898.43 2390.00 . . ~633:3¿" . - 6275.Ciû" 11201.80 7230.64 11583.757302.00 1158.4.00 7302.00 16066.30 7272.00 ." .... ..... Formation To"s 0.00 N 0.00 N . 395.88 S 485.44 S 920;34 S '''43'37:49 S'" . 3903.80 S 3560.81 S 3560.59 S 387.47 N North Slope, Alaska 0.00 E SHL (1865' FNL & 1527' FEL, 0.00 E Begin Dir @3°/1QOft (in ~4 586.91 W Continue Dir @ a:t)OOor1@'è~ ,1784.24ftTVD 705.51 W End Dir, Start Sail )~. 54.000°':,2187 .49ftMD, 1898.43ftTVD 1223.80 W 9-5/8n~~~:~t,;.,~~;Dì1I1,O.~~ 8~~!2¡'Hole: 3024 ft MD, 2390 ft TVD ····532û:û3·W·'·· -i¡'ôSai:;J~&Yiri'Dir @ 6.5~Í'í;jC;iL9633itiviD,õ;;:75ftTVD· - ............ 6199.38 W ", ntinue @ 6.5000/100ft : 11201.80ftMD,7230.64ftTVD 6344.01 W ,'::>':; Tå,~get : 11 .75ftMD,7302.00ftTVD; 149' FNL, 2595' FEL (Sec 1 0-T11 N-R4E) 6344.12·W ":~ ~:. 7R:Csg Pt... Begin 6-1/8R Hole: 9183 ft MD, 7117 ft TVD 8465'.aiwc, <'l1'¡;.Target: 16066.30ftMD,7272.00ftTVD; 1482' FNL, 4714' FEL (See 3-T11 N-R4E) ~). ~~::~.~l.:: :~~-"::.;~. '0 ~-~..:::-. . . - .,::;"",~,,:~:,,;.:. ~~.i'.V Formation Plane (Below Well Origin) Sub-Sea Dip (ft) ",", Ang'~, ~."~~.,.¡';:,,..,- ~f~<~ '., . ~~;!;: . it~, 1000.00 :', 0.000~~.·.359.020 1550.0.0 _. .>-0~qOO\:~~59.020 2161.00', 0.000 '.'359.020 2358.0Q:it:¡ 0.000 359.020 2734.00 0.000 359.020 3796.00 4024.00 5361.00 5895.00 6797.00 21 July, 2003 - 12:29 0.000 359.020 0.000 359.020 0.000 359.020 0.000 359.020 0.000 359.020 1072.93 1732.62 2722.67 3057.83 3697.52 5504.30 5892.20 8166.84 9075.33 10469.12 1052.00 1602.00 2213.00 2410.00 2786.00 3848.00 4076.00 5413.00 5947.00 6849.00 Penetration Pol n t Sub-Sea Depth Northlngs Eastings Formation Name (ft) (ft) (ft) 1000.00 86.27 S 127.90 W West Sak 1550.00 286.64 S 424.96 W Permafrost -.-J 2161.00 763.75 S 1037.18 W C-40 2358.00 938.04 S 1244.89 W C-30 2734.00 1270.69 S 1641.33 W C-20 3796.00 2210.27 S 2761.07 W K-3 Marker 4024.00 2411.98 S 3001.47 W K-2 Marker 5361.00 3594.86 S 4411 .16 W Albian 97 5895.00 4067.30 S 4974.20 W Albian 96 6797.00 4417.11 S 5880.99 W HRZ Page 13 of 15 DrillQuJst 3.03.02.002 I Sperry-Sun Drilling Services Proposal Report for CD2-30 (wp05) Revised: 21 July 2003 Alaska North Slope Formation Tal's (Continued) Formati on Plane (Below Well Origin) Sub-Sea Dip Up-Dip (ft) Angle Dlrn. Profile Measured Vertical Depth Depth (ft) (ft) Penetration Sub-Sea Depth (ft) Northings (ft) Eastlngs (ft~G if~~~d . -60Üi.oß9 W5-,Base HR <-'6059:70cW -'K-1 Marker .<6094.63 W Kuparuk Fm '. 6130-;'82 W LCU- Miluveach "W16190.84 W Miluveach A 6945.00 0.000 359.020 10699.22 6997.00 6945.00 7000,00 0.000 359.020 10794.91 7052.00 7000,00 7042.00 0,000 359.020 10874.31 7094.00 7042.00 7087,00 0.000 359.020 10968.38 7139.00 7087.00 7167.00 0.000 359.020 11170.72 7219.00 7167.00 7184.00 0.000 359.020 11216.38 7236.00 7202.00 0.000 359.020 11270.09 7254.00 Casin_Q details ~.--:L'-i7~?:~-.. Fro m .' "._, 'iI 0 ·c'.-·i Measured Vertical Meàsu'redli"~,~Vertlcal Depth Depth ú;~f~D'epth ···~~;:'-Depth (ft) (ft) , .' -~=~ (ftt (ft) Casing Detail ,. '-., .-.. , <Surface> ' :<Suriãce;'·~~~~;::3023.80 <5Í:Îrtã'Ce> <:Su riaCé> ;~J 1583.71 1 t~~~~'QÔili '7301.99 '016066.50 2390.00 7302.00 <No Data> 95/8" Csg Pt 7" Csg Pt 61/8" Open Hole <':_~:<:~~>\";" "0-::-::~~~':: 21 July 2003 - 12:29 Poi n t North Slope Alaska ID 4301.36 S 4238.81îf§., 4J ~iJfþ~~;i~t¡_ 7'{()4 $,:;: 'f1t{~: ~ ' 3:ß7S 38~2~90 S 6203.45 W Alpine D 6219.52 W Alpine C Page 14 of 15 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for CD2-30 (wp05) Revised: 21 July, 2003 North Slope, Alaska Alaska North Slope Tarqets associated with this wellpath Target TVD (ft) Target Name Target Target Shape Type CD2-30 (Heel) 6344.01 W 365308.00 E 151005' 32.7699" W Polygon Current Target ~ Mean Sea Level/Global Coordinates: Geographical CoordI~~tes~7 6' \ '~~{~, ~~,~';~:(~y~ Target B.'·, .:;ftoriifW.1 '~~¡Lr/, 02.00 \~;,~:/~V .~~~"' ";;;1;"~;~~~:gg #4 7302.00 3701.59 S 3594.79 S 404.30 N 117.60 N 6393.23 W 6196.74 W 8435.04 '"V 8625.36 W bar Coordinates #1 #2 #3 #4 7250.00 7250.00 7250.00 7250.00 5970901.08 N 5971004.50 N 5975041.30 N 5974757.90 N 365256.38 E 365454.66 E 363285.11 E 363089.91 E Geographical Coordinates #1 #2 #3 #4 700 19' 42.3288" N 1510 05' 34.2034" W 700 19' 43.3808" N 1510 05' 28.4695" W 70020' 22.6931" N 151006' 33.9504" W 70020'19.8711" N 151006' 39.5004" W 7272.00 387.47 N 8465.87 W 7220.00 5975025.00 N 363254.00 E 70020' 22.5272" N 151006' 34.8503" W Point Current Target Mean Sea Level/Global Coordinates: Geographical Coordinates: ,~ Page 15 of 15 DrillQuest 3.03.02.002 21 July, 2003 - 12:29 I Travelling Cylinder Azimuth (TFO+AZI) See MD Inc Az; TVD 1 36.100 0.000 0.000 36.100 2 300.000 0.000 236.000 300.000 3 2000.000 51.000 236.000 1784.239 4 2187.488 54.000 230.000 1898.428 5 9633.358 54.000 230.000 6275.000 6 \1079.821 68.005 342.763 7184.956 7 11201.803 68.005 342.763 7230.641 8 11583.713 90.383 331.746 7302.000 9 16066.496 90.383 331.746 7272.000 [ deg] 0.000 0.000 0.000 0.000 -395.878 -586.914 -485.439 -705.504 -4357.485 -5320.029 -4011.823 ·6165.862 -3903.799 -6199.377 .3561.116 -6344.514 387.474 -8466.558 VS Centre to Centre Separation [50ft/in] Dug TFaee 0.00 0.000 0.00 236.000 3.00 236.000 3.00 300.366 0.00 0.000 6.50 121.007 0.00 0.000 6.50 -27.078 0.00 0.000 VSe<: 0.000 0.000 568.202 682.574 5115.254 5976.005 6014.423 6175.075 8475.419 CD2-30 Rev (Heel) CD2-30 Rev (foe) CD2-30 (WpOS) --- Approved Plan --- =100 -:50 Depth Frn Deplh To SurveylPbn 36.100 1200.000 P1anried:CD2~30wp(5)V15 1200.000 16066.496 Plahned:CD2:;3DWp05) V]5 -25 -0 -25 -:50 -75 -75 =IOQ 270 SECTION DETAn.s +NI·S +EJ-W Target -20.0 -15.0 -10.0 -5.0 -0 270 -5.0 -10.0 -15.0 -20.0 Travelling Cylinder Azimuth (TFO+AZI) [ deg] VS Centre to Centre Separation Oft/in] Name PIu!: CD2·:J{) >i1·S 148.631 .ëI-W 18.307 SURVEYPROGRA.-\1 WELL DET AlLS NonIUng E.~in¡ 74492.75 J7l2.00 l.atiude 7<n0'18.763N l.onpude 1 '02'27.S4IW Slot NlA Interpolation Melbod: MD Depth Rl1\ge From: 36.100 Maxi!l1JrnRange: 1791.738 ANI1.çOUlSION SETTINGS Interval: 100.000 To: 16066.496 Refere=: Plan: CD2-30 wp(5) COMPANY DEI AILS Cooo<oPIUWp, Ala... Inc. F.ngincerinl Kupuul:: c.lcu.1alion Method; Mínimwn CUmtoJre. F-frof SY1Icm: ISCWSA Scan M«hod: Tnv Cylinder North Error SUJ"facc.: HllipticaJ + Cui1g W.a.min¡: y&thod.: Rules Bue.d. R Ri¿: [)¡Ium: V.Secth-m AngJ. 272.620" V'E1.l.PATH DF.TAII_~ CDZ·:J{) Doyon 19 52' MSL Origin Origin ...~/.S +EI-W 1.000 0.000 5LOOOft SlaI1Ì'ng From TVD '.000 ) Sperry-Sun Anticollision Report Company: ConocoPhillips Alaska .Inc. Field: Colville.River Unit . . Reference Site: . Alpine C02 . Reference Well: "Plan: 'CD2"30 Reference WeUpath: CO'2-30 NO GLOBAL SCAN: Using user defined seJection & scan criteria Interpolation Method: MO Interval: 100.000 ft Depth Range: 36.100 to 16066.496 ft l\Ia.",imum Radius: 1791.738 ft \ . Casing Points 'l\-ID. TVD Diaineter Hole Size .' Name . ft" ft in in 3023.801 2390.000 9.625 12.250 9 S/8" 11353.159 7276,347 7.000 8.500 7'" 15835.852 7273.544 6.125 6.125 Open Hole Prindpal: Yes Plan: C02"30 wp05) Swnmary . <~-:-~:..~~:.;-"""~-"-":..~-~ C)[fse~ WeUpå,th ---~-~-;-':~----..,..-~~~-">. . . Si~e .' " .. WeIJ:' '. . ':Weli~th' . Alpine C02 Alpine C02 Alpine C02 Alpine .c02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine· C02 Alpine C02 Alpine C02 Alpine C02 Alþine,C02 Alpine C02 Alpine C02 . Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 AlpineQ02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 . Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine. C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 C02-08 C02" 12 C02-13 CD2-13 C02-13 C02-14 .002-15 002-15 002-15 'C02-16 C02-16 C02-17 CD2-19 C02-20 C02-22 C02"23 CD2-23 .002-24 CD2-24 C02-25 CD2-26 CD2-26 CD2-26 C02-28 CD2-28 C02-29 CD2-32 CD2-32 C02-33 CD2-33 CD2-33 C02-34 C02-34 CD2-35 C02-35 C02-36 CD2-36 CD2':37 .002-38 CD2-39 C02-39 C02-41 C02-42 C02-42 C02-44 C02-45 C02-08 V8 .002-12 V7 C02-13V1 C02-13PB1 V10 C02~13PB2 \'4 C02-14 V1 C02-15 V3 C02-15PB1 \'1 C02"15PB2 V2 C02-16 (Rig Surveys) V C02-16 V7 C02-17 VO C02-19 V8 C02"20 V4 C02-22 V1 C02-23 V2 'C02-23PB1 \'12 C02-24 VO .: C02-24PB1 \"1 C02-25 V1 C02-26 V4 C02-26PB1 V2 C02-26PB2 V3 C02-28 V3 C02-28PB1 V13 C02-29 V1 C02-32 PB1 '/0 C02-32 VO . C02-33 V2 . C02-33A V1 r C02-34B V1 C02-34 V3 C02-34PB 1 \'2 C02~35 V1 . C02.:.35A V1 C02':36 PB 1 V5 C02-36 V5 . C02-37 V16 . C02-38 V5 C02-39 V1 C02-39PB1 VO .002-41 V9 . C02-42 VO C02-42PB1 VO C02M V15 C02-45 V5 Date: 7/21/2003 ') Time: 10:52:44 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plàn:'.C02-3Q, True North ~2' MSL 52.0 Date Composed: Version: Tied-to: :. .: Refè~enée· ':.Uffset,' .;. .MD ..' '.":Mi)' ft . . . ..ft 199.599 .299.760 299.446 299.446 299.446 '395.316 299.579 299.579 299.579 299.993 299.493 299.565 396.933 299.512 397.642 ' 299.223 299.223 397.723 397.723 397.979 300.000 498.465 488.536 299.349 299.349 299.448 499.437 499.437 . 600.658 600.658 600.658 399.905 399.905 614.782 600.908 299,725 299.725 503.482 502.665 199.999 199.099 603.385 804.652 804.652 605.509 402.490 200.000 300.000 300.000 300.000 300.000 400.000 300.000 300.000 300.000 '300.000 300.000 300.000 400.000 . 300.000 400.000 300.000 300.000 . 400.000 '400.000 400:000 300.000 500.000 490.000 300.000 . 300.000 300.000 500.000 500.000 600.000 600.000 600.000 400.000 400.000 600.000 600.000 300.000 300.000 500.000 500.000 200.000 200~000 600.000 800.000 800.000 600.000 400.000 Reference: Error Model: Scan Method: Error Surface: Db: . Oracle Plan: C02-30 wp05) & NOT PLANNEO PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing 7/14/2003 14 From Well Ref. Point . .;·:Cti:,.Ck' .. No-Go .Dista:D.ce . Area :. . " <~_ .:":. ff'. 220:158 4.061 180.199 5.719 171;821 6.148 171.821 6..148 171.821 6.1.48 160.772 6.387 149.996 5~852 149.996 5.852 149.996 5.852 140.307 5.396 140.306· 5.278 130.778 5.472 109:489 6.469' 101.534 .5.767 80.185 6.299 71.252 5;291 71.252 5.400 60.703 6.567 60,703 6.567 51;115 6.786 41.168 5:374 35.407 7.680 34.545 7.718 ~.459 5.305 20.459 5.415 10.742 5.462 17 .893 7.766 17.893 7.656 27.346 8.884 27.346 8.837 27.346 8.884 34.279 7.218 34.279 7.328 49.424 9.315 49.197 8.976 60.047 5.417 60.0.47 5.417 70~950 8.881 81.178 7.772 90.377 3.368 90.369 3.353 104.246 9.638 109.927 12.408 109.927 12.408 134.759 9.913 149.091 6.648 . . Ai10Wable . . De.viätion ... ~~ning . 'ft. .' . 216.097 174.480 165.675 165.675 165.675 154.414 144.144 144.144 144.144 134,911 135.029 125.307 103.075 95.768 73.927 65.962 65.852 54.141 54.141 44.336 35.800 27.762 26.908 15.154 15.044 5.280 10.149 10.258 18.464 18.511 18.464 27.091 26.981 40.135 40.252 54;631 54.631 62.093 73.469 87.009 87.016 94.634 97.526 97.526 124.858 142.503 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: M~jor Risk Pass:. Major Risk Pass: Major Risk Pass: Major Risk P¡;¡,ss: Major Risk Pass: Major Risk pass: Major Risk Pass: Major.Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk P(i.ss: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Coo(J(;oPhillips.A.låSkå.1r1c~ Colville Rived)nit AlpinèCD2 .. Plan:CD2-30 . GD2-30 C6iI1Þ:lI1Y:> Fi~ld: Reference Site: RefCreliceWell: R~feI:enCe.Weßpath: Swnmary <: ~~~---~~:'~~~-~~~--~~~iÓffsCt ·WeUpath __:'~"~~__:'~",:~~2~_~_"~> Site Well · WcllJiàth Sperry-Sun Anticollision Report Date: 1/2112003 Co:'ordinate(NE) Reference: . . ·VerücaI (TVD)Reference: Alpine C02 AlpineC02 AlpineCp2 AlpineÇ02 AlpinèC02 AlpirieCQ2 AlpineC[)2 AlpirieC02 A!p@fQP2 Alpin~Çp2 .Ä1þineCÇ>2 Alþip¢QQ2 þ,lpihë·(3[)2 Alpi(1~QP2 AlpineQ02··· AlpineQP~ Alþlh~Pþ2 AlpinêQP2 AlpirieCD2 Alpine 002 A!þineQD2 Alpine C02 AlpiMCD2 Alpirie<CQ2 Alpin~ C02 CD2-46 C02-47 OD2-48 C02-49 C02-50 C02~50 Q02~51 C02-52 Plan:Q02~;31 Plan; C02-31 Plqn:CD2:'4Q Plårï:GD2-43 Plari :C>02~43 Plan: 0(:)2:'43 Plån:.cD2~43 PlaIl:Öb2:'54 Plän:OD2:'S5 Plän:. CD2~55 Prelirn: 002.,05 PrØlilTl:ÇO~-œ Pn~lim; CD2-10 Prelim:GD2-18 Prelim: CD2-S3 Prelim: CD2-56 Prelim: G02"57 Site: AlþilleC02 Well: CD2-0.8 Wellp..th: G02-08 V8 Reference MD TVD It ft Offset MD TVD It ft 36.100 99.600 199.599 299.519 393.701 486;20.1· 576.$6$ 664.283 749.165 830.39$ 36.100 36.500 99.600 100.0.00 199.599 200.0.00 299.519 300.0.00 393.664 400..0.00 485,906 500..0.0.0 $15~6þO 6()O:ÖÖO 662.078 700..00.0 7'4$~Ö$5 800.000 623;603 900,000 36.500 100.000 199.999 299.919 399.632 Refer~nce .MD ·ft Off$et ·MD ft C02~46 V2 904.224 900.000 C02~47 V2 1027:096 1000,000 C02-48 Vi 708.885 700.000 ë02-49 V1 1108.665 1100.000. CD2·BOV2 1015.944 10(;l(}.;qQQ C02-50PB1 \12 1015.944 1000.000 C02~51V8 607.784 600~OÒO C02-52 V6 299.521 300.000 PLAN.:CO.2-31(~8Horz) ·4qO.14B 400.0.00 Plqn:CP2~31.($TÇ()re) . .40<n~.6 4oo·0QO CD2-4o. VOPlan:· C02-401 0865.942 10.700:000 Cb2~43 (G~ Core Pilot) 1128.613 llOQ..OOO CD2-43 (ST Core) V7 PI 3239.8183200.000 Plan: C02-43 (GR Horz) 3239.818 3200J>Q0 Plan: C02-43 (ST Harz) 1128.6131100~OOO ÇD2':54VO PIaJ):>Ai5(J> 1286.517 1300.000 Plan: CP2-55V2 Plari: 406.290 400.000 Rig:C02-55 ¥2.. .. . W9,995 200.000 C02-;Q5V1'Þlan: CP2-o.53587.2.46 3700.000 C[>2.{)6VOp,an: G02-o.6 300.000 300;000 C[)2-1 OVo.P;:an:CD2-1 0 3OO~000 300.()(X) C02~ 1.8 V1Ran:G[)2-18 300..000 300.000 C02.,53 VO P:an: C02-53 40.5.619 400.0.00 CQ2-5QV1 P~an:C02-56 406;393 400.000 C02:'57Vo.p'an:.C02:'57 300.000 300.000 Semi-l\.lajoIj Axis . Ref Olfset TFO+AZI TFO-HS Casing . ft ft deg deg in 0..000 0.000 352.94 352.94 9.625 0..072 0.087 352.94 352.94 9.625 0..298 0.288 353.02 353.02 9.625 0..525 0'.507 353.79 353.79 9.625 0..581 0666 355.79 119.79 9.625 499,0.76 0:q45 598;362 0.593 1)97.476 0.1g4 796;510 0.;912 895.193 1.137 900.QOO 8~.179 1000.000 992;517 1:354 97Z106 958:319 1100.000 1066.905 1;617 1029:194 1Qtt606 1200..0.00 1177.375 ·1.840. 1080..612 lQ59.0.5ß 1300.000 1266.152 2.0.53 1127.904 110221.7. 1400.000 1354;174 2;196 1169..88.5 1140.118 1500,0.00 1440.259 2;291 12QO.QQQ 1161.058 1600..000 1524.43.9 2.359 1240..583 1203..0.19 1700.000 1607.449 2,376 1270..298 1229;093 1800.000 1688.688 2.388 1300.000 1254;930 1900.000 1167;141 2.400 1300.000 1254.930 2000.000 1841.389 2.400 1329.627 1280.471 2100.000 1910:099 2.427 1339.003 1288.505 2200..000 1973.898 2.435 1346;931 1295.280 2300.000 2036.509 2.442 1352.981 1300.439 2400.0.00 2096.874 2.447 ----.--,---.---..".". """'''-"''''"~. I)age: 2 Well: Plari: C02:'3Ö, True North· 52' MSL52;0.· . ·Ctr':Ctf·· Nø2GO Distance· Area ft ·.ft· 148.558 13,518 161.303 18.115 175.655 11.147 170..403 18~857 186.494 16;978 1ªQJ494 1.6:978 202;922 10.217 222.452 6~120 9.145 8..112 9.1.45i:L112 264,1()3· 272.781 123';399 23;507 112:425 .82:631 112.4g5 82:568 123:;399 . 23~507 29.426 26.026 250.979 7;626 250;201· 3.589 243.683 146~888 239:842 6.375 199;959 6.375 120.075 6.375 231.138 7,632 260.90.2 7.674 270..026 6.375 RüJ~As$igned: Int~r~SiteError: Ctr-Ctr No-Go Distance Area ft ft 219.953 219.956 220.158 222.506 228.554 AlIQwable· Deviaüon ft 135.111 143.450 164524 151.617 1i?~.?23 169.523 192]55 216.333 1.033 1.033 25.225 101.0.74 40.264 4o.~327 101 ;074 4:589 243.355 246.61.3 97;874 233.467· 193.584 113.699 . 223:50.7 253.229 263.650 Db: . OraCle Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Májor.Risk . ·Pa$s:MàjorRisk Pá$s;MajorRisk Páss:Májdr Risk Pass: Major Risk Pa$s: Major Risk Pass: Major .Ri.sk Pa$S: Majorflisk På$$: MajQr Risk Pa$s:MåjorBisk f>áss:MåjorHisk Pàss:MajÒrRisk Påss:'MajórRi.sk . Pa,ss:MåjorHisk Pa$s:Mäj6rRisk Påšs:MajorHisk Pass: MajorHisk Pass: Major F)isk Pass: Majo(Risk Pass: MajorHisk Pass: Major Risk Pass:. Major Risk Majo(Risk 0.000 ft AJlowable Deviation Warning ft 0.912 219.041 1 .957 217.999 4.0.61 216.097 6.20.9 216.299 7.70.3 220.870 0;700 359;27 123.27 .9.625·· 2.39:135 .8.pp8 .2$0;562 0..752 3.62 1.27.132 9.625 2$3:8p7 9J710 244·180. 0.810 6.49 132.49 9,625 273;293 11.0.20 262.307 0:871 1.3.45 137.45 9.625 297;376 12.513· 284.99.5 0,952 18.43 1.42.43 9.625 327,60.8 1Al16 . 313.774: 1.,057 23.51 147:51 9.625 367.463 15.646 352:283 1'.180. 28.10 152:10 9~625 420.774 17:372 404.131 t3.19 31.62 155.62 9.625 487,29.9 18.928 469.455 11.383 34:22 158.22 9.625 ~60:Q33 20.179 541.308 l' .4$9 36.28 160.28 9.625 636.208 21.326 616.771 1..735 37.98 161.98 .9.625 716;543 22,640 696.412 2.011 39.40 163.40 9.625 800.402 23:6.33 779.747 2.296 40.55 164.55 9.625 886.564 25.022 865.405 £;;588 41 .40 165.40 9.625 975.426 26.10.3 953;869 1'.908 42.03 166.03 9.625 1067.11.3 27.260 1045.148 2.267 42.48 166.48 9.625 1161.812 28.185 1139.735 ::.659 42.85 166.85 9.625 1258.667 29.55.9 1236.20.8 4.040 43.22 167.22 9.625 1357.072 30.653 1334.459 ð..~73 43.55 167-.55 9.625 1455.797 31.607 1433.072 £·.713 43.74 167.74 9.625 1555.083 32.555 1532.268 Pass Pass Pass Pass Pass R®s Pass p~ss Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pa$s Pass Pass Pass Pass Pass Pass i ..~-. I I ¡Ii 1350 ···4-·:".õ- _;m.~____;__._: ¡Ii I 1300 , '~"'¡'__"ª'h¡' Iii i 1250 I 1 I I 1200 '. i I I 1150 ! I ~ : ~ j 1050 I ; ,': ¡ ¡ ¡ ¡ : ¡ , , ; i I III 950 I I I. III 900 I I Z' I CD2-30/CD2-30) i 860 :ÁT 'I/L .. I 750 / - I' - -~-~.':.~-'~~ - --- -1--_. ~ ( '. '--. ·R:···..·:··· . .¡ . ..' .1.". :. I II-Iii.: I I, "I . I I I :-------.-. :: I . .' I ._.._~ - "".",·:1 1:.:,11; I ~-_: I I II; II; IT 11111 I i IIIIIII 250 400 450 500 550 600 I : ,,< , ; I I I 700 I I : I I I I III 650 I I . I -1 I I Plan: CD2-30 wp05) (Plan: I i I I I I I I I I I -1 I I i I 200 I I I III 100 Ë c:: .9 ~ Þ3 0- Q) CI) Q) b c:: Q) u 9 Q) M ~ U U CD2-14 (CD2-14) CD2-17 (CD2~17). CD2-24 (CD2-24) CD2-28 (CD2f28) CD2-33 (CD2~33A) CD2-36 (CD2-36PBl) CD2-41 (CD2-41) CD2-47 (CD2c47) CO2-52 (CD2-52) Plan: CD2-43 (plan: CD2-43 (GR Prelim: CD2-06 (CD2-06) 1100 CD2-13 (CD2-13PB2)· CD2-16 (CD2-16) . CD2-23 (CD2-23PB 1) CD2-26 (CD2-26PB2) CD2-33 (CD2-33) CD2-35 (CD2-35A) CD2-39 (CD2-39PB I) CD2-46 (CD2-46) ---- CD2-51 (CD2-51) - Plan: CD2-43 (CD2-43 (ST Core)1-- Prelim: CD2-05 (CD2~05) - Prelim CD2-57 (CD2-57) Measured Depth [ft] CD2-13 (CD2-13PBl) CD2-16 (CD2-16 (Rig Surv, - CD2-23 (CD2-23) CD2-26 (CD2-26PBI) - CD2-32 (CD2-32) - CD2-35 (CD2-35) - CD2-39 (CD2-39) - CD2-45 (CD2-45) - CD2-50 (CD2-50PB I) Plan: CD2-43 (CD2-43 (GR COle ra..A) Plan: CD2-55 (Rig: CD2-5~;) -- Prelim: CD2-56 (CD2-56) - eys» CD2-13 (CD2-13) CD2-15 (CD2-15PB2 CD2-22 (CD2-22) CD2-26 (CD2-26) CD2-32 (CD2-32 PBI) CD2-34 (CD2-34PB I) , CD2-38 (CD2-38) CD2-44 (CD2-44) CD2-50 (CD2-50) Plan: CD2-40 (CD2-40) Plan: CD2-55 (plan: CD2-55) Prelim: CD1-53 (CD2-53) ISO - DrillQuest - 1 - 21 July, 2003 - 12:31 MD : . Delta Inclin. Azimuth I TVD Northings Eastìngs Dogleg I T ooIface VS (c273°) (ft) : MD (ft) , C) CO) I (ft) (ft) (ft) (°/1 DOft) , (0) (ft) 1 0.00 0.000 0.000 0.00 O.OO! 0.00 0.00 - ---- ----.--- 2 300.00 300.00 0.000 0.000 300.00 0.00 0.00 0.000 0.000 0.00 3 2000.0~ ,,1700.00 51.000 236.000 1784.24 395.88 S 586.91 W 3.000 236.000 568.20 __,,L'. -r-"--'--¡..- _..- 4 2187.49 187.49 54.000 230.000 1898~43 4aS.44 S 705.50 W 3.000 300.366 682.57 230.000 . 6275.00 43!.i7.49 S _ -----.-,....--. 5 9633.36 7445.87 54.000 5320.03 W 0.000 0.000 5115.24 342.763 7184.96 40'! 1.83 S 6165.86 W --------.--.... 6 11079.82 ,,1446.46 68.005 6.500 121 ~007 ' 5975.99 .,-.,..-"-------... .- 7 11201.80 121.98 68.005 342.763 7230.64 3903.80 S 6199.38 W 0.000 '0.000 6014.41 8 11562.7,? ·,,~60.,93 '89.~11 332.459, ' 7301 .71 '35~~9.44 S "6334.29 W 6.500 ,'~í3.304, 6164.01 9T " .~ 15,83~75 ,21.0~89211, .332.459 7302.00 3560.81 S 6344.01 W 0.000'. CÜJOO ~617 .4.~7 ,101 :,12896)5' ·l,313.ob ,90.585 331.623 7304;34 2401.09 S 6959.siw 0.122 32'8~69Ó ' 6842.52 L!1T ; 16066~3å':'·3169.55.; 90~~~ 331.623 7272.00 3G7.47 N 8465.87 W 0.000 0.000 8474.73 ---_._---_._--,-- Spe~-~y-Slun Drilling Sr ~vices Proposal Lo(~aIData - CD2-3D - CD2-3D (wpD5) DrillQuest - 1 - 21 July, 2003 - 12:31 ,- 1 . '~ , MD '. [ Delta.; InèIÎI1.. :Azimuth . TVD North.ings' ,;. Eastings· 'Dogleg: "Toolfacè:: V$ (c274°) . (ft)' f' MD (ft) <" (0) : (0) (ft)' ; :.:. :'(ft) ·(ft) ': :' (0/100ft) ,::,: (Of .': . '.' (ft)': ' 1 0.00' 0.000· O.OQO . -52.00 5974492.75 N 371712.~0 E ':',' \: .p.OO '2 ' 300.00 300.00 0.000.: Q.O,OO . :248~00 59'14492.75:N. 371712;09E ." O.OPQ,:,:',>Û.QOO :..... ':~9:P~~. 3 '!. j-.;2Øøo.PO H.oO~ÖO 51.000 236.980' :1732,24: 59".'!41Q6.9.7.N .·;371.1,18.40' E 3.000. :2~6.980 ~'>..';:.ß6~.?Ö . ·'.f>" <::218t.4~.·" 187~4~: 54.000 230.980.' '184:6.43 '. '597401~:45.N "37Q998;29 E, ,3.000: 300,366 ~'~~~T~š-§"i 5,[:, ·9ß33.36 7445.87 54.000 230.980' 6223;00 . 5Ø:.rO~26::92 N 366~H8.20'E ' '; 'O':OÒO ::·0.000 :.~1.1,5:24 ..':"'" ',' .,.' .'. ........."'--:'...........-!:-~- 6. :::·nø79.~2. 1446.46 68.005 343.743 '::71~2.96· .597Pþ81.PON .365478:.~O J: 6.50?: ":42t001.~·L.:~~2~~~~_ '7.. 'J12Ò1'.aò 121.98 68.005 343.743 '717tL64 . 59',70ß95.5S'N. '$65446~?4J~ "r<n~òo,:.·,:;:(t.þöò,,·,\,"':.~Q1AA1 ,8;,': :J,f~62.73,' '360.è3·"89~?1:1.':,·:?~~A~9":':72A~::71:, ,59~h022;20N., :36531:7.40:1; 6.500' ':':~3'~:~A;<~\~J64:01 :, ..... ,~:" _ " "', "', ~~"',~-',: ,............ .:.....'-......... -- _.- 1_.. . '. .- .' '._ '_.,'_... ,. .., .'.,'.. .,_·,._~1." ""'." .' ::>9T",' l1:~,Ø3.7,5 " .'21:.,Q2.:,':~~:2,1'1~:';':33~A~.9,. 7250.00 5971041.00 N 365308.00 E: ,0.000 ':":'.O,;bO(U::~¡.:;·~1?¡1.57 1'1;~t {~~~&'l~k:~ì·:~~;t~:~ 'i~~:: ':~;~~~~~:~::'~~i~~:¿b'~;'^'i:::M~ij;~~~~:~;',~~~ IP."~f'~~{fJxn·Q~I~~f"I~;--r~f.e. PtopCJSâfGJo./JalData' -CCJ2~30~øQ2-aO:¡(wp05) Convcrsion (:olnplcte 70 deg 19 min 43.714 see 151 deg 5 min 32.770 see Meridian: U TIIN R4E Section 10 148.70FNL 5131.30FSL 2595. 19FEL 2684.80FWL UTM Zone 5 X=571658.656188 Y=7803491.045062 70.32880940 151.09243607 COl1versionResults For: Heel Target ASP Zone 4: 365308 5971041 Con.version Com.pletl~ 70 deg 20 min 18.763 see 151 deg 2 min 27.548 see Meridian: U TI1N R4E Section 2 1864.85FNL 3415.15FSL 1527.44FEL 3752.56FWL UTM Zone 5 X=573555.887718 Y=7804637.775147 70.33854534 151.04098562 Conversion ]{csults :For: CD2-30 ¡\s.p Zone 4: 371712 5974492.75 Surface J.¿ocation ) ) Conversi.on 1~.csults I~'or: Toe Target ,ASP Zone 4: 3()3254 5975025 70.33959089 151.10968064 UTM Zone 5 X=570973.683002 Y=7804672.732141 Meridian: U TI1N R4E Section 3 I 1481.93FNL 3798.08FSL .. / 4713.63FEL 566.36FWL ,/ 70 deg 20 min 22.527 see 151 deg 6 min 34.850 see Conversion. Com.plete GEOLOGIC SUMMARY: Target 1 : Landi.._ Resp: David Shafer - 4. L. (TVD.SS) Porosity Perm 7,250' 0.195 Formation Alpine C X 365,308 y 5,971 ;041 Target 365,254 5,970,902 365,454 5,971 ,002 363,354 5,975,075 363,154 5,974,975 T t Sh Rectangular as defined above arge ape: Remarks: Target 2 : Toe Not Applicable Formation Alpine C L. (TVD.SS) Porosity Perm 7,220' 0.195 X 363,254.0 y. 5,975,025.0 T t Sh Rectangular as defineÔ above arge ape: . Remarks: Geological Prognosis: Responsible: David Shafer - 4284 Formation X Y Z MD Gross (TVD.SS) Thickness West Sak 1,000' Permafrost 1,550' C-40 2,161' 196' C-30 2,357' 375' C-20 2,732' 1,061' K -3 Marker 3,793' 201' Basal K -3 Sand 3,994' 28' K-2 Marker 4,022' 89' Base K-2 Cycle 4,111' 1,249' Albian 97 5,360' 530' Albian 96 5,890' 926' HRZ 6,816' 150' Base HRZ 6,966' 54' K-1 Marker 7,020' 42' Kuparuk Fm 7,062' 45' LCU-Miluveach 7,107' 83' Miluveach A 7,190' 17' Alpine D 7,207' 16' Alpine C 7,223" 87' Alp C above shoe 7,212' 74 Alpine A shoe 7,286' 10 Alp C above toe 7,198' 26 Alpine A toe 7,224' 20 Net Pay 86 Approx Stepout: Net Pay 45 Approx Stepout: Complete I-Jreferred Tar. Angle 88-89 7220 preterred· . Tar. Angle 90 8450 (}Þrnpk~t~ Net Pay Net to Gross o 10.5 86 73 25 Remarks: Geological Discussion: Responsible: David Shafer - 4284 Complete There are no mapped faults intersecting the' wellbore below the top Alpine D. Alpine A sands will be present below Alpine C at the shoe and toe. These sands may be difficult to differentiate from Alpine C. The Alpine C section thins toward the toe, but the section )s also thin on a local high at the landing point. The well will be steered from the office to the landing depth;)wo wellsite geologists will be used thereafter. 1:48000 FEET 0 2000 FEI;~T I , '; Top Alpille C Structure Without Faults Alpi.ne A&C Isoch.ore . Attril)ute Calibrated. , FEltT FEET p L ~,t!\JlI1rl/"\lllu.o~.,t'I"K'M't"II:·r-<lO'ffi'JI~~r-""~~fll!'-·j\;.W... :...."'·'111'.....- 1~I~M,",,"I""'tII'j1':L\I'~I~~ ConocoPhillips Alaska, Inc) Post Office Box 100360 .. Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ) ~.. ConocoPhillips July 29, 2003 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 JUL 3 0 Re: Application for Permit to Drill CD2-30 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the Alpine CD2 drilling pad. The intended spud date for this well is August 15, 2003. It is intended that Doyon Rig 19 be used to drill the well. CD2-30 will be drilled to penetrate the Alpine reservoir horizontally. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as an open hole injector. At the end of the work program, the well will be closed in awaiting completion of well wõrk and facilities work that will allow the well to begin injection. Note that it is planned to drill the surface hole without a diverter. There have been 38 wells drilled on CD1 pad and 37 surface holes drilled on CD2 pad with no significant indication of gas or shallow gas hydrates. All of the wells on C02 have surface casing shoes within a 2000' radius of the planned surface casing shoe of C02-30. It is also requested that the packer placement requirement be relaxed to place the completion packer 200ft TVO above the Alpine formation. This will place the completion at a maximum inclination less than 65° and allow access to the completion with standard wireline tools for future intervention. Please find attached the informati0l\t required by 20 ACe 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 1 0-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. 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 AOGCe is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling flu'itis handling system. 3. Diagram of riser setup which replaces diverter. OR\G\NAL If you have any ques'.~11S or require further information, plea~. contact Zane Kuenzler at 265-1308 or Chip Alvord at 265-6120. Sincerely, Ä W~.,{b3 Zane Kuenzler Drilling Engineer Attachments cc: CD2-20 Well File / Sharon Allsup Drake Chip Alvord Vern Johnson Cliff Crabtree Steve Moothart Nancy Lambert Lanston Chin e-mail : ATO 1530 A TO 868 ATO 802 ATO 848 ATO 844 Anadarko - Houston Kuukpik Corporation Tommy_Thompson @anadarko.com , . ,'\ .,~ . - \\ ......'.-.-." \....\ '\ \ -- - ...... ~ ¡ / "~ CD 2-.32 "':' -...........~ '. ......... \ "", \ ~ V // ~) ) . "'-_ ~ ._.~._\ ", \ '. "1 '\ ~;/ GO 1-.32PH ~-42 Þ , , ,,\ '. -"", -~ "" \ ¡ ~ : C02-JJ8 '!: _.~ \ \:---.~" \ \ \ 1/". .-;,' - '. CC. """ \ ~ 'ì' / CD2~,30Q '\ ----r- ¡ '\ --._ ~ ", ' // /\ ~A/ " " '.''' \ ~*- I \ \ \ --+-- -- '" " \ \ // / . - "/ '. ' ' \ - \ \, j>. ~ ¡ \ \ \' ~ ~ ".. ;__ /_ ' . \ \ \ \ '\ \.".' , /.",~-.;>Ii ¡ \ ' \ \. ! :'\, \ \ \ CD 1-.36PH ~~-...=.~..: '" - .;- ~.; \ \ ,"" \ \ \ ' ;cr ~ ~, ~. I\.\ \ ~7" \ ~ \ \ \ .~\~.-' / ,lIX\~\~~ \~ : \ \' f -# /Í \\ ~_____. ~ \ \ ' ~ /1 ;1 \\ "- : \ .--/____~~# \ /I! \ ~2~~ ~9t. ~HI ø(/; ¡(. I ~\I~:\ ~ ._.:./~/~\ ,//:Ç'\ N; ;~\ \ ~~-- '1~ ~\ 1<\; ~/' \\ ~\CD~: 0....-1 'y-__: . ~ '^ _~ ~~~l- _ \ I!\ \ \ \" \ ./ \ 1 . 0.._--- . \ - 'í ¿ .' --\--.. I J \ \ "'~.~ \ \ \ ~: .' if \! "-T /..---..- ,->--' nm. -\;J:' \ / fDI a : / \. v' \ CD2f\.42'Sq~ \\; \' \ C -J~ \ "- \. CD 4S' \ \\ / \ I: \ !~ \. \r ~; .}"PINE 18).. "" \ CD~~ CD1- 9PH1 15\ \ / \ !C02-4? \. \ ~D2- -. '\ . CD2-3.3A,4 : CD2-40 b {i _ \ \ \ \. \ J "" \ \ \ \.\ ¡ ¡ \ \ I I \ \ \ ", \ \ I' \. " , : \ \: \ \ \ \ 'l~ . ..L. \[ \. \. ~ \ C02-J9'" \ \ I \. CDH7' I '. '\ \ \ Î\' \ "\ \1 \ ! -------i\---+--~.J 'iGD2-Ja'b \ \ 1GDH9t,¡ ~ ¡ i \ N!oVE 1-9-\ I \T i '1- .\-.-.. --- .-- ---- \ \. : \ ! - \ \ CD2-4a ~\ I \ --- ~'--\.'- -- \- ¡ \ : \ CD2-4>' \ ~ \ \ GD~~~'\-:Dr-~:\--:- ---.- I \ \ ~-S8 L1\¡ CD2-S2\' ¡ / ,:,,' r \ \ ;\ \\ r /'.. _ I! \ \ 1 ' CDI-j229'- ¡ \ \ j \ \ I I \ i \ \ Feet ) CD237~1~ \ I \\ \ I u,uOO " \ 0 2,000 ' I \ r \ CD2-S8 0 380,000 4,000 6,000 8,000 \1 \ I V)) \" ~-- \. ,,~-:\ ~ " &G02-32 to, ----.-'J'. .},. - v ' \.» '\ ,if' \ \ " '-.Æ'"\ ',-- \..? ",:."" \ \ \ . J "" G02-338 f/ "--.._____..9\ 2; -~~_ ¡"--S' y'\ )>- . \ ~~~ ",p'n -32PH ~t CD~-.30 Y \, '--_~ ~' \~........... o:¥\ ¡ \ .,./ / ~- ~~~ ~ CIJ.i 1 . f \ \ -.", '--. ~" '-p \ /, j)óo~ '-, '~; \ \ \ _~__ ~~'l. ~ß'\ ' A \ _ø't~ ,'- ,¿t \ i , \ \ ~ ¡;¡ ,r ~' ~13'! Y J :'. " , ' '. ,_ ~ C'5 ' , \ \, \ ~ r .~.........' '. .., <[D 'ð\ \ \ \ \ ." \ _--..;:0_ - - ft ~J \ \ , ,\ ~_-.:-~ ' ':v'" \ \ \ \ '. ,þ :J -', ' . \ , ' . ,~", n._ ._'" ,§ \ ' \ " " .- %. . ,~ ' \ 1 \ \ ., (j;> ~ 0/ . -- W·' "''' \ \ \ 1 \ \ ',Æ>_ ~~ .. ,~ ' --~ ~.\ æ C) \ \ ! \ \ /'~' "" / tfbu ,~ ~~ ,I; ¡,,»trJ.v § \ \ I \ \.------- ,,/ 2 .'_ '. ~"/" ,\ . JjL ~#;q- ~\ - \ C> \ ! \ /.A ~ <. y ''1' _ . ~' ?Or- \ C> : \ ~ ~ \ " '" '. ort ' ( .)., . ,. ""- ' '\' ß ------- & \- , ~~ 'r,,"-o /_ \ G02 341'4Þ ^ ~ <j ->,-- \ .....__--*\-----: L'b7,,--:";b4:" ':1 .' 'b \<¿~1. \: \ \i~~\\~ýj' ß \ ~---...@2-29~ I, _ ~. ,// /~% ~ CJ / /"0 ~ ; :l. A<jj<) \ ~ . \1 .... \ ---------- ,6 -l?~_.__._.- \ ~/~ /-:_.~j1oo~ L~ 1"VD ~ '. d"';)'0 -..~~ - .::-19~ " ______/ '" ...."'-_ -p I'. V(j;¡ \ . ' I 'I ~' \" co - -. {J --...... -f) " o .r---' '?, .'" ......, <Þ--A/, .... \ . \ ~ _t,~ - üß . : "-- .... ,\0/ 0"'" '" .' ,-0 "-'. jI..""-' ," _ 0_ /_____ I' I Y'<f' ~ /' \ '0 ~-;¡ -- ~ ...,-. · 50 5°F . ",,<:P- ~\.'--.., \ )~~.~ I -/ I(' ,,\ \ / "a.. 'M -y-'- ........J...._ \ "~~- \ ' '" en / ' /0" Ä "0/ /J\ . ,I ì i '--\---- '\. ,0 ~ 'ô "' i /"\4"q, \ I \ \ \ \ fuaa #-.~-t<;; ::..:::0,. <iF ð ¡ /~ \." \. I , \ I "~Ù \ ~ 6)lfbD2-39 p) ~ \\;~, ~ ~\' Va \ \, '1 f¡¡¡V!) , . 'a¡: '81 '\ \" '\.. ¡ . V \ \/ '\ "\ 4 0 -\00 \ .1\1fjJ{J \ \ .....;...... \........... ,7 . ^ \ . ' . J;'.' ! / \.,1 \' G02¡~ J G02-"" UO ! \ \. \~~ <5:'\ ...... .I \./ \ ( 1000 . í \ \ \ 0_ 35~" ! -' \ /. \ 'i~üß\ \ \1<fF' '\ /.;/oq, \ . /-TJ( \ ~ \ .' ~,\.,I \ \t.LPINE 18 t.. \. G02-.3JA« 1 \;' ~02-42 · ()/){) \ '~ \ : CD2-40 b \. \. - 500°1 \ .... \ \ GO~ i . \ \ i \ \ I \ \ 50\'01 \ - ~ ':110 \. \ \\ i \ MOO \ \ ...... _ ~+ -_~b~ ~~ . (ì "'/ \ \ '\ '\ \ \ r.n?-:>¡~ <-.t-. ' ,.... 0. "" ~ '!.\' \ \ '\ F t \/ ;).-1:,"':> II\. I ____. _____. \.. __ \ ¡ \ I ' ee ~ -::> v.-~ ~ \ ~_.. ~~ ,~~ 7i 501)01 . ~ 1?'t1:::>'F-~ ""'" . \ ~ . --- _:...ß!JlliL_ ¡ 0 - 1 ,000 2,000 ' +Vp O.ç;:... À-\ ì ~e' NBlE j J '\ ~~Jlo.C_=:::"""""'~ 3,000 4,000 ~ ~ \ ,\ ---- 10 .- ¡¿n:..~ [ ( (~ 360,000 I - . JUL :] {) 7003 ..... CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars '-, 'OOW"~ 0", 0,*",. ,->< oc '"" (7. " MEMO ( Ùd- - 3()_Jt-~b_d!£¡ci2cL I: 0 ~ * * 0 0 * L. L.I: 2 * BODO 0 L. 2 7 2 5 7111 * 0 5 5 .- I $ (DQOÒ ~~~~~ 6~E Sf I!:r e or .4 L-I/<;fUt !lfcqCL ~~L~ ck~ ;J~C) fao DOLLARS ~ ~~E~:::.' 62-14/311 "/50/0-:5 DATE s. K. ALLSUP-DRAKE CONOCOPHILLlPS 711 G STREET - A T01530 ANCHORAGE AK 99501 1055 ) TRANSMJT AL LETTER CHECK' LIST CIRCLE APPROPRIATE: LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER . . WELL NAME (' \) )~ ~D PTD# dO ~- \'~ ç CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number. stated above. HOLE In accordance with 2.0 AAC 25..0.05(1), all records, data and logs acquired for the pilot hole must be clearly differentiated In both name (name on permit plus PH) and API number (56 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject ·to fuD compliance with 2.0 AAC 25..055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 3.0' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL. -PERM IT·· CHECKLIST Company _.CQNQCQPlitLLIE?S .A.l,.A.SM_l.r~tC__~___..._______.___.__ __ __.______________._ __ ___.____ PTD#: 2031350 Field & Pool _~QL,~L,_L.E:J3L\l¡;8,_A.L,Plb1E Ql.L_.:.J2PJJLO Initial ClassfType Administration 11 Permit fee attached . . . . . . . _ y~s . \2 Leas.e.number .appropriate. _ y~s _ 13 Uni.que well. nam~ .ancl r:ll.Jmb.er _ _ . . . . . . . . Yes . !4 WeJIJQcat~d i.n.a. d.efine_d .pool_ _ y~s _ 15 WeJIJQcated proper _di_stance.from. drilling unit. b_ound9ry y~s . 16 WellJQcated proper .di.stance. from Qther wells y~s 7 _S_ufficient9creage.avaiI9ble in.dril.ling un.it . . . . . . . Yes _ 8 Jf.deviated, is. weJlbQre plQUnc)uded Yes 9 .oper:ator only' affectecl party. _ . y~s 1 0 .Qper.ator bas. apprppriate. b.oncl in .force _ _ . . . Y ~s 11 P~rmit. can be i.ssu_eÒ withQut co.nservation order. . . . . . . . . Yes . Appr Date 12 Permit. can be i.ssu.ed withQut ad.ministr:ati\le.apprpvaJ . . . . . . . . . _ _ . . . . Y~s . . . . . . . _ SFD 7/31/2003 13 .C.an permit be app.rov~d before 15-Òay. wa.it. . . . . . . . . . . . . . . - . . . . . . . . . Y~$ . 14 .Well JQcat~d wi.thin area and_strata authorized by InjectiOn Ord~r # (put. 10# in. COr:n!11~ots). (For. Y~$. 15 .A)I wel!s. witnin J l4. mite _are.a. of review id~otifiecl (For: servjc~ welJ only.). . Y ~s . 16 Pre-produ.ced. injector; durat.io.n .of pre-productiOn I~$s. tnan. 3 months. (For .ser:vi.ce welt Qn)y) . _ No. 17 ACMP. Finding.of Con$i$t.ency.has bee.n .issued_ for tbis proiect . . . .NA. . Well Name: C.OL'iILLE.J3JY.UNtT. CD2-.3Q_._________.___ __ Program SER._._..._________ _..ß.E;RLPEJ~~P_ GeoArea ß.9_Q___.___._...___ Unit _5_0~_6.º__.__... On/Off Shore _QO.___.__ [] [] Well bore seg Annular Disposal . - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - ( _ . Area Inje.ctio.n.QrderNo.. t8A_ . . . . . . . . . . CQ2-33A~ CD2-~0 wiJhJn 1/4 r:nHe . . . . . . . . _ . . . . . . . . . . - - - - - - - - - - - - - - - - . - - . _ Exis.ting project. _ _ - - - - - - - - Engineering --..-.------.,---.,---.----..-----.----....--------- ~ - - - ~ - - - - - - - - - Appr Date TEM 7/31/2003 ~~t~\ --.------- ---.-.---.--,-.---------.--.-,---,---,.,--.--,-.-,------.-- 18 .C.onclu.c~or st(ing.pfQvi.decl . . . . . . . . . . . _ . . . . Y~$ . . . . . . . . . . . _ . . . _ _ . . . . . " . . . . . . . .. _. _ . . . . _ . 19 .S.urfac~ .casing_ p.rotec.ts all_.known. USPWs . . _ . . . . . NA _ . ~o ç¡quifers per AIQ 18A conclusiQn.3. . _ . . . _ . . 20 "CMT v_at adequ.ate.to çirc_ulate_on .cond.uctor. & su.rf.CSg .. . .. _ . " . . . . . . . . . . . . _ _ . _ . _ Y~s _ . . . . . . . . . . . . _ . . . _ _ . _ _ . . . . . . _ . _ . . . . . . . _ . . . . _ . . . . _ . _ _ _ . . 21 .CMT.v.otadequ_ateJotie-i.nJQng$tringto.s!Jr1CSg_""" _ _ _" _ _ _" _"" _"""""""..""" No_"."" _ _ "ðnn_u'-ardi$p.o$alwlllJils.e.ly.l~e"requ~$tecl."""" _" _ _ _ _ _ _ _"."."..... _ _ _" _ _ _ _ _ _"""....."". 22 CMT will. çover.aHkno.wn_pro.duçtive bQrizon.s. . _ _ . . . . . _ . . . . . _ No. . _ . Qpe.n.hote"completi.on pLanned.. . . _ .. . _ _ _ . . . _ . . . . . . . . . . . . _ . _ . _ _ _ . 23 .C.asiog de.si-9ns ad.eQlJé1.te. for: C..T~ 13 .&. permafr:ost. . " . _ .. _ . " _ . . . . . .. . _ . _ Y~$ _ . " . . . . .. ." _ " _ _ . . _ _ . . . . . . . . . . . . _ _ _ . . . _ _ . . . . . . . . . . . . . . . . _ . . 24 .Adequ9t.eJan.kage_one_serve pi~. ....... _ _ . . . . . . _ . . . _ . . . . Y~$ . Rig .is.e.quippe.d.w.itb st~el"pi.ts.. NQ. re$eNe., pjt.planne.d .wa$t~.to ç¡n approved. annulus or _disposal. weJ!. 25 .If.a. re-d(iH. nas..a_ 1.0.::-403 for ~bandonment be~o ç¡PPfQved .. . .. . _ . . . NA _ . _ _ _ _ . . _ _ . _ _ .. . .. . _ . . . 26 .Adequat.ewellb.ore. separç¡tion .proposed. .. . . . . . . . . " . .. . . . . Y~s . . . .. . . . Prp~imiJy.. an91ysis perfOrn}e.d,_ Traveling çy'lioder patb ca.lGul_ate.d, Byrps PQssiþle.. _ . " . _ . _ . . . _ .... _ _ . 27 Jf.djver::ter .require.d, OQes jt meet. reguJa.tions. . . . _ NA _ .. . . . . . Qiyerter waiyer nas_ b_een given.for.GD..2.p.aO._ _ _ " . " .. .. .. . " . " . " . .. . 28 .D.ril.ling fluid_program sc.hernatlc.&.equipJist.adequate_ _ .. . . _ _ . _ . . . . . . _ Y~$. . MaximurT) expected formation. pressur~.8XEMW._ Planned.9,6.to 9.8.ppg to_set?"." . 29 .S.oPEs..d.o .they meet. reguJa.tion . _ . _ _ _ . . . . . . . . . . _ . . . . . _ Y~s . . . . _ _ _ _ . . . .. _ . . . . . . . . . . . . . . . . _ . _ . . _ . . . . . . . . _ . _ " . _ _ . _. . _ . . . . _ 30 ).S.o.PEpressraJiogappropriate:.testto.(pu.tpsigin_comments... .... Y~s.. .MASPcaIGu!ate.d.at25.7~psi.. 35QO.psi.a.ppropri.ate.. pp.Co_u$uaJIy.t~$tsto.5.000psi.. _......... 31 .G.hoke.manjfolcl CQmpJies. w/API.RP-53. (May 84). . .. _ _ _ _ . . . . .. . .. Yes_ .. . . . . . 32WQrk wil.l pcc.U( without.operation _sbutd.own. . . _ _ . . .. . . Y~s . . . _ _ . . . _ _ ... .. _ . . . . . . . . . .. . _ . . _ " . . . . . . . . _ _ _ . . 33 .Is presence. Qf H2S gas. PJob.aþle. . . . . . . . . . . _ . . . . " . . . . . No. _ . . . . . . ðUbe top oUhe. Alpine. th.ere.a.re OQ penetra.tions.within .1l4.miLe. CD2-.40 has. not Þeen "completed. y'et.. . 34 Me.cba.ni.cal.cpod.iti.on oi we.lIs wi.thin AOR yerified (fpr.s.e(Vice wel! on.ly.). . Ye$. .. CD2-4Q wilJ Þe withjn 1/4 r:niJe. when .drilled.. MIT_1t an.alysis fOf ÇD2-~Q wi]1 .conJirrT) i$olçltion.. ( Geology -.-....-----,-...-. ,-.--.--..--,.--.-------, - --.,-----. --."~-,_.....,_._-_.._....__._..._.._,--_.__._---'"-,~_.__.....,,-----.._".__.,_....~-_.__... "...,~._._.-..,- ,--"-.._--_.,,,--- .. ~ - - - - . - - Appr SFD Date 7/31/2003 Geologic Commissioner: DT~ __..____._,___...._______,.____.__...,__.___0____'__ __,_. .____h..'__.__..____...____._.._.._,_________.__,.,,____.__.....__..__....____,.,___...______ 35 P~(mit. c.an be i.ssu.eÒ wlo. hyò r.og en. s.ul..fide l)1E:¡aS!Jr:es. . _ " . . . . _ . . 36 .D.ata"p.reseoted on. pote.ntial overpres.sure _zones "." _ . . .. . . . . . 37 .S~Lsl)1i.c.analys.is_ Qf sha.llow gaszoDes. .. 38 S~ab.ed.cond.itipo survey.(if oft-sho(e) .. . . . . . . . _ . . . . . _ _ . .. . . . . . .. . _ . . . _ . 39 .. CQnta.ct narn.elphoneJor.weekly prpgressreports [exploratpry "only]. . .. ..... _ . _ Y~$ - . . . . . Y~$ '. NA .. NA NA .. - - - - - . ~ _ _ . _ _ _ _ _ _ _ _ _ d . ~on.e .expe_ct.ed.. Res~(Voir press.ure. expecte.d.is 8.7 ppg. EMW;. will be. dri.lled" wit.h .9,0. - ,,9.,3 ppg _mud.. . - - - .. - .. - - - - - - - - , - - - - - - - - - - . .. - - - - - - - -. - - - - - - - - - - - - - - .. - - . . - . - - . - - - - - - - - - - - Date: 7/3(/3 Engineering Commissioner: Date Public D; / 0' ~ <.-is.,.service well will be a WAG injector. Operator plans to drill well without a diverter. eommisSioneS7' í ( -5/ / ~ ) ') Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim'plify finding infomlation, 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. ~13 -/3!S ~..... ) ) , ..... ¡>' ) Sperry-Sun Drilling Services LIS Scan Utility -/" I ' $Revision: 3 $ LisLib $Revision: 4 $ Thu Dec 18 15:02:26 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/18 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 colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-30 501032046500 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 18-DEC-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002601675 R. KRELL G. WHITLOCK MWD RUN 3 MW0002601675 R. KRELL D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 llN 4 E 1865 1527 MSL 0) .00 52.70 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3006.0 6.125 7.000 11485.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). RECEiVED 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). DEC 22 2003 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. Alaska Oil & \.:.i&S COns. LommÎS8iOn Aochoœge ~~~r\'\~ , ) ) 4. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). RUN 3 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE. THE WELL WAS TEMPORARILY SUSPENDED AFTER RUNNING THE 7" CASING (AFTER RUN 2) DUE TO A POOR CEMENT JOB. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 6. MWD RUNS 2 AND 3 REPRESENT WELL CD2-30 WITH API#: 50-103-20465-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15700'MD/7268'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/12/18 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2974.0 2974.0 2974.0 2974.0 2974.0 2982.0 3017.5 STOP DEPTH 15651.5 15651. 5 15651.5 15651. 5 15651. 5 15644.5 15699.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3 MERGE TOP 2974.0 11499.0 MERGE BASE 11499.0 15699.5 ') ) # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value............... ...... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2974 15699.5 9336.75 25452 2974 15699.5 ROP MWD FT/H 0.12 564.26 173.384 25365 3017.5 15699.5 GR MWD API 31.63 421.12 97.5702 25326 2982 15644.5 RPX MWD OHMM 0.07 2000 11. 628 25356 2974 15651. 5 RPS MWD OHMM 0.08 2000 12.9441 25329 2974 15651. 5 RPM MWD OHMM 0.1 2000 15.349 25329 2974 15651.5 RPD MWD OHMM 0.23 2000 20.0793 25356 2974 15651. 5 FET MWD HOUR 0.12 1227.04 5.26329 25356 2974 15651. 5 First Reading For Entire File......... .2974 Last Reading For Entire File.......... .15699.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/18 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOl Corrunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 2 header data for each bit run in separate files. 2 .5000 START DEPTH STOP DEPTH ) RPX 2974.0 11456.5 FET 2974.0 11456.5 RPD 2974.0 11456.5 RPS 2974.0 11456.5 RPM 2974.0 11456.5 GR 2982.0 11464.0 ROP 3017.5 11499.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 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 (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 Da ta Record Type.. . . . . . . . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record.......... ...Undefined Absent value..................... .-999 Depth Units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 01-SEP-03 Insite 66.37 Memory 11499.0 3016.0 11499.0 47.1 76.7 TOOL NUMBER 132477 13 67 4 9 8.500 3006.0 LSND 9.80 43.0 8.8 300 4.0 2.200 1. 330 2.000 3.750 84.0 152.6 76.0 76.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 ') ) RPD MWD020 FET MWD020 OHMM HOUR 4 4 1 68 1 68 24 28 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2974 11499 7236.5 17051 2974 11499 ROP MWD020 FT/H 0.46 564.26 206.687 16964 3017 . 5 11499 GR MWD020 API 43.74 421.12 115.723 16965 2982 11464 RPX MWD020 OHMM 0.85 2000 6.03524 16966 2974 11456.5 RPS MWD020 OHMM 0.12 2000 6.12815 16966 2974 11456.5 RPM MWD020 OHMM 0.23 1029.36 5.73092 16966 2974 11456.5 RPD MWD020 OHMM 0.23 2000 11.7921 16966 2974 11456.5 FET MWD020 HOUR 0.12 52.08 0.681894 16966 2974 11456.5 First Reading For Entire File......... .2974 Last Reading For Entire File.......... .11499 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/18 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 11457.0 11457.0 11457.0 11457.0 11457.0 11464.5 11499.5 STOP DEPTH 15651. 5 15651. 5 15651. 5 15651. 5 15651. 5 15644.5 15699.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 28-0CT-03 Insite 66.37 Memory 15700.0 11499.0 15700.0 79.8 92.4 # ') TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ 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 (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..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing......... ........... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') TOOL NUMBER 129046 159439 6.125 11485.0 Flo-Pro 8.85 47.0 8.8 20000 11.2 .300 .130 .230 .340 70.0 167.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11457 15699.5 13578.3 8486 11457 15699.5 ROP MWD030 FT/H 0.12 232.5 106.136 8401 11499.5 15699.5 GR MWD030 API 31.63 113.84 60.7377 8361 11464.5 15644.5 RPX MWD030 OHMM 0.07 64.15 22.9376 8390 11457 15651.5 RPS MWD030 OHMM 0.08 1098.63 26.728 8390 11457 15651.5 RPM MWD030 OHMM 0.15 2000 35.9245 8390 11457 15651.5 RPD MWD030 OHMM 0.47 2000 36.8375 8390 11457 15651.5 FET MWD030 HOUR 0.31 1227.04 14.5277 8390 11457 15651.5 First Reading For Entire File.. ....... .11457 Last Reading For Entire File.......... .15699.5 File Trailer Service name............ .STSLIB.003 ) ) Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .03/12/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 2 11/7/05 AG DB C.A. PER K05146ACS 3 11/08/06 CZ GD PER K06058ACS 34 J Z 35 36 P r, 32 3 DR L SIV - 6 G) T12 T11 N Y J W_ 2 O ELI 6 5 0 V Lj VICINITY MAP (NTS) PLANT N O CD2 -01 CD2 -02 ASPC 0 CO2-03*CD2-04 N O CD2-05,CD2-06 r� CD2 -0700O2-08 6°03'35" D2-09 .CD2 -10 • CD2 -11 . CO2 -12 CD2 -13 0CD2-14 CD2 -15 *.CD2 -16 CD2 -17 00O2-18 CD2 -19 0CD2-20 CD2 -21 0 CD2 -22 LCM F CD2 -230 cD2-2a CD2 -250 C12-26 a CD -2 02-27: CD2 -28 PAD CD2 -29 . CD2 -30 CD2 -31 .CD2 -32 CD2 -33 00O2-34 D2-310 CD2 -36 CD2-37:CD2-38 LEGEND: DD2-39• 10' O PROPOSED CONDUCTOR CD2 -41 O.CD2-42 1 CD2 -430 • CD2 -44 • EXISTING CONDUCTOR CD2-45:CO2-46 CD2 -47: CD2 -48 NOTE: coz-a1 CD2 -50 02-51 • NO CHANGE TO CONDUCOTR LAYOUT CD2 -530 SINCE 4/9/2004. S CD2 -54 1)2-550 CD2 -56 CD2 -57 . CD2 -58 CD2 -59 0 CD2 -60 T E]KUUKPIK IMMFul. 139 E.51d Aw. - Andmm%Ala" 99503 - (907)2731590 Alpine Office (90]) 6]04739 Alpine Survey Office �.� ALPINE MODULE:CD20 UNIT: CD Cin®c®Phiips ALPINE PROJECT CD -2 WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CADD FILE N0. DRAWING N0: PART: REV: 01-02-05-1 05-27-1 CD—CD20-121 1 OF 3 3 REV I DATE I BY CK APP DESCRIPTION IREVI DATE IBYI CKIAPPI DESCRIPTION 0 5/29/01 G. D. J. Z. C. A. PER A01004ACS 6 4/13/06 CZ BD I C.A. PER K06058ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.2, T 11 N, R 4 E, U. M. SEC.LINE 0/S PLAN WELL Y' X' LAT.(N) LONG.(W) FNL FEL GND PAD i* i* I* CD2 -1 5, 974,781 .09 371 681.81 70° 20' 21.594" 151 ° 02' 28.574" 1577' 1562' 8.7 15.9 CD2 -2 5,974,770.84 371 682.85 70° 20' 21.493" 151' 02' 28.539" 1587' 1561' 8.7 15.9 CD2 -3 5,974,761.44 371 683.77 70° 20' 21.401" 151° 02 28.507 1597' 1560' 8.7 15.9 CD2 -4 5,974,751.48 371,684.73 70° 20' 21.303" 151° 02 28.474 1606 1559 8.7 15.9 CD2 -5 5,974,741.17 371 685.60 70° 20' 21.202" 151 ° 02' 28.443" 1617' 1558' 8.7 15.9 CD2 -6 5,974,731.13 371 686.73 70° 20' 21.103" 151 ° 02' 28.406' 1627' 1556' 8.7 15.9 CD2 -7 5,974.721.46 371 688.17 70° 20' 21.008" 151' 02' 28.359" 1636' 1555' 1 8.7 15.9 CD2 -8 5, 974 711.45 371 688.72 70° 20' 20.910" 151' 02' 28.337" 1646' 1554' 8.7 15.9 CD2 -9 5,974,701.48 371 690.14 70° 20' 20.812" 151 ° 02 28.291 1656' 1552' 8.7 15.9 CD2 -10 5,974,691.64 371 691.07 70° 20' 20.716" 151 ° 02' 28.259" 1666' 1551' 8.7 15.9 CD2 -11 5,974,681.62 371 692.02 70° 20' 20.617" 151 ° 02' 28.226" 1676' 1550' 8.7 15.9 CD2 -12 5,974,671.61 371 692.98 70° 20' 20.519" 151 ° 02' 28.193" 1686' 1549' 8.7 15.9 CD2 -13 5,974,661.90 371,694.26 70° 20' 20.424" 151° 02' 28.151" 1696' 1548' 8.7 15.9 CD2 -14 5,974,652.12 371,695.50 70° 20' 20.328" 151° 02' 28.110" 1706' 1546' 8.7 15.9 CD2 -15 5,974,641.66 371,696.24 70° 20' 20.225" 151° 02' 28.083" 1716' 1545' 8.7 15.9 CD2 -16 5,974,631.95 371,697.39 70° 20' 20.130" 151° 02' 28.044" 1726' 1544' 8.7 15.9 CD2 -17 5,974,622.10 371,698.48 70° 20' 20.033" 151° 02' 28.008" 1736' 1543' 8.7 15.9 CD2 -18 5,974,612.15 371 699.38 70° 20' 19.935" 151 ° 02' 27.976" 1746' 1542' 8.7 15.9 CD2 -19 5,974,602.64 371 700.50 70° 20' 19.842" 151 ° 02' 27.939" 1755' 1541' 8.7 15.9 CD2 -20 5,974,592.18 371 701.77 70° 20' 19.739" 151 02' 27.897" 1765' 1539' 8.7 15.9 CD2 -21 5,974,582.28 371 702.51 70° 20' 19.642" 151' 02' 27.870" 1775' 1 1538' 8.7 1 15.9 CD2 -22 5,974572.39 371,704.15 70° 20' 19.545" 151° 02 27.817 1785 1536' 8.7 1 15.9 CD2 -23 5,974,562.21 371,704.52 70° 20' 19.445" 151° 02 27.801 1795 1536' 8.7 15.9 CD2 -24 5,974,552.30 371 705.92 70° 20' 19.348" 151 ° 02 27.756 1805' 1534' 8.7 15.9 CD2 -25 5,974,542.33 371 706.81 70° 20' 19.250" 151 ° 02 27.725 1815' 1533 8.7 15.9 CD2 -26 5,974,532.34 371 707.80 70° 20' 19.152" 151° 02 27.691 1825' 1532' 8.7 15.9 CD2 -27 5,974,522.31 371,709.10 70° 20' 19.053" 151° 02 27.648 1835 1531 8.7 15.9 CD2 -28 5,974,512.60 371 709.87 70' 20' 18.958" 151 ° 02 27.620 1844' 1530' 8.8 15.9 CD2 -29 5, 974 502.63 371 711.26 70° 20' 18.860" 151' 02' 27.575" 1855' 1528' 8.8 15.9 CD2 -30 5,974,492.75 371 712.00 70' 20' 18.763" 151' 02' 27.548" 1865' 1527' 8.8 15.9 CD2 -31 5,974,482.74 371,713.04 70° 20' 18.665" 151° 02 27.513 1875 1526' 8.8 15.9 CD2 -32 5,974,472.57 371 714.18 70° 20' 18.565" 151 ° 02 27.474 1885' 1525 8.8 15.9 CD2 -33 5,974,463.34 371,715.28 70° 20' 18.475" 151' 02 27.438 1894 1523 8.8 15.9 CD2 -34 5,974,452.65 371 716.13 70° 20' 18.370" 151 ° 02' 27.407" 1905' 1522' 8.8 15.9 CD2 -35 5,974,442.90 371 717.49 70° 20' 18.274" 151 ° 02' 27.363" 1915' 1521' 8.8 15.9 CD2 -36 5,974,433.20 371 718.42 70° 20' 18.179" 151 ° 02 27.331 1924 1520 8.7 15.9 CD2 -37 5,974,423.05 371,719.40 70° 20' 18.079" 151' 02 27.297 1934 1519' 8.7 15.9 CD2 -38 5,974,413.52 371 720.66 70° 20' 17.986" 151' 02 27.256 1944' 1517' 8.7 15.9 CD2 -39 5,974,403.28 371 721.83 70° 20' 17.885" 151° 02' 27.216' 1954' 1516' 8.7 15.9 CD2 -40 5,974,393.27 371,722.68 70° 20' 17.787" 151° 02' 27.187" 1964' 1515' 8.7 15.9 CD2 -41 5,974,383.33 371 723.84 70° 20' 17.689" 151 ° 02' 27.148" 1974' 1514' 8.7 15.9 CD2 -42 5,974,373.69 371 724.77 70° 20' 17.595" 151° 02 27.116' 1984' 1513' 8.7 15.9 CD2 -43 5 974 363.45 371 725.60 70° 20' 17.494" 151' 02 27.087 1994 1512 8.7 15.9 CD2 -44 5,974,353.42 371 726.94 70° 20' 17.396" 151 ° 02' 27.042" 2004' 1510' 8.6 15.9 CD2 -45 5,974,344.11 371 728.07 70° 20' 17.304" 151 ° 02 27.005 2013' 1509' 8.6 15.9 CD2 -46 5,974,333.52 371 729.06 70° 20' 17.200" 151 ° 02' 26.971 2024' 1508' 8.6 15.9 CD2 -47 5,974,323.53 371 730.13 70° 20' 17.102" 151 ° 02 26.934 2034 1506 8.6 15.9 CD2 -48 5,974,313.77 371,731.19 70° 20' 17.006" 151° 02 26.898 2043 1505' 8.6 15.9 CD2 -49 5,974,303.80 371 732.05 70° 20' 16.908" 151' 02 26.868 2053' 1504' 8.5 15.9 CD2 -50 5,974,293.84 371,733.00 70° 20' 16.811" 151° 02 26.836 2063' 1503 8.5 1 15.9 CD2 -51 5,974,283.88 371,734.28 70° 20' 16.713" 151° 02 26.793 2073 1502 8.5 15.9 CD2 -52 5,974,274.18 371 735.18 70' 20' 16.618" 151 ° 02 26.762' 2083' 1501' 8.5 15.9 CD2 -53 5,974,264.07 371,736.31 70° 20' 16.518" 151° 02 26.724 2093 1499 8.5 15.9 CD2 -54 5,974,254.19 371 737.50 70° 20' 16.421" 151° 02 26.684 2103 1498 8.5 15.9 CD2 -55 5,974,244.05 371,738.44 70° 20' 16.322" 151° 02 26.652 2113' 1497' 8.5 15.9 CD2 -56 5,974,234.27 371 739.42 70° 20' 16.226" 151 ° 02 26.618 2123' 1496' 8.5 15.9 CD2 -57 5,974,224.26 371 740.55 1 70° 20' 16.128" 1 151 ° 02' 26.580" 2133' 1494' 8.5 15.9 CD2 -58 5,974,214.18 371 741.60 1 70° 20' 16.029" 1 151 ° 02 26.544 2143 1493 8.5 15.9 CD2 -59 5,974,204.48 371 742.95 1 70° 20' 15.934" 1 151' 02' 26.544" 2152' 1492' 8.5 15.9 CD2 -60 5,974,194.47 371,743.77 1 70° 20' 15.835" 1 151° 02 26.471' 2162' 1491' 8.5 15.9 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) 3. * INDICATES DATA PER LOUNSBURY AS -BUILT. 1r/ ALPINE MODULE:CD20 UNIT: CD ConocoPhillips ALPINE PROJECT CD -2 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE N0. DRAWING N0: PART: REV: 01-02-05-1 05-27-01 CE-CD20-121 2 of 3 6 REV I DATE I BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 5 4/13/0 AG I BD C.A. PER K03074ACS 1 6 11/08/0 CZ GD C. A. PER K06058ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS ARE INTERPOLATED FROM MICHAEL BAKER JR. DWG. CE-CD20-102, SHEET 1, REV 0. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK/LCMF, JUNE 2001. 4. CONDUCTOR CD2-35 WAS AS-BUILT 3/12/98 BY LOUNSBURY AND ASSOC., CONDUCTORS CD2-23 AND CD2-39 WERE AS-BUILT 3/22/00 BY LOUNSBURY. AS-BUILT COORDINATES ARE FROM DWG. NO. CE-CD20-664D2, SHEET 2, REV. 1. 5. DATES OF AS-BUILT SURVEYS: WELL CONDUCTORS CD2-37, CD2-32 & CD2-24, 05/06/01, FB 2001-14 PGS 76-78; CONDUCTOR CD2-49, 5/07/01, FB2001-15 PG 2; CONDUCTOR CD2-33, 5/08/01, FB 2001-15 PGS 11-13; CONDUCTORS CD2-05, CD2-15 & CD2-50, 5/09/01, FB 2001-15 PGS 21-22; CONDUCTORS CD2-13, CD2-14, CD2-16, CD2-17 & CD2-19, 9/09/01, FB 2001-25 PGS 12-13; CONDUCTORS CD2-25, CD2-26, CD2-28, CD2-36, CD2-45, CD2-47 & CD2-48, 10/04/01, FB 2001-26 PGS 36-38; CD2-34, 10/12/01, FB 2001-27 PGS 12-13; CONDUCTORS CD2-22 & CD2-38, 4/01/02, FB 2002-13 PG 44; CONDUCTOR CD2-29, 4/02/02, FB 2002-13 PG 51; CONDUCTORS CD2-30, CD2-40, CD2-44, CD2-51, CD2-53, CD2-55 & CD2-57, 4/09/02, FB 2002-15 PGS 2-5; CONDUCTORS CD2-41 & CD2-46, 4/19/02, FB 2002-16 PG 73; CONDUCTOR CD2-08, 4/27/02, FB 2002-17 PG 47; CONDUCTORS CD2-07, CD2-10, CD2-11, CD2-12, CD2-18 & CD2-20, 9/10/02, FB 2002-24 PGS 3-9; CONDUCTORS CD2-06, CD2-09, CD2-43, CD2-54, CD2-56 & CD2-58, 4/10/03, FB 2003-08 PGS 43-46; CONDUCTORS CD2-21 & CD2-27, 4/25/03, FB 2003-09 PGS 47-50; CONDUCTORS CD2-31 & CD2-521 5/14/03, FB 2003-09 PGS 73-74, CONDUCTORS CD 2-1 THRU CD2-4 & CD2-59, CD2-60, 4/9/04 LCMF FB 2004-06 PG. 29 & PGS. 33-38. SURVEYOR'S CERTIFICATE ��•�'��\�� I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED ♦♦♦ �� OF ALj �� TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS ♦ " S/F- ♦ AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT �P•..•••••••••.. G;.• •••'09 �1� :♦ SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. i 49th , ■= / """""""""/ .....:.. • .............. DATE: REGISTRATION N0. LS-8629 �.......�...............................::.�o. 19 / Janice M. Zilko Aff AlF •�. sT'•� No. LS-8629 .��`AV ♦♦♦4I1 pROFESS I ONA� \' •��♦♦♦• K U U K P I K P ,,.........- LCMFuc 119 E.61MAw. • Anchouga, Mata DOM • (W7)Z73-18M Alpine Office 6704739 (907) Alpine Survey Office �.� ALPINE MODULE:CD20 UNIT: CD C®n cePhillips ALPINE PROJECT CD-2 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE N0. 01-02-05-1 05-27-01 I DRAWING NO: CE-CD20-121 PART: 3 OF 3 REV: 6