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Home My WebLink About202-1711 Gluyas, Gavin R (OGC) From:Wallace, Chris D (OGC) Sent:Friday, February 28, 2025 11:40 AM To:AOGCC Records (CED sponsored) Subject:FW: CRU CD2-38 (PTD# 202-171) Attachments:AnnComm Surveillance TIO for CD2-38.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Friday, February 28, 2025 9:48 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD2-38 (PTD# 202-171) Chris, CRU CD2-38 (PTD# 202-171) as per the communication below, was placed on a 30-day monitoring period to watch to watch IA pressures while on gas injection. During the 30 days, the IA has not exhibited problematic behavior and has been stable on injection. Attached is the 90-day TIO plot and wellbore schematic. The plan is to stop the 30 day monitor and continue gas injection. Please let me know if you have any questions or disagree with the plan forward. Thanks, Mark From: WNS Integrity Sent: Monday, January 27, 2025 4:56 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD2-38 (PTD# 202-171) Chris, CRU CD2-38 (PTD# 202-171) was reported by operations, for exceeding the MAOP (maximum allowable operating pressure) for high IA pressure (of 2,600 psi) while on MI. The IA was bleed and has been stable since and we completed diagnostics. The well has passed a MIT-IA (passed at 3000 psi), an IA DDT (passed) and a T-POT (passed) and T-PPPOT (passed). The plan is to put the well on a 30 day monitor on gas injection. I will follow up with proper notifications after the 30-day monitor. Let me know if you have any questions or disagree with this plan. Thanks, Mark 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. 2 From: WNS Integrity Sent: Tuesday, December 17, 2024 10:49 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD2-38 (PTD# 202-171) Chris, CRU CD2-38 (PTD# 202-171) was reported by operations, on 12/16/24, for exceeding the MAOP (maximum allowable operating pressure) for high IA pressure (of 2,600 psi) while on MI. The well’s IA was bleed down to 1,500 psi and the well is online and IA is stable. DHD will start initial diagnostics of a MITIA and DDT. DHD will complete initial diagnostics. 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 Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com OƯice (907) 263-3782 Mobile (602) 513-0775 CD2-38 90-Day Bleed HistoryWELL DATE STR-PRES END-PRES DIF-PRES CASINGCD2-38 2024-12-16 2600 1500 -1100 IACD2-38 2024-12-17 1500 900 -600 IACD2-38 2024-12-19 290 950 660 IACD2-38 2024-12-30 1625 990 -635 IA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod ByLast Tag:9,224.0CD2-38 9/28/2002 WV5.3 ConversionLast Rev Reason Annotation Wellbore End Date Last Mod ByRev Reason: Swap out A1 inj valve for WAG CD2-38 oberrNotes: General & Safety Annotation End Date Last Mod ByNOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 9/1/2010 haggeaCasing StringsCsg Des OD (in)ID (in)Top (ftKB)Set Depth (ftKB)Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top ThreadCONDUCTOR16 14.69 36.0114.0114.0109.00 H-40 WELDEDSURFACE9 5/88.92 36.4 2,649.7 2,366.7 36.00 J-55 BTCPRODUCTION76.28 34.89,208.8 7,190.7 26.00 L-80 BTCM OPEN HOLE 6 1/86.13 9,209.013,010.0 7,312.6 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 32.8 Set Depth … 8,935.5 Set Depth… 7,099.1 String Ma… 4 1/2 Tubing Description TUBING 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) 32.832.80.05 HANGER 10.800 FMC TUBING HANGER 4.500 2,208.9 2,027.0 40.95 NIPPLE 5.620 CAMCO DB NIPPLE CAMCO DB 3.812 8,705.36,986.7 55.26 GAS LIFT 5.984 CAMCO KBG-2CAMCOKBG-23.938 8,819.9 7,046.162.09 PACKER 5.970 BAKER S-3 PACKER w/Millout extenstion BAKER S-33.875 8,923.0 7,093.4 62.89 NIPPLE 5.000 HES XN NIPPLE HES XN 3.725 8,934.3 7,098.5 63.38 WLEG 5.000 BAKER WIRELINE GUIDE 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) 2,208.9 2,027.0 40.95 VALVE A-1 INJECTION VALVE W/1.250" ORIFICE, HWS- 208 1/30/2022 1.250 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) 8,705.36,986.7 55.26 1 GAS LIFT DMY BK 1 0.010/16/2002 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) 9,209.0 7,190.8 77.79 OPEN HOLE 6.125 6.125 CD2-38, 6/10/2023 9:39:32 AMVertical schematic (actual) OPEN HOLE; 9,209.0-13,010.0 PRODUCTION; 34.8-9,208.8 WLEG; 8,934.3 NIPPLE; 8,923.0 PACKER; 8,819.9 GAS LIFT; 8,705.3 SURFACE; 36.4-2,649.7 NIPPLE; 2,208.9 VALVE; 2,208.9 CONDUCTOR; 36.0-114.0 HANGER; 32.8 WNS INJ KB-Grd (ft)43.81 RR Date9/8/2002 Other Elev…CD2-38...TDAct Btm (ftKB)13,010.0Well AttributesField NameALPINE Wellbore API/UWI501032042900 Wellbore StatusINJ Max Angle & MDIncl (°)90.49 MD (ftKB)9,940.19WELLNAME WELLBOREAnnotationLast WO:End DateH2S (ppm)DateCommentSSSV: 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 CD2-38 (PTD# 202-171) Date:Monday, January 27, 2025 5:26:38 PM Attachments:image001.png From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Monday, January 27, 2025 4:56 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD2-38 (PTD# 202-171) Chris, CRU CD2-38 (PTD# 202-171) was reported by operations, for exceeding the MAOP (maximum allowable operating pressure) for high IA pressure (of 2,600 psi) while on MI. The IA was bleed and has been stable since and we completed diagnostics. The well has passed a MIT-IA (passed at 3000 psi), an IA DDT (passed) and a T-POT (passed) and T- PPPOT (passed). The plan is to put the well on a 30 day monitor on gas injection. I will follow up with proper notifications after the 30-day monitor. Let me know if you have any questions or disagree with this plan. Thanks, Mark From: WNS Integrity Sent: Tuesday, December 17, 2024 10:49 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD2-38 (PTD# 202-171) Chris, CRU CD2-38 (PTD# 202-171) was reported by operations, on 12/16/24, for exceeding the MAOP (maximum allowable operating pressure) for high IA pressure (of 2,600 psi) while on MI. The well’s IA was bleed down to 1,500 psi and the well is online and IA is stable. DHD will start initial diagnostics of a MITIA and DDT. DHD will complete initial diagnostics. 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 Shulman WNS 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: CRU CD2-38 (PTD# 202-171) Date:Tuesday, January 7, 2025 4:19:59 PM Attachments:image001.png AnnComm Surveillance TIO for CD2-38.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Tuesday, December 17, 2024 10:49 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD2-38 (PTD# 202-171) Chris, CRU CD2-38 (PTD# 202-171) was reported by operations, on 12/16/24, for exceeding the MAOP (maximum allowable operating pressure) for high IA pressure (of 2,600 psi) while on MI. The well’s IA was bleed down to 1,500 psi and the well is online and IA is stable. DHD will start initial diagnostics of a MITIA and DDT. DHD will complete initial diagnostics. 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 Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD2-38 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD2-38 2024-12-16 2600 1500 -1100 IA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:9,224.0CD2-38 9/28/2002 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Swap out A1 inj valve for WAG CD2-38 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 9/1/2010 haggea Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 14.69 36.0114.0114.0109.00 H-40 WELDED SURFACE 9 5/88.92 36.4 2,649.7 2,366.7 36.00 J-55 BTC PRODUCTION 7 6.28 34.89,208.8 7,190.7 26.00 L-80 BTCM OPEN HOLE 6 1/86.13 9,209.013,010.0 7,312.6 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 32.8 Set Depth … 8,935.5 Set Depth… 7,099.1 String Ma… 4 1/2 Tubing Description TUBING 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) 32.832.80.05 HANGER 10.800 FMC TUBING HANGER 4.500 2,208.9 2,027.0 40.95 NIPPLE 5.620 CAMCO DB NIPPLE CAMCO DB 3.812 8,705.36,986.7 55.26 GAS LIFT 5.984 CAMCO KBG-2CAMCOKBG-23.938 8,819.9 7,046.162.09 PACKER 5.970 BAKER S-3 PACKER w/Millout extenstion BAKER S-33.875 8,923.0 7,093.4 62.89 NIPPLE 5.000 HES XN NIPPLE HES XN 3.725 8,934.3 7,098.5 63.38 WLEG 5.000 BAKER WIRELINE GUIDE 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) 2,208.9 2,027.0 40.95 VALVE A-1 INJECTION VALVE W/1.250" ORIFICE, HWS- 208 1/30/2022 1.250 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) 8,705.36,986.7 55.26 1 GAS LIFT DMY BK 1 0.010/16/2002 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) 9,209.0 7,190.8 77.79 OPEN HOLE 6.125 6.125 CD2-38, 6/10/2023 9:39:32 AM Vertical schematic (actual) OPEN HOLE; 9,209.0-13,010.0 PRODUCTION; 34.8-9,208.8 WLEG; 8,934.3 NIPPLE; 8,923.0 PACKER; 8,819.9 GAS LIFT; 8,705.3 SURFACE; 36.4-2,649.7 NIPPLE; 2,208.9 VALVE; 2,208.9 CONDUCTOR; 36.0-114.0 HANGER; 32.8 WNS INJ KB-Grd (ft) 43.81 RR Date 9/8/2002 Other Elev… CD2-38 ... TD Act Btm (ftKB) 13,010.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032042900 Wellbore Status INJ Max Angle & MD Incl (°) 90.49 MD (ftKB) 9,940.19 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-38 COLVILLE RIV UNIT CD2-38 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/20/2022 CD2-38 50-103-20429-00-00 202-171-0 G SPT 7046 2021710 1762 4010 4010 4010 4010 860 950 950 950 4YRTST P Bob Noble 6/7/2022 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 CD2-38 Inspection Date: Tubing OA Packer Depth 1810 2510 2470 2465IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220612152855 BBL Pumped:0.6 BBL Returned:0.6 Wednesday, July 20, 2022 Page 1 of 1         MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,June 11,2018 P.I.Supervisor {j4° C-(t31 l SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD2-38 FROM: Brian Bixby COLVILLE RIV UNIT CD2-38 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JFl -- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD2-38 API Well Number 50-103-20429-00-00 Inspector Name: Brian Bixby Permit Number: 202-171-0 Inspection Date: 6/6/2018 Insp Num: mitBDB180611051545 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min — �Type ;Test pSl 1762 '� IA g 2000 2000 2000 ' 2000 340 2800 2740 2730 --- Well 1 CD2-38 T e Inj W 'TVD 7046 Tubing PTD 2021710 T e Test SPTIBBL Pumped: 2.4 BBL Returned: 2.2 OA 210 490 - 490 ^ 490 - Interval � 4YRTST P/F P J Notes: LU1� VIII SCANNED JUN 2 z Monday,June 11,2018 Page 1 of 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. d.O~ 17 L Well History File Identifier 0 Two-sided 1111111111111111111 Organizing (done) ~scan Needed IIIIIII111111111111 R.ESCAN Jcolor Items: 0 Greyscale Items: DI~AL DATA ~Diskettes NO.~ 0 Other, No/Type: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: Scanning Preparation BY: Helen ~ '3 x 30 = 0 Other:: . I 1 !J Date J 0 <9-7 Dlf 151 m 1111111111111111111 f !J Date Jó fß!. Olf 151 Wt. a D + CA = TOTAL PAGES C?..C? I . (Count d~ not in~uge cover S'lif1..o Date tv d- r. Îi~llillllllllll. BY: Helen ~ Project Proofing BY: Helen~ Production Scanning Stage 1 Page Count from Scanned File: I t)O (Count does include CO/heet) Page Count Matches Number in Scanning Preparation: V YE)¡ NO IliA úJ BY Helen (Maria) Date II, I 0 bt 151 f If ~ f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES' NO BY: Helen Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 11111111111111111 \ I ReScanned 1111111111111111111 BY: Helen Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc • MEMORANDUM To: Jim Regg ~e~C ~I2~I~~ P.I. Supervisor 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 CD2-38 COLVILLE RIV UNIT CD2-38 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~" Comm Well Name: COLVILLE RIV UNIT CD2-38 API Well Number: 50-103-20429-00-00 Insp Num: mitJJ100615090724 Permit Number: 202-171-0 Rel Insp Num: Inspector Name: Jeff Jones Inspection Date: 6/11/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well cD2-3s' T e In'. YP J P.T.D, zozl7io~TypeTest ~/' ~ SPT TVD ~oa6 ~ ~ Test psi L I~6I i IA 0A aso z9oo ' ___ Iso Iso z83o ; 2soo _ _ Iso Iso Interval4~TST p/F P Tubing zloo zloo zloo zloo ~_ NOtes: 2.1BBLS diesel pumped; no exceptions noted. Monday, June 28, 2010 Page 1 of 1 Y' ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 'N(~-¡ .,..."'~. . . en þ.,?R '11 . st;..y.I~ ~~- \'] ¡ 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, ~.Z:~~-_/ 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 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 C02-30 203-135 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 CD2-38 202-171 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¡\ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 & ·,ì _ , P\!'~ !y(" Mr!",g1@..age March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7Th Avenue, Suite 100 Anchorage, AK 99501 J.o~-7J SCANNED APR 0 9 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells rrom 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 rrom 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 C02-30 203-135 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 CD2-38 202-171 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 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor R Zif tþ (3D/DG DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-38 COLVILLE RIV UNIT CD2-38 ..-\1\ ~D:r- FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,:IBiZ- Camm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CD2-38 API Well Number 50-103-20429-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060828 143742 Permit Number: 202-171-0 Inspection Date: 8/26/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-38 Type Inj. G TVD 7046 IA 1425 2340 2310 2310 P.T. 2021710 TypeTest SPT Test psi 1761.5 OA 800 900 900 900 Interval 4YRTST PIF P /' Tubing 3100 3100 3100 3100 Notes Pretest pressure observed and found stable SCANNED SEP 0 82006 Wednesday, August 30, 2006 Page 1 of I e e r ~ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Insem\Microfilm _ Marker.doc '3 CJ ~ ,z()~ L\ DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 MD 13010 ~ TVD 7313 ,./ Completion Date 9/8/2002 ~ Completion Status WAGIN Current Status WAGIN S¡ÎGL¿ ;; )---~ I)? API No. 50-103-20429-00-00 ~\ (ÚIC Y_) 4J'.Î1Z- Permitto Drill 2021710 Well Name/No. COLVILLE RIV UNIT CD2-38 Operator CONOCOPHILLlPS ALASKA INC REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~-~--~-- ~. LlS\1ärifícätión .,.Rpt L:Er:f[) ~ ¿/pt ~D D 1J:9~~ Ó Œ£Ý/ D ØC ~ JD D Las l-ED D Las ~r-f:Og t / )-og rEP V;~D ,/ ED D Las D Las D Las Log Log Run Scale Media No 4 --- -------~ ~--~--,._- - Directional Survey ~nriSUrvey Cement Evaluation Directional Survey 5 Col 1161g---rIS V~rifieetion - c.;-f;{éw-ri-t.f: If< ð f 4 ?-:;Dírãctional Survey &t1679 LI$-VerificatiolJ~.-;>, ~ f/ SU-JII, cf/ Â ó ¡/ Lis 12589 Induction/Resistivity LIS Verification ~2369 Temperature 2369 Pressure Temperature Pressure 1--12370 Spinner 12370 Temperature I \-12370 Pressure 1~0 1 -L- -iM 1 See Notes BM ~----------- 5 Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval OH/ -.-" Start Stop CH Received Comments 2625 12949-0pon - 7/24/Z003 RE-PLACES DATA RCVD ...--04/17/200~ 343 13010 Open 10/3/2002 0 343 Open 10/3/2002 GYRO 100 9216 Case 11/29/2002 0 343 Open 10/3/2002 GYRO 2625 12949 Open 7/24/2003 REPLACES DATA RCVD 04/17/2003 343 13010 Open 1 0/3/2002 ¡}/\ W ~ 2625 12949 Open 4/17/2003 REPLACED BY NEW DATA RCVD 0~24/2003 ~ 2625 12957 Open GR. ROP + EMF, PDF GRAPHICS 2625 12949 Open 4/17/2003 REPLACED BY NEW DATA RCVD 07/24/2003 -,--" 9050 12990 Case 1/20/2004 Warm Back Temp Log 9050 12990 Case 1/20/2004 Warm Back Temp Log 9050 12990 Case 1/20/2004 Warm Back Temp Log 9050 12990 Case 1/20/2004 Warm Back Temp Log 8877 10486 Case 1/20/2004 8877 10486 Case 1/20/2004 8877 1 0486 Case 1/20/2004 8877 10486 Case 1/20/2004 Flow Pack Profile Permit to Drill 2021710 MD 13010 DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Well Name/No. COLVILLE RIV UNIT CD2-38 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20429-00-00 Well Cores/Samples Information: TVD 7313 Name Well Cored? ADDITIONAL INFORMATION y~ Chips Received? --vTN- Analysis Received? Comments: --y-rn Compliance Reviewed By: Completion Date 9/8/2002 ~--Q Completion Status WAGIN Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status WAGIN Sample Set Number Comments &N Œð/N Date: UIC Y ~ ) <--! () ~--::(JJ~ Y ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 0 389* 389 0 0 0 0 0 100 0 29622 33 7/28/2003 9/3/2003 CO2-55, C02-40, C02-30 0 0 0 0 0 0 -;'! 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG0 GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: 303-082 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/28/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 0 2003 / 2nd 0 2003 / 3rd 29522 2003 / 4th 0 2004/1st 0 Total Ending Volume (bbls): 100 389 29522 30011 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~I ~ - - Printed Name: Randy Thomas Title: Step Rate Test 0 Date: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 202-171 C02-38 8. API Number: 50-103-20429-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: -I ~i ~ 33 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7/810'-/ Phone Number: (907) 265-6830 Submit in Duplicate ) } WELL LOG TRANSMITTAL To: State of AlCLqka Alaska Oil and Gas Conservation Catnm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Apri120,2004 RE: MWD Formation Evaluation Logs: CD2-38, AK-MW-22143 CD2-38: Digital Log Images: 50-103-20429-00 dJ / J--)~2r 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPJES OF THE TRANS:MITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date:) ~~ Signed: L ó ¡JJJ ;¿u;l-J71 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG0 GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 6. Permit to Drill Number: 7. Well Name: 202-171 C02-38 8. API Number: 50-103-20429-00 9. Field: 303-082 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/28/2003 Volume (bbls): Number of days disposal occurred Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~. Previous totals (bbls): 0 0 389* 389 0 0 0 0 0 100 0 29622 33 7/28/2003 9/3/2003 CO2-55, CD2-40, C02-30 0 0 0 0 0 0 Report is due on the 20th .~ 100 389 30011 33 of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, Pressure vs. Time D Step Rate Test D October 20 for the third quarter, and January 20 for the fourth quarter. 2003 / 2nd 0 2003 / 3rd 29522 2003/4th 0 2004/1st 0 Total Ending Volume (bbls): 29522 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoin is true and correct to the best of my knowledge. ~~ Signature: Date: l.( 1(6 /6 7' Printed Name: \ ~~,..,(ì \ L..b~\, Title: \J~t~~~~- Lc.'-.J Phone Number: 2.. 6S- ~ 'i 3 C> Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 3rd 29522 2003 / 4th 0 2003 / 4th 0 2004/1st 0 Total Ending Volume 29522 (bbls): 100 0 0 0 100 Signature: Printed Name: Form 10-423 Rev. 9/2003 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas D WAG0 GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: 303-082 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/28/2003 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 202-171 C02-38 ~' 389* 389 0 29622 33 7/28/2003 9/3/2003 CO2-55, C02-40, C02-30 0 0 0 0 0 0 '-.-/ '- 389 Step Rate Test 0 Title: 30011 33 Date: ~ ('" t~ \" ~- '-e-...../ INSTRUCTIONS ON REVERSE SIDE 8. API Number: 50-1 03-20429-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \(7...6 (oy Phone Number: UJ 6 ß J 0 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ~\~~ .- \ <.~ ~) \ ~~ '-- -=- ~ Submit in Duplicate clr3S-I" W~~L LOG TRANSlfAi''~L ') ~Œ- 1'1-\ ProActive Diagnostic Sen'ices, Inc. To: AOGCC 333 West 7th Ave. Ste. 1 00 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 CO-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 C02-38 1 2-03-03 Res. Eva!. CH }r9~~1ZJ 1 1 Mech. CH Caliper Survey 1CO 1 Rpt or 1 Color Signed: ~. ' ~\~ ^" ~'-\LC'-.-~-y\' Dare: RECt:IVEU Print Name: Ji\N 2 C 2004 Alaska Oil & Gas Cons. CornrrIiIIan Anchorage PRoACTivE DiAGNOSTic SERViCES, INC., PO Box 1 ~69 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~~f\~ clr3s II. 3Œ-l-=t- \ Wtu LOG TRANSMITTAL 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 CO-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 CD2-38 1 2-02-03 Res. Eva!. CH )~~~~<1 1 1 Mech. CH Caliper Survey 1CD 1 Rpt or 1 Color Signed: ">~"0 .., ~ ~C'\ s.~_.,y\' -W,ç¡ (0-- :~O,)~ Date : -Rr.:C~IVED JAt'.J 2 C 2004 Print Name: Alaska Oil & Gas Cons. Cornr11isiM Anchorage PRoAcTivE DiAGNOSTic SERVicES, INC., PO Box 1 ~b9 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~---n~Ç,\~ Annular Disposal during the third quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-41 19560 100 0 19660 377 4000 24037 June 2003 July 2003 CD2-20, CD2-55 3S-17A 2133 100 0 2233 361 4659 7253 June 2003 July 2003 38-19 ;}pt,* Hansen 1 2498 100 0 2598 0 115278 117876 January July 2003 Hansen 1, Hansen 1 A 2002 rl( CD2-38 29522 100 0 29622 389 0 30011 July 2003 Sept 2003 CD2-40, CD2-30, CD2-55 IB-20 36655 100 0 36755 0 0 36755 July 2003 Sept 2003 1B-102, 1B-101 CD2-23 22140 100 0 22240 377 0 22617 Sept 2003 Sept 2003 CD2-18, CD2-55 Total Volumes into Annulifor which Disposal Authorization Expired during the third quarter 2003: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-46 31393 100 0 371 31864 Open, Freeze Protected April 2003 May 2003 CD2-51, CD2-] 2 CD2-22 30773 100 0 380 31253 Open, Freeze Protected February March CD2-08, CD2-36, CD2- 2003 2003 51 CD2-48 31525 100 0 375 32000 Open, Freeze Protected December February CD2-45, CD2-35, CD2- 2002 2003 08, CD2-28 R. E- c... 1= PV.. i= " II--n , - OCT 2 3 2003 Alaska Oil & Gas Cons. Commission f:i~r1.chüfagE ') ) " ~D:.)_,., \ \\lo,q WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 April 16,2003 RE: MWD Formation Evaluation Logs - CD2-38, AK-MW-22143 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 1 LDWG formatted Disc with verification listing. API#: 50-103-20429-00. F b.. to: i ,,¡:"." r) ~,,- i !"""', "",jJ Note: This Data Replaces Any Previous Data For Well CD2-38. JUI~4 ~~ .-". ..~. ,"" .¡.. ..~ L....., Alae!<! o..~;.~ .**~M ~J~¡~ð ) aœ-17/ / I to 19 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 April 16,2003 RE: MWD Formation Evaluation Logs - CD2-38, AK-MW-22143 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 1 LDWG formatted Disc with verification listing. API#: 50-103-20429-00. ~ ~"' ~ .~ RECEIVED APR 1 7 2.003 A1aaia Oil & Gas Cons. Commission Anchorage ') ) ConocÒÂ,illips ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 7, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of DrillinfJ Waste on well CD2-38 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2-38 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD2-38 approximately April 15, 2003. Please find attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. Further details regarding wells on CD2 pad within 14 mile radius should be on file at the AOGCC. If you have any questions or require further information, please contact Vem Johnson at 265-6081, or Chip Alvord at 265-6120. S~ly,- V'-' ~~'/AI6J Vem Johnson Drilling Engineer cc: CD2-38 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake :~~CEIVED A TO-868 Anadarko ATO-1530 MAR 1 1 2003 vÌi o¡\jas Cons. ~å~ Anchorage Þ'i(.};) ~;</ ~ '\ ~ts~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well- Change approved program - 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1944' FNL, 1517' FEL, Sec. 2, T11N, R4E, UM At top of productive interval 1564' FNL, 221' FWL, Sec. 12, T11N, R4E, UM At effective depth At total depth 281' FSL, 2061' FWL, Sec. 12, T11N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 13010 7313 9224 7194 measured true vertical Length 80' 2616' 9175' Casing Conductor Surface Production Size 16" 9.625" 7" Perforation depth: Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service _XX (asp: 371721,5974414) (asp: 373379,5969484) (asp: 375164,5966019) feet feet feet feet Plugs (measured) Junk (measured) Cemented 12 cu yds Portland Type 3 372 sx AS lUL, 230 sx Class G 145 sx Class G measured open hole completion from 9209' - 13010' true vertical Tubing (size, grade and measured depth) 4.5", 12.6#, L-80 @ 8936' Re-enter suspended well- Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (DF or KB feet) RKB 52.7' MSL 7. Unit or Property name Other _X Annular Injection Colville River Unit 8. Well number CD2-38 9. Permit number I approval number 202-171 10. API number 50-103-20429-00 11. Field I Pool Colville River Field/Alpine Oil Pool Measured Depth 114' 2650' 9209' True vertical Depth 114' 2367' 7190' RECEt MAR 1 1 Al8I1œ Qj & Gas CO!!E;!, Anch~~ Packers & SSSV (type and measured depth) Baker S-3 packer @ 8820' , Landing Nipple @ 2209' 13. Attachments Description summary of proposal_XX 14. Estimated date for commencing operation April 15, 2003 16. If proposal was verbally approved Detailed operations program - 15. Status of well classification as: BOP sketch - Oil- Name of approver Date approved Service _XX 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval nO'3 '2 do Plug integrity - BOP Test - Location clearance - ~~ - - - ....~ 0<:. y-D l\~ Mechanical Integrity Test- Subsequent form required 10- ~\ "" ~ '~~~~sn.....\ iL7 ¡¡:- ~~ Signed /J ~ ~ rv () ChipA/vord ,./\}'1 ~'.. ~ Approved by order of the Commission Title: Alpine Drilling Team Leader Gas- Suspended - Questions? Call Vem Johnson 265-6081 Date 5/1,103 Prepared by Sharon AlIsup-Drake Commissioner Date Dy/¿B/D_5 ,... ..... ..... ... ............ .... . ...~ ') ) Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-38 b. The depth to the base of freshwater aquifers and There are no USDW aquifers in the Colville River permafrost, if present. Unit. Base of Permafrost = 1552' TVD (RKB) c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) d. A list of all publicly recorded wells within one- See attached map indicating wells within 1/4 mile. quarter mile and all publicly recorded water There are no water wells within 1 mile. wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of Types of fluids can be mud, diesel, cement, and waste to be disposed of and the estimated density water. Maximum volume to be pumped is 35,000 of the waste slurry. bbls. f. An estimate of maximum anticipated pressure at Maximum anticipated pressure at casing shoe the outer casing shoe during annular disposal during disposal operations is 1906 psi. See operation and calculations showing how this attached calculation page. value was determined. g. Details that show the shoe of the outer casing is See attached cementing reports, LOT /FIT reports, set below the base of any freshwater aquifer and and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing See attached casing summary sheet and calculation strings have sufficient strength in collapse and page. burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission NA to confirm containment of drilling wastes. ) ') CD2-38 Pressure Calculations for Annular Disposal DETAILS: ~ ~ ~ Q) Q) '0 '0 co co Q) Q) s::. s::. 'w 'w Co Co o 0 0) 8 0 c C\I 0 'w C\I co + + U ~ E ~ (/) ëñ U) Co Co I ..... ..... ~ 0 0 ~ (/) (/) co co C> C> {=9-5/8" 36 lb/ft, J-55 BTC casing @ 2650 ft MD (2367 ft TVD) Pburst = 3520 psi, @ 85%: Pburst85% = 2992 psi ....,..... "" "" .... ..tö'ë Z Z Estimated Top of Cement @ 8600 ft MD (6921 ft TVD) (7" csg x 8-1/2" Open hole annulus) 0) c :ë :J .... I: 0) ~ c '7 ëñ ~ co U {=4-1/2" 12.6 lb/ft L-80 tubing to 8216 ft MD = ..... L ~ {=7" 26Ib/ft, L-80, BTC casing @ 9209 ft MD (7190 ft TVD) P collapse = 5410 psi, @ 85%: P collapse85% = 4598 psi ~ ASSUMPTIONS: . Maximum injection pressure, P Applied = 1500 psi . Maximum density of injection fluid is 12.0 ppg. . Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft . Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULATIONS: Maximum pressure at 9-5/8" shoe: P max = PHydrostatic + P Applied - PFonnation Pmax = 12.0 (0.052) (2367)+ 1500 - 0.4525 (2367) Pmax = 1906 psi Maximum fluid density to burst 9-5/8" casing: Pburst85% = PHydrostatic + P Applied - PFormation 2992 = MW max (0.052) (2367) + 1500 - 0.4525 (2367) MWmax = 20.8 ppg Maximum Fluid Density to Collapse 7" Casing: P collapse85% = PHydrostatic + P Applied - P GasGradient - PHeader 4598 = MWmax (0.052) (6921) + 1500 - (0.1) (6921) - 2000 MWmax = 16.1 ppg ) ) Note to File(s) CD2-23 (202-134.. .303-080) CD2-19 (202-112.. .303-083) CD2-38 (202-171.. .30-082) CD2-41 (202-126.. .303-081 ) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal in the subject wells. The pertinent information for the wells has been examined and the following determinations made. SURFACE HOLE AND SURFACE CASING --No unusual events were reported while drilling the surface holes of any well. --Surface casing in all wells was cemented to surface. The attachments to the applications note that various amounts of cement were circulated from the wells. The actual pumped volumes were reviewed using the spreadsheet and the XS volumes left in the hole.were calculated to range from a low of 50% to a high of 1500/0. INITIAL LEAKOFF TESTS --Initialleakoff tests were conducted on all wells. It was not possible to pump into any well with slightly more than 16 ppg EMW applied. --The leak off pressure plot of CD2-23 is offset to the left of the casing pressure plot. The leak off plot does exhibit essentially linear response when pumping begins in contrast to the casing pressure plot. Beyond 10 strokes the casing pressure shows linear response and the slope of the linear section is similar to that of the leak off plot. It appears that some amount of air was in the mud present in the casing or drill pipe during the casing test --The leak off pressure plots of CD2-38 and CD2-41 essentially overlay the casing test pressure plot. --The leak off pressure plot of CD2-19 lies slightly beneath the casing pressure plot. PRODUCTION HOLE AND PRODUCTION CASING --No unusual events were reported while drilling any 8-1/2" hole section. --7" casing was successfully run and cemented in each well. SUBSEQUENT INJECTION TESTS M:\tommaunder\Well Information\By Subject\Annular Disposal\030422-CD2 AD.doc ) --Subsequent injectivity tests were done down the 9-5/8" x 7" annuli of each well. In each case the formation failures were lower than the than the stabilized 81 pressures from the initialleakoff tests. PROXIMATE WELLS Proximity analyses to identify any wells within 1/4 mile radius were performed for each well. CD2-23 CD2-19 CD2-38 CD2-41 There are 15 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-15, 205' distant. Annular disposal has been approved and successfully. conducted in 11 of the wells including CD2-15. Annular disposal is recommended for the other wells analyzed in this document. There are 23 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-28, 153' distant. Annular disposal has yet to be requested in CD2-28, although there is nothing in the LOT information that would preclude approving such a request. Annular disposal has been approved and successfully conducted in 11 of the remaining wells and is recommended for the 3 other wells analyzed in this document. There are 20 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-36, 173' distant. Annular disposal has yet to be requested in CD2-36, although there is nothing in the LOT information that would preclude approving such a request. Annular disposal has been approved and successfully conducted in 11 of the wells and is recommended for the 3 other wells analyzed in this document. There are 23 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-38, 279' distant. CD2-38 is analyzed in this document and is recommended for annular disposal. Annular disposal has been approved and successfully conducted in 13 of the wells and is recommended for the 3 other wells analyzed in this document. I recommend approval of Based on examination of the submitted information, Phillips' requests for the subject wells. 4.:~u::r~ Sr. Petroleum Engineer April 22,2002 M:\tommaunder\Well Infonnation\By Subject\Annular Disposal\030422-CD2 AD.doc ) ) Casing Detail 9 518" Surface Casinq -~~~s~~~~LI~~~~~'cL~~ Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 61 Doyon 19 RKB to LDS FMC Gen V Hanger 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 9-5/8" 40# L-80 BTC Csg Davis Lynch Float Shoe 59 Jts Jts 1 to 2 2 Jts 9- 5/8" shoe @ TD 12 1/4" Surface Hole RUN TOTAL 34 BOWSPRING CENTRALlZERS- 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42, 44, 46, 48, 50, 52, 54, 56,& 58 * Note jt. # 3 is 40# L-80 68 joints total in shed - 61 joints total to run Last 7 joints stay out, # 62 thru # 68. Use API Mod Best 0 Life Artie Grade Csg Compound. Remarks: Up Wt - 165K Ibs Dn Wt -120K Ibs Block Wt 75K Ibs Well: CD2-38 Date: 8/27/2002 LENGTH 36.40 2.18 2529.02 1.50 78.86 1.75 Supervisor: Mickey / Bowie DEPTH TOPS 36.40 38.58 2567.60 2569.10 2647.96 2649.71 2660.00 1 tPHI~UPS~ ~ ~~. ) ') ConocoPhillips AI'aska Cementin'gReport Legal Well Name: CD2-38 Common Well Name: CD2-38 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 12.250 (in) 2,650 (ft) 8/27/2002 Surface Casing 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Report #: Start: Spud Date: 8/25/2002 1 Report Date: 8/27/2002 8/25/2002 End: 9/8/2002 Cement Job Type: Primary Squeeze Open Hole Hole Size: SQ TMD: (ft) SQ Date: SQ Type: Cmtd. Csg: Squeeze<ca$irig Hole Size: TM D Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Cementer: Jim Thompson Pipe Movement Pipe Movement: Hole Size: Top Set: 8TM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Rot Time Start:: Time End:: RPM: Rec Time Start:07:00 Time End: 09:15 SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 165,000 (Ibs) Drag Down: 120,000 (Ibs) Type: Cement Casing Volume Excess %: 145.00 Meas. From: 102 Time Circ Prior To Cementing: 1.00 Mud Circ Rate: 231 (gpm) Mud Circ Press: 230 (psi) Stage No: 1 of 1 Start Mix Cmt: 08:00 Start Slurry Displ: 08:01 Start Displ: 08:53 End Pumping: 09:24 End Pump Date: 8/27/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 7.00 (bbl/min) N 450 (psi) (psi) (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 102.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: Densometer Type: Spud Mud Density: 9.7 (ppg) Visc: 52 (s/qt) Bottom Hole Circulating Temperature: 76 (OF) Displacement Fluid Type: Mud PVIYP: 15 (cp)/17 (lb/100ft2) Gels 10 sec: 9 (lb/100ft2) Gels 10 min: 22 (lb/100ft2) Bottom Hole Static Temperature: 54 (OF) Density: 9.7 (ppg) Volume: 201.50 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Mud Data Stage No: 1 Slurry No: 1 of 4 To: (ft) Description: water /w biozan & nut pi Class: Cmt Vol: (bbl) Density: 8.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: 40.0 (bbl) Other Vol:40 0 Purpose: Pre-wash Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Temp CF) (OF) Pressure (psi) (psi) Printed: 9/12/2002 3:25:28 PM y IPHI~lIP8'~ ,~ ) ConocoPhillips Alaska Cementing Report ') Legal Well Name: CD2-38 Common Well Name: CD2-38 Event Name: ROT - DRILLING Report #: Start: Spud Date: 8/25/2002 1 Report Date: 8/27/2002 8/25/2002 End: 9/8/2002 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Stage No: 1 Slurry No: 2 of 4 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol:50 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: (OF) Stage No: 1 Slurry No: 3 of 4 Slurry Data Fluid Type: LEAD Slurry Interval: 2,150.00 (ft)To: (ft) Water Source: lake water Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temp (OF) (OF) Pressure (psi) (psi) Description: ASLite Class: Cmt Vol: 294.0 (bbl) Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Slurry Vol:372 (sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: (OF) Stage No: 1 Slurry Nø: 4 of 4 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,650.00 (ft)To: 2,150.00 (ft) Cmt Vol: 50.0 (bbl) Water Source: lake Slurry Vol:230 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temp (OF) CF) Pressure (psi) (psi) Class: G Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temperature: CF) Temperature: CF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: (OF) Temp (OF) (OF) Pressure (psi) (psi) Printed: 9/12/2002 3:25:28 PM ) ) . ~HI~LlP8'. ~ ConocoPhilHpsAlaska Cementing Report Legal Well Name: CD2-38 Common Well Name: CD2-38 Event Name: ROT - DRILLING Report #: Start: Spud Date: 8/25/2002 1 Report Date: 8/27/2002 8/25/2002 End: 9/8/2002 Casing Test Shoe Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 15.90 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N Remarks Pumped 40 bbls of biozan spacer with nutplug marker, line up to cementers, tested Ii nes to 2500 psi. Dowell mixed and pumped 50 bbls of 10.5 ppg Mudpush Xl spacer, 2 94 bbls of 10.7 ppg lead (7.5 bpm ave.rate) and 50 bbls of 15.7 ppg tail cement (5.0 bpm ave. rate) followed by 20 bbls of wash up water displacement. Continue displace ment with rig pumps at 6-7 bpm, pumped 181.6 bbls of 9.6 ppg mud, plugs did not bu mp, floats held. Full returns throughout job, had 102 bbls of 10.7 ppg cement returns to surface. CIP @ 0924 hrs. Printed: 9/12/2002 3:25:28 PM PitJill'ips..Alâ_ha,<ln'e. Dail,y .Dil"illil'lg.Fiepørt I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD CD2-38 ODR 2,660.0 2,374.0 3.00 I RIG NAME & NO. I FIELD NAME IOCS NO. AUTH MD I DAILY TANG Doyon 19 Alpine 13,064.0 0.00 ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL Dril out cmt, PIT, Drill 8 1/2" hole 8/27/2002 226,473 I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE WCD.W3A.0038.01 LAST SURVEY: DATE TMD INC AZIM LASTCASING NEXTCASING 8/26/2002 2,599.09 39.420 163.620 16.000 (in) @ 114.0 (ft) 9.625 (in) @ 2,674.0 (ft) ~ISNSITY(ppg) I 9.50 I PP I IECDI9.50 IMUD DATAl DAILY COST I 0.00 I CUM COST I FV PVNP GELS WUHTHP FCIT.SOL OILIWAT %Sand/MBT Ph/pM Pf/Mf CI Ca H2S 37 9/4 1/4 8.8/ 1/ / 0.1/12.5 7.9/ /3 40 ) . ~wHIL'¡'"'S" , I ~~. WELL NAME SUPERVISOR David Burley CURRENT STATUS Drilling out cement from 2580'. 24 HR FORECAST LITHOLOGY ..---" !=StilANO.! 2 SHA WT. BELOW JARS ....--.. .------- ",.---..---..---.- - STRING WT. UP BHA I HOLE CONDITIONS STRING WT. DN ì STRING WT. ROT I ITEM DESCRIPTION Bit Mud Motor Drill Collar - Pony Adjustable Guage Stabilizer MWD MWD Sub - Float Drill Collar - Non Mag Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt Crossover BIT {RUN SIZE MANUF. TYPE 2/ 2 8.500 HUGHES-CHR DP0912 BIT /RUN WOB RPM GPM 2/ 2 / / NOJTS 1 1 1 1 1 1 3 3 1 8 1 LENGTH 0.96 25.15 9.95 10.65 28.30 20.36 2.83 91.60 90.47 32.81 240.23 1.37 O;D. 8.500 7.050 6.650 6.500 6.750 6.640 6.750 6.650 6.250 5.000 6.500 BITS SERIAL NO. JETS OR TFA 7000565 12/12/12/12/12/ BIT OPERATIONS PRESS P BIT HRS FROM TO HOURS CODE TROUBLE SUB 00:00 01 :30 1.50 DRILL P PULD 01 :30 02:30 1.00 CASE P RURD 02:30 02:45 0.25 CASE P 02:45 06: 15 3.50 CASE P SFTY RUNC 06: 15 06:45 0.50 CEMENT P 06:45 07:45 1.00 CEMENT P PULD CIRC 07:45 09:00 1.25 CEMENT P PUMP ) I REPT NO. 4 8/27/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 668,936 AUTH. 3,407,697 LAST BOP PRES TEST 8/27/2002 0.00 LIME ES ..--.----.--.-."--- TORQUE / UNITS ..¿.I!__~~. ...: 2 BHA LENGTH 554.68 CONN SIZE CONN TYPE 2.250 4.250 2.813 2.750 1.920 1.920 2.813 2.875 2.250 3.000 2.500 DEPTH IN.. DATE IN I..O.D~l.B~G~O~R 2,660.0 8/27/20020-0-NO-A-D-I-NO-DTF 24Hr DIST 24Hr ROP CUMHRS. CUM DEPTH CUMROP OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC Lay do w n s tab. I e a d coil a ran d mot 0 r, c I ear too Is from rig floor. SURFAC R U fill up too I, e I e vat 0 r s. s lip san d h a n 9 Ion 9 b a ìls to run 9 5/8" casing. SURFAC He Ids a f e t y and 0 p t s me e tin 9 wit her e w . SURFAC Run 6 1 j 0 i n t s tot a I 0 f 9 5/8", 3 6 #, J - 5 5 cas i n g, ( jnt #3 40#, L-80), no problems. MU LJ and land casing with shoe @ 2650', FC @ 2568'. SURFAC ROd 0 w n fill up too I and m u cern e nth e ad. SURFAC S tag e d p u m p sup to 5. 5 b p man d con d it ion mud f or cementing, final pressure 230 psi. SURFAC P u m p e d 40 b b Iso f b i 0 Z a n spa C e r wit h nut p lug m a Printed: 9/1212002 3:27:14 PM PhiiIJipsAltJ~f(a,. iloc. Daily .....D.r.i.I.ling/R~þ~tt I JOB NUMBER I EVENT CODE \24 HRS PROG I TMD ODR 2,660.0 Op.EAATIOiN.SStJMMARY PHAS~ SURFAC r k e r, Ii n e up to c em e n t e r 5, t est e d Ii n est 0 2500 P si. Dowell mixed and pumped 50 bbls of 10.5 ppg Mudpush XL spacer, 294 bbls of 10.7 ppg lead ( 7.5 bpm ave. rate) and 50 bbls of 15.7 ppg tail ce ment (5.0 bpm ave. rate) followed by 20 bbls of wash up water displacement. SURFAC Con tin u e d is P I ace men t wit h rig p u m p 5 at 6 - 7 b p m ,pumped 181.6 bbls of 9.6 ppg mud, plugs did no t bump, floats held, CIP @ 0924 hrs. SURFAC R D c em e nth e ad, run n i n 9 too Is, and I and i n 9 j 0 i n t , flush riser. SURFAC N D r i s era sse m b I y, ins t a II F M C Un i bod Y well h e a d and test M/M seals to 1000 psi. NU BOP stack a nd flowline. SURFAC Set t est p lug and t est BOP E. T est e d Pip e and b I i nd rams, choke, kill, manifold and surface safety valves to 250/5000 psi, annular preventer 250/3 500 psi. Pull test plug and set wear bushing. AO GCC (Lou Grimaldi) waived witnessing tests. SURFAC Rem 0 vel 0 n 9 b a i I san din s t a II d rill i n 9 b a i I san d e levators. SURFAC M U b h a # 2, s c rib e too I san d u p loa d L W D . SURFAC Pic k u P 30 j 0 i n t s 0 f 4" d rill pip e and R I H . SURFAC S lip and cut d rill i n 9 Ii n e, s e r vie e top d r i v e and d rawworks. ) . ^fäH'L~IPS' I I _~I WELL NAME CD2-38 fRoM TO HOURS COD~ TROUBLE SUB 07:45 09:00 1.25 CEMENT P PUMP 09:00 09:30 0.50 CEMENT P DISP 09:30 10:30 1.00 CEMENT P PULD 10:30 14:00 3.50 WELCTL P NUND 14:00 18:30 4.50 WELCTL P BOPE 18:30 19:00 0.50 CASE P RURD 19:00 22:00 3.00 DRILL P PULD 22:00 23:00 1.00 DRILL P TRIP 23:00 00:00 1.00 RIGMNT P RSRV ) Page 2 of 2 24 HR SUMMARY: LD bha, RU and run 61 jts 9 5/8" casing, circ and cond mud, cement casing. COMPANY Phillips Doyon Sperry-Sun MI SERVICE ITEM Rig Fuel Rig H2O UNITS gals bbls USAGE TYPE CD2-50 NO. 2,412 CD2-38 PERSONNEL DATA NO. HOURS COMPANY 1 Dowell 26 DSR 4 ARCA 3 NO. 2 4 5 SERVICE HOURS MATERIALS I CONSUMPTION ON HAND ITEM -51,362 Camp H2O -1,590 UNITS bbl USAGE ON HAND -155 REMARKS SUPPORT CRAFT I TYPE NO. REMARKS Printed: 9/1212002 3:27:14 PM Well Name: Drilling Supervisor: CD2-38 I Rig: David Burley PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 8/28/2002 Pump used: I #2 Mud Pump I... .... Pumping down annulus and DP. .... Type of Test: Casing Shoe Test LOT/FIT Hole Size: 18-1/2" r... Casing Shoe Depth RKB-CHF: 34.8 Ft 2,650 Ft-MD 2,367 Ft-TVD Casina Size and Description: 19-5/8" 36#/Ft J-55 BTC pasina Test Mud Weight: 9.5 ppg Mud 10 min Gel 57.0 Lb/100 Ft2 Test Pressure 2,500 psi Rotating Weight 124,000 Lbs BlockslTop Drive Weight: 75,000 Lbs Estimates for Test: 1.7 bbls Hole Depth 2,680 Ft-MD 2,390 Ft- TVD I. Pressure Int~aritvTes1 Mud Weight: 9.5 ppg Mud 10 min Gel: 58.0 Lb/100 Ft2 Rotating Weight: 125,000 Lbs BlockslTop Drive Weight: 75,000 Lbs Desired PIT EMW: 16.0 ppg Estimates for Test: 800 psi 0.6 bbls I... I... EMW = Leak-off Pressure + Mud Weight = 790 + 9 5 0.052 x TVD 0.052 x 2367 . EMW at 2650 Ft-MD (2367 Ft-TVD) = 15.9 pp~ PIT 15 Second Shut-in Pressure, psi 780 3000 - - Lost 110 psi during test, held = 95.6% of test pressure. 2500 - .. / .~ -L- J'...L~r~ 2000 - w 0:= ::> ~ 1500- W 0:= a.. 1000 - 500 - 0 0 2 3 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point Barrels ~CASING TEST -8-LEAK-OFF TEST Comments: I Volume)nput Volume/Stroke ... O. 1 01 0 Bbls/Strk ... Strokes Casing Test Pumping Shut-in Strks psi Min psi 0 0 0 2500 2 140 1 2490 4 310 2 2480 6 510 3 2480 8 730 4 2470 10 920 5 2470 12 1070 6 2470 14 1210 7 2460 16 1400 8 2460 18 1560 9 2460 20 1760 10 2450 22 1970 15 2430 24 2180 20 2410 26 2400 25 2400 27 2510 30 2390 30 Volume Volume Pumped Bled Back 2./ i:sbls -'l:ibls Pump Rate= 6.0 Strkjmin ... Pressure Integrity Tes1 Pumping Shut-in Strks psi Min psi 0 0 0 790 1 ~& 45 0.25 780 2 ~() 105 0.5 770 3 \00 200 1 760 4 \(i) 300 1.5 750 5 WD 41 0 2 740 "-" 6 \C>õ51 0 2.5 735 7 '10 600 3 725 8 qã 690 3.5 715 9 ,()~790 4 710 4.5 705 5 700 5.5 695 6 690 6.5 685 7 680 7.5 675 8 670 8.5 665 9 665 9.5 660 10 66 ~' Volume Volume Pumped Bled Back 0.9 i:sbls - i:sbls Phillips Alaska, Inc. ) Casing Detail 7" Intermediate Casinq Jt Number Num of Jts Jts 3 to 223 Jts 1 to 2 Remarks: 221 Jts 2 Jts Up Wi =330 COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKS to LOS FMC 11" X 7" Hanger 7" 26# L-80 STCM Csg 7" Davis Lynch Float Collar 7" 26# L-80 STCM Csg 7" Davis Lynch Float Shoe 1 straight blade centralizer per jt # 2 thru # 16 #'s 160, 161, 162 then every other jtf/ #164 to # 220. Total Centralizers: 47 ") 7" shoe @ 8-1/2" TO 230 joints in pipe shed - 223 total jts. to run - last 7 joints stay out Use Best-a-Life 2000 pipe dope Dn Wi = 170 Block Wi= 75K Well: CD2-38 Date: 9/2/2002 LENGTH 34.80 2.55 9082.37 1.45 86.33 1.30 Supervisor: David P. Burley DEPTH TOPS 34.80 37.35 9119.72 9121.17 9207.50 9208.80 9218.00 . ~H Il'LlPS'" I~ ') ConocoPhillips Alaska Cementing Report Legal Well Name: CD2-38 Common Well Name: CD2-38 Event Name: ROT - DRILLING Primé1ry 8.500 (in) 9,209 (ft) 9/2/2002 Intermediate Casing/Li 7.000 (in.) Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Report #: Start: ') Spud Date: 8/25/2002 2 Report Date: 9/2/2002 8/25/2002 End: 9/8/2002 Cement Job Type: Primary Squeeze.oþéh. Höl.e Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Squeeze C$sing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: SteveDoughten Pipe Movement Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating (ft) (ft) Rot Time Start:: Time End:: RPM: Rec Time Start:00:16 Time End: 19:05 SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 330 (Ibs) Max Torque: (ft-Ibf) Drag Down: 170 (Ibs) Type: Cement Casing Volume Excess %: 40.00 Meas. From: 0 Time Circ Prior To Cementing: 3.75 Mud Circ Rate: 60 (gpm) Mud Circ Press: 540 (psi) Start Mix Cmt: 18:01 Start Slurry Displ: 18:04 Start Displ: 18:11 End Pumping: 19:10 End Pump Date: 9/2/2002 Top Plug: Y Bottom Plug: Y Stage No: 1 of 1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: Mud Dâta 6.00 (bbl/min) 6.70 (bbl/min) Y 744 (psi) 1 ,400 (psi) 3 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Recirculat Density Meas By: press scal Type: Non-Disp. LS Density: 9.7 (ppg) Visc: 37 (s/qt) Bottom Hole Circulating Temperature: CF) Displacement Fluid Type: Mud PV/yP: 8 (cp)/15 (lb/100ft2) Gels 10 sec: 6 (lb/100ft2) Gels 10 min: 10 (Ib/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.7 (ppg) Volume: 346.70 (bbJ) Slurry Data Fluid Type: Wash Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Stage No: 1 Slurry No: 1 of 3 To: (ft) Description: ARCO wash Class: Cmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp CF) (OF) Pressure (psi) (psi) Printed: 9/12/2002 3:26:13 PM ) .I)HI~~IPS" ~ ~ Legal Well Name: CD2-38 Common Well Name: CD2-38 Event Name: ROT - DRILLING Report #: Start: Spud Date: 8/25/2002 2 Report Date: 9/2/2002 8/25/2002 End: 9/8/2002 Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: Spacer Slurry Interval: (ft) Water Source: To: (ft) Description: MUDPUSH Xl Class: Cmt Vol: 50.0 (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid loss: (cc) Fluid loss Pressure: Temperature: (OF) Temperature: CF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Stage No: 1 Slurry No: 3 of 3 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 9,209.00 (ft)To: 8,600.00 (ft) Cmt Vol: 31.0 (bbl) Water Source: lake water Slurry Vol:145 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: 17.6 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid loss: (cc) Fluid loss Pressure: Temperature: (OF) Temperature: CF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) StageNó:1 SlutryNó:3<of 3..Additives Trade Name Type DEFOAMER DISPERSANT RETARDR MID-T FLAC Concentration Units Liquid Cone. Units D-46 D-65 D-800 D-167 0.20 %BWOC 0.30 %BWOC 0.04 %BWOC 0.35 %BWOC Printed: 9/12/2002 3:26: 13 PM ) ) . /PHI~LIPS\ ,~ Page 3 of 3 Legal Well Name: CD2-38 Common Well Name: CD2-38 Event Name: ROT - DRILLING Report #: Start: Spud Date: 8/25/2002 2 Report Date: 9/2/2002 8/25/2002 End: 9/8/2002 Casing Test Shoe Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 12.50 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N Remarks Stage pumps up to 6.0 bpm and condition mud for cementing. lower yp to 15, final cir culating presssure 540 psi. PJSM. line up to Dowell, pumped 5 bbls of FW and test ed lines to 3500 psi. Pumped 20 bbls of 8.3 ppg ARGO wash, 50 bbls of 12.5 ppg Mud Push Xl spacer, dropped bottom plug, pumped 31 bbls of 15.8 ppg G wI adds, dropp ed top plug and began displacement with 20 bbls of FW from Dowell. Switched to rig pumps and displaced with 326.7 bbls of 9.65 ppg lSND mud @ 6 - 6.5 bpm I 250 - 79 0 psi, reduced rate to 4.0 bpm last 10 bbls of displacement. Bumped plugs to 1400 ps i, floats held. CIP @ 1910 hrs. Full returns throughout job, reciprocated pipe untill I ast 15 bbls of displacement. Printed: 9/12/2002 3:26:13 PM ') ') . ~..mHILUPS~ , , '~ WELL NAME f'hillif:ìS. ~1~~I(~,lñç. Qail,/....Qri.'ili."iÎRQP~iirt I JOB NUMBER I EVENT CODE 124 HRS PROG TMD CD2-38 ODR 9,218.0 7,194.0 9.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG David Burley Doyon 19 Alpine 13,064.0 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD RIH with BHA #3, picking up 4" drill pipe. 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL RIH, test csg, clean out, PIT, c/o to Flo-Pro, drill ahead. 9/1/2002 289,150 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 15.86 WCD.W3A.0038.01 3,407,697 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 9/1/2002 9,130.04 73.160 152.370 9.625 (in)@ 2,650.0 (ft) 7.000 (in) @ 9,302.0 (ft) 8/27/2002 ~~N~ITY(ppg) I 9.70 I PP I IECDI9.70 ¡IVIUD DATA DAILY COST I 0.00 cÜI\II COST I 0.00 FM PVNP GELS WLlHTHP FCIT.SOL OILlWAT %Sand/MBT Ph/pM Pf/Mf CI Ca H2S LIME ES 37 8/15 6/10 4.6/10.2 1/ / 0.1/20.0 8.9/ 0.01/1 40 10 9/2/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1,640,059 OPERATIONS SUMMARY FRØM TO HOURS CODE TROUBLE SUB PHASE 00:00 01 :30 1.50 CASE P NUND INTRM1 08:00 08:30 0.50 CASE P CIRC INTRM1 DESCRIPTION Change top pipe rams to 7", pull wear bushing an d install test plug and joint. Test 7" rams 250/50 00 psi. Pull test plug and install thin wall wear b ushing. MU fill-up tool, change out bails for casing, RU e levators, slips and power tongs. Held prejob safety and operations meeting with ri g team. PU and run 5 joints of 7", 26#, L-80 casing. Thre ad lockfirst 4 joints, fill casing and test floats, g 0 od. Continue to run casing to 4026'. PUW 152k SO W 130k. Stage pumps up to 7 bpm and condition mud until I mud wt. out @ 9.7 ppg, total volume pumped 17 0 bbls. Maintain mud wt. in at 9.65 ppg, average mud wt. out 9.9 ppg. Initial rate 4 bpm @ 390 psi , final 7 bpm @ 470 psi. Run casing to 6084'. PUW 200 K SOW 160k Stage pumps up to 6.2 bpm CBU+, maintain mud wt. in @ 9.65 ppg. Average mw out 9.9 ppg, max 10.05 ppg, final 9.75 ppg. Initial rate 4.0 bpm @ 530 psi, final 6.2 bpm @ 520 psi, 160 bbls pump ed. Run casing to 8016'. PUW 285k SOW 170k. Stage pumps up to 5.2 bpm CSU+, maintain mud wt. in @ 9.65 ppg. Average mw out 9.85 ppg, max 10.05 ppg, final 9.7ppg. Initial rate 3.9 bpm @ 620 psi, final 5.2 bpm @ 470 psi, 245 bbls pump ed. Run casing (223 jts total 7", 26#, L-80) MU FMC mandral hanger and LJ, land casing with FS @ 92 09', FC @ 9120'. PUW 330k SOW 160k Lay down fill-up tool amd RU cement head. Stage pumps up to 6.0 bpm and condition mud for 01 :30 03:00 1.50 CASE P RURD INTRM1 03:00 03:30 0.50 CASE P SFTY INTRM1 03:30 04:15 0.75 CASE P PUTS INTRM1 04:15 08:00 3.75 CASE P RUNC INTRM1 08:30 10:45 2.25 CASE P 10:45 11:30 0.75 CASE P RUNC INTRM1 CIRC INTRM1 11:30 13:15 1.75 CASE P 13:15 14:15 1.00 CASE P RUNC INTRM1 CIRC INTRM1 14: 15 15:30 1.25 CASE P RUNC INTRM1 15:30 16:00 0.50 CEMENT P 16:00 17:30 1.50 CEMENT P PULD INTRM1 CIRC INTRM1 Printed: 9/1212002 3:28:26 PM ') ') '~œ. BILLIPS. . , , \~ CD2-38 WELL NAME 22:15 00:00 1.75 WELCTL P 0PERA"ifI0NS...StlMM'A.RY PHASE DESCRIPTION INTRM1 c em e n tin g. lower y p to 1 5, fin a lei r cui a tin g pre sssure 540 psi. PJSM. PUMP INTRM1 L i n e u p t 0 D 0 well, p u m p e d 5 b b Iso f F Wan d t est ed lines to 3500 psi. Pumped 20 bbls of 8.3 ppg ARCO wash, 50 bbls of 12.5 ppg Mud Push XL sp acer, dropped bottom plug, pumped 31 bbls of 1 5.8 ppg G wI adds, dropped top plug and began d isplacement with 20 bbls of FW from Dowell. I NTRM 1 S wit c h e d tor i g P u m P san d d i s P I ace d wit h 3 2 6 . 7 b bls of 9.65 ppg LSND mud @ 6 - 6.5 bpm I 250- 790 psi, reduced rate to 4.0 bpm last 10 bbls of displacement. Bumped plugs to 1400 psi, floats h eld. CIP @ 1910 hrs. Full returns throughout job , reciprocated pipe untill last 15 bbls of displace ment. OBSV INTRM1 M 0 nit 0 ran nul us, 00 b s e r v e d s I i g h t f low b a c k. s hut in well @ 1920 hrs. with pipe rams and monitor p ressure for 25 min, zero psi on casing. Open cho ke no returns to shakers. Open rams, observed sl ight flow, line up returns to trip tank and monitor well. Gained 0.5 bbls in 8 min (7.7 bph), gained 0.25 bbls in the next 12 min. (1.25 bph). Conclu ded well breathing slightly. (Rigged down cemen t head and casing equipment while monitoring we II ) PTCH INTRM1 L D I and i n g j 0 i n tan d pull t hi n wall we arb u s h i n g . Install and test packoff to 5000 psi for 10 min. ( monitor breathing at wellhead) final rate observe d 0.5 bph. NUND INTRM1 Set t est p lug i n well h e ad, c h a n get 0 p pip era m s t 0 3 1/2" x 6" variables. BOPE INTRM1 Beg i n t est i n g BOP E, A 0 G C C J e f f Jon e son 10 cat i on for tests. TO HOURS CODE TROUBLE SUB 16:00 17:30 1.50 CEMENT P CIRC 17:30 18:15 0.75 CEMENT P 18:15 19:15 1.00 CEMENT P DISP 19:15 20:30 1.25 WELCTL f\¡DH 20:30 21:15 0.75 CASE P 21:15 22:15 1.00 CASE P 24 HR SUMMARY: RU and run 223 jts of 7" casing, landed with shoe @ 9209', FC @ 9120'. Condition mud and cement casing. Install and test packoff, Begin testing BOPE. SERVICE PERS0NNEL DAT'A NO. HOURS COMPANY 1 DSR 26 ARCA 4 AOGCC 3 FMC 2 HOURS COMPANY Phillips Doyon Sperry-Sun MI Dowell SERVICE NO. 4 5 1 1 ITEM Rig Fuel Rig H2O UNITS gals bbls USAGE 1,025 296 M'A TERIALS I C0NSUMPTI0N ON HAND I ITEM -57,791 I Camp H2O -5,395 I UNITS bbl USAGE 115 ON HAND -855 Printed: 9/12/2002 3:28:26 PM "~m. HI~~'\ , , \~ WELL NAME TYPE CO2-50 C02-38 NO. 633 C02-38 ) ~) REMARKS SUPPORT CRAFT TYPE NO. REMARKS Printed: 9/12/2002 3:28:26 PM PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 9/3/2002 I Volume Input Pump used: I Cement Unit I. I ~ Barre s .... I Rig: David P. Burley CD2-38 Well Name: Drilling Supervisor: Pump Rate: 0.5 Bbl/min ... ... Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casing Test Pumping Shut-in Bbls psi Min psi 0 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Pressure Integrity Tes1 Pumping Shut-in Bbls psi Min psi 0 0 0 227 0.5 60 0.25 222 1 111 0.5 217 1.5 131 1 207 2 152 1.5 202 2.5 172 2 197---/ 3 187 2.5 192 3.5 207 3 192 4 217 3.5 187 4.5 222 4 182 5 227 4.5 177 5.5 232 5 177 6 242 5.5 172 6.5 247 6 172 7 242 6.5 167 7.5 247 7 167 8 247 7.5 162 8.5 253 8 162 9 253 8.5 157 9 157 9.5 157 10 15 '--."./' Hole Size: la-1/2" I... Casing Shoe Depth RKB-CHF: 34.8 Ft 2,650 Ft-MD 2,367 Ft- TVD Casina Size and Description: I USE PICK liST Chanaes for Annular Adeauacv Tes Enter outer casing shoe test results in comments Casing Description references oute! casing string Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. Hole Depth 8,600 Ft-MD 6,920 Ft-TVD I. Pressu,,-e IntearitvTes1 Mud Weight: 9.6 ppg Inner casing OD 7.0 In. Desired PIT EMW: Estimates for Test: 14.0 ppg 542 psi 0 bbls I... I... EMW = Leak-off Pressure + Mud Weight = 111 9 6 0.052 x TVD 0.052 x 2367 + . EMW at 2650 Ft-MD (2367 Ft-TVD) = 10.5 PIT 15 Second Shut-in Pressure, psi 222 500 - w 0:= :) en en w 0:= Q. ~\-I\f(\"~ \ \ ~ CO . ~ . . . . . . ..... . 0 0 2 3 4 5 Barrels 6 7 8 9 10 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point 30 Volume Volume Pumped Bled Back 0.0 Bbls - Hbls Volume Volume Pumped Bled Back 9.0 Hbls - Hbls ""'CASING TEST "'--LEAK-OFF TEST Comments: 9 5/8" casing shoe FIT=15.9 pp~ Name ClJ2.38 -227.71 -1597 -1500 -1250 -1000 -750 -500 -250 -0 -250 -500 -750 -lOOO -1250 -1500 -1597 WElL DErAILS COMPANY DErAILS Phillips Alaska Inc. Engineering Kuparok ANTI-COLLISION SETIlNGS WElLPATH DErAILS ClJ2.38 501032042900 +N/-S +EJ.W Northing 28.32 5974413.52 Interpolation Method:MD Interval: 1.00 Depth Range From: 2649.00 To: 2651.00 Maximum Range: 1497.34 Reference: Definitive Survey CaJcuJation Method: Minimun CU1V3Iw"e Frror Systenr ISCWSA Scan Method: Horizontal Plane Fnor Surface: Elliptical + Casing Warning Method: Rules Based Starting From TVD fBsting Latilude Lnngilude Sk>t 3717:W.66 70"2O'17.986N 15I'02'27.2S6W NIA Rig: Ref. Datum: Doyon 19 ClJ2.38: 52.5Oft Y.Section Angle 151.85' Origin Origin +N/-S +EJ-W 0 0.00 0.00 0.00 1~'7 From Colour 0 200 400 600 800 1000 1250 1500 1750 2000 2500 3000 4000 5000 6000 7000 8000 9000 ToMD 200 400 600 800 1000 1250 1500 1750 2000 2500 3000 4000 5000 6000 7000 8000 9000 11000 .........,' ~ 1/4 Mile Radius of CD2-38 ... 9-5/8" Csg Pt (@ 2650' MD /2366' TVD) Reference Azinuth Angle [deg] vs Centre to Centre Separation [500ft/in] SURFACE CASING SHOE SEPARATION FROM CD2-38 CD2-38 X Y Surface Casing Shoe ASP 4 Coordinates: 372033.86 5973527.13 Distance Surface Suñace csg. Cement Casing Ann. Vol. from Object csg. Shoe X Shoe Y Wells Permit # Permit Date Report Tally No. of LOT Source well Start Date End Date well* Coord. Coord. CD2-35** ---- ---- x x 1 --- ----- ---- 564 372312.31 5974017.68 CD2-24, CD2-33, CD2-33A, CD2-42 301-140 6/1/2001 x x 2 CD2-15 33992 6/1/2001 10/10/2001 1045 371098.46 5973992.48 CD2-33 (+A&B), CD2-39, CD2-24 301-186 7/13/2001 x x 2 CD2-14, CD2-15 33999 7/16/2001 10/9/2001 1843 370630.11 5974721.81 CD2-33 B*** ---- ---- x x 4 --- ---- --- 1912 370155.64 5973886.23 CD2-39 301-281 10/9/2001 x x 2 CD2-15, CD2-47, CD2-44 29945 10/10/2001 9/16/2002 334 372350.61 5973633.17 CD2-14 301-288 10/9/2001 x x 2 CD2-45, CD2-47, CD2-32 31073 11/13/2001 3/5/2002 1444 372202.47 5974960.87 CD2-15 301-308 11/6/2001 x x 2 CD2-50, CD2-25, CD2-44 31652 3/6/2002 9/21/2002 1889 370832.00 5974984.02 ~ CD2-47 301-322 12/3/2001 x x 2 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 835 371231.72 5973294.19 CD2-45 301-345 12/13/2001 x x 2 CD2-49, CD2-17 22991 1/20/2002 2/19/2002 801 372765.13 5973853.74 CD2-34 302-069 3/4/2002 x x 2 CD2-13, CD2-37 22842 10/17/2002 11/28/2002 941 371803.06 5974439.79 CD2-26 302-068 3/4/2002 x x 2 CD2-44, CD2-29, CD2-13 29626 917/2002 10/17/2002 1054 371798.52 5974554.55 CD2-49 302-070 3/4/2002 x x 2 CD2-50, CD2-46, CD2-22 27960 4/22/2002 5/28/2002 949 371252.38 5974065.93 CD2-17 302-122 4/10/2002 x x 2 CD-48, CD2-08 18181 5/29/2002 217/2003 1148 371774.00 5974645.00 CD2-32 302-119 4/30/2002 x x 2 CD2-19, CD2-41, CD2-23 31113 6/14/2002 7/23/2002 1071 371295.61 5974302.38 CD2-41, CD2-19, CD2-16, CD2-50 302-121 4/30/2002 x x 2 CD2-38 32000 7/24/2002 917/2002 792 371665.21 5974227.65 CD2-25 x x 2 NA 1049 371594.00 5974479.00 CD2-46 302-273 9/20/2002 x x 2 NA 0 854 371694.80 5974310.85 CD2-22 302-274 9/20/2002 x x 2 CD2-08, CD2-36 13152 217/2003 2/20/2003 1094 371678.61 5974562.30 CD2-28, CD2-35a, CD2-48 302-275 9/20/2002 x x 2 CD2-45, CD2-08 32000 12/10/2002 2/4/2003 453 371631.74 5973736.14 CD2-19 x x 2 NA 0 1181 372284.88 5974681.33 CD2-41 x x 2 NA 0 279 371990.58 5973802.52 CD2-23 x x 2 NA 0 1859 371013.17 5975080.67 CD2-16 x x 2 NA 0 1333 372460.34 5974790.01 CD2-38 x x 2 NA 0 0 372033.86 5973527.13 CD2-44 x x 2 NA 0 801 372034.57 5974328.53 CD2-29 x x 2 NA 0 1502 372652.44 5974896.02 ~' CD2-13 x x 2 NA 0 2343 372658.78 5975785.31 CD2-37 x x 2 NA 0 801 371569.79 5972874.47 CD2-28 x x 2 NA 0 1206 372139.80 5974728.95 CD2-08 x x 2 NA 0 2168 372655.88 5975603.76 CD2-36 x x 2 NA 0 173 371861.00 5973538.00 * Lateral distance in feet, between surface casing shoes, in the X- Y plane ** CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annular disposal. ***CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. **** As of 21-Feb-03 Schlumberger NO. 2565 Schlumberger Technology Corporation, by and through is Geoquest Divïsion 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth 11/26/02 Company: Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD2-38 jO a... 1 ' I 22491 SCMT 10/01/02 CD2-44 Iîa - tD~ 22493 SCMT 10/04/02 CD2-29 ~~.I"~ 22492 SCMT 10/22/02 SIGN~ cJ}00~ DATE: :-' R~C~\"ED NO\l 2.9 2.002 . .~ mm\øon A\aS\Ia Q\\ S. ~ ìiO Please sign and return one copy ofthis transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ~) ') ~ PHilLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 November 8,2002 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2- 38 (202-171) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-38. If you have any questions regarding this matter, please contact me at 265-6120 or Vem Johnson at 265-6081. Sincerely, ~_í.- ~ G. C. Alvord Alpine Drilling Team Leader P AI Drilling GCA/skad RECEIVED NOV 1 3 2002 AlasKa on& Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ") ) 1. Status of well Classification of Service Well Oil 0 Gas 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Sox 100360, Anchorage, AK 99510-0360 4. Location of well at surface ,...,,~.,~..,,~_._,...__..'I 1944' FNL 1517' FEL Sec. 2 T11N R4E UM ¡ CJr,~?LET¡ON ! AtTop Prod~cing Interval' , , , i ,f.~~'~~zJ 1564' FNL, 221' FWL, Sec. 12, T11 N, R4E, UM '~,') _. V. ~¡." ED.' _.1"" At Total Depth , '~..f'" J, 281' FSL, 2061' FWL, Sec. 12, T11N, R4E, UM ~~.,.':(,¡~!I!i ; , (ASP: 375164, 5966019) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKS 36' feet ADL 380075 12. Date Spudded 13. Date T.D. Reached ¿ 14. Date Comp., Susp. Or Aband. August 25, 2002 September 6, 2002 September 8, 2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 13010'MD/7313'TVD 13010'MD/7313'TVD YES 0 No 0 Suspended 0 Abandoned 0 Service 0 ~ -"-'i:nr-\'~- . ..' 1CMJ~ .! " ,¡ ~} '.f '~ " I k ,i ~:l:~~~~t~ WAG Injector 7. Permit Number 202-171 / 8. API Number 50-103-20429-00 (ASP: 371721,5974414) 9. Unit or Lease Name Colville River Unit 10. Well Number (ASP: 373379, 5969484) CD2-38 11. Field and Pool Colville River Field Alpine Oil Pool 15. Water Depth, if offshore N/ A feet MSL 20. Depth where SSSV set Landing Nipple @2209' 16. No. of Completions 21. Thickness of Permafrost 1660' MD 22. Type Electric or Other Logs Run GR/Res 23. 16" 62.5# 36# 26# GRADE H-40 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2650' Surface 9209' HOLE SIZE CASING SIZE WT. PER FT. 42" CEMENTING RECORD 12 cu yds Portland Type 3 372 sX AS III Lite, 230 sx Class G 145 sx Class G AMOUNT PULLED 9.625" 12.25" 7" 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 4.5" TUBING RECORD DEPTH SET (MD) 8936' PACKER SET (MD) 8820' open hole completion from 9209' - 13010' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. Date First Production N/A Date of Test N/A Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL Test Period> Calculated GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) 24-Hour Rate> 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RE€ErVED N/A RBDMS 8FL G¡; NO\! I 8 2002 NOV 1 3 2002 AJasl<a OU& Gas Gons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME CD2-38 Top Alpine D Top Alpine C Base Alpine 9046' 9104' 12902' 7144' 7163' 7307' Re«øIVED NOV 1 3 2002 Alaska on & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 Signed ~ ~ (}k( Chip Alvord Title Alpine Drilling Team Leader Date HP[ ø l- 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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/24/2002 8/25/2002 8/26/2002 ) ) Page 1 of 8 ConocoPhillips Alaska Operations Summary Report CD2-38 CD2-38 ROT - DRILLING Doyon Doyon 19 Sub From - To Hours Code Code Phase 20:00 . 21 :00 21 :00 . 21 :30 21 :30 . 22:00 22:00 - 23:30 23:30 - 00:00 00:00 - 02:00 02:00 - 08:00 08:00 - 08:30 08:30 . 10:30 10:30 - 11 :30 11 :30 - 15:30 15:30 - 00:00 00:00.12:00 12:00 - 14:30 14:30 . 15:30 15:30.18:30 18:30 - 20:00 20:00 - 21 :00 21 :00 - 23:00 23:00 - 00:00 1.00 MOVE 0.50 MOVE 0.50 MOVE 1.50 MOVE 0.50 MOVE 2.00 MOVE SFTY DMOB MOVE POSN OTHR MOVE MOVE MOVE MOVE MOVE MOVE MOVE 6.00 DRILL RIRD SURFAC 0.50 DRILL OTHR SURFAC 2.00 DRILL DRLG SURFAC 1.00 DRILL TRIP SURFAC 4.00 DRILL DRLG SURFAC 8.50 DRILL DRLG SURFAC 12.00 DRILL DRLG SURFAC 2.50 DRILL DRLG SURFAC 1.00 DRILL CIRC SURFAC 3.00 DRILL WIPR SURFAC 1.50 DRILL WIPR SURFAC 1.00 DRILL CIRC SURFAC 2.00 DRILL TRIP SURFAC 1.00 DRILL TRIP SURFAC Spud Date: 8/25/2002 End: 9/8/2002 Group: Start: 8/25/2002 Rig Release: 9/8/2002 Rig Number: 19 Description of Operations Pjsm, move back pits & motors. Skid floor in for move. Move off well Move drlg module over CD2-38 & check plumb over conductor. Skid floor to drlg position Skid rig floor into position - Spot pit & motor complexes. spot pipe shed - hook up service lines Accept Rig @ 0200 hrs. PU 18" riser & tie into slip-lock starting spool - LD riser to modify ( first use of riser for diverterless surface hole) Take on spud mud - PU BHA tool to rig floor. MU riser to slip lock starting spool - PU 1 std HWDP to ckeck conductor for fill - tagged up @ 42' MU bit, motor WI no bend, pony DC, stab, 1 std HWDP Held Pre- spud meeting wi drilling team - Fill hole ckeck for leaks. pressure test lines to 3500 psi - C/O ice plug in 16" conductor fl 42' to 114' Spud-in Drill 12 1/4" hole fl 114' - 227' MD Round trip, picking up MDW tools & setting AKO to 1.5 deg . Drlg 12 1/4" hole wi directional assembly f/227' - 460' MD, staging pump up to 470 gpm I 1020 psi. Taking gyro surveys each stand down. Drlg 121/4" hole f/460' - 1076' MD, 1070' TVD. Pump pressure 1020- 1300 psi, 470 gpm, rot I slide for directional control. Continue wi gyro surveys to 443'. ADT = 7.2 = ART 4.1 + AST 3.1 hrs. fl spud to 1076' - Weight on bit 15 - 30k Ibs, rpm 0 -50, torque on I bottom = 5k I 4k ft-Ibs, pu 1 so I rot wts = all 130k Ibs. Motor rpm factor = .15 rpm I gal. Started additions of drilling detergent @ 1200' due to gumbo like clay. Conducted PJSM on drilling ops w/out diverter - shallow gas procedures wi both crews. Drill 12 1/4" hole fl 1076' to 2435' MD 2200' TVD 70 RPM (170 rpm @ bit) WOB 30/35 k - 2420 psi @ 588 gpm - String wt. - Up 140 Dn 125 Rot 135 - Torq. On btm 9500 I off btm 6000 ADT- 6.84 ART- 4.81 AST- 2.03 Drill 12 1/4" hole fl 2435' to 2660' MD 2374' TVD - TD of 121/4" hole 70 RPM (170 rpm @ bit) WOB 30/35 k - 2540 psi @ 588 gpm String wt. - Up 150 Dn 130 Rot 140 - Torq on btm 90001 off btm 6000 ADT-1.91 ART- 1.83 AST- .08 Circulate hole clean for wiper trip pump out fl 2660' to 2503'. monitor well - static Wiper trip fl 2503 to 1676' . Tight spot @ 1676' work tight hole to 1667' pulling 45 to 60 over - RIH to 1745' Back ream fl 1745' to 1557' - Pull fl 1558' to 1078' - monitor well static 15 min. RI H to 1536', minor tight spot @ 1536', work same 2x, continue to 2598', MU TD & precautionary wash - ream to 2660, no fill. Cir - condition @ 450 gpm I 1700 psi for 15 min, increase to 585 gpm I 2400 psi [ drlg rate]. Large quanity of gumbo clay & gravel to surface prior to bu. Plugged jet after cir 45 minutes, cont to cir @ 340 gpm I 2600 psi. Initial yp =+1- 48, decrease to 32. Circ shakers clean. Observe well for 15 minutes- static POOH for csg. Good trip out, hole fill good. Stand back BHA components to be used on next section, flush MWD equip, LD selected BHA, Bit plugged [3 jets] wi bits of rubber. Printed: 9/26/2002 12:53:26 PM ) ) Page 2 of 8 ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-38 Common Well Name: CD2-38 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 8/27/2002 00:00 - 01 :30 1.50 DRILL PULD SURFAC 01 :30 - 02:30 1.00 CASE RURD SURFAC 02:30 - 02:45 0.25 CASE SFTY SURFAC 02:45 - 06:15 3.50 CASE RUNC SURFAC 06: 15 - 06:45 0.50 CEMENT PULD SURFAC 06:45 - 07:45 1.00 CEMENTCIRC SURFAC 07:45 - 09:00 1.25 CEMENT PUMP SURFAC 09:00 - 09:30 0.50 CEMENT DISP SURFAC 09:30 - 10:30 1.00 CEMENT PULD SURFAC 10:30 - 14:00 3.50 WELCTL NUND SURFAC 14:00 - 18:30 4.50 WELCTL BOPE SURFAC 18:30 - 19:00 0.50 CASE RURD SURFAC 19:00 - 22:00 3.00 DRILL PULD SURFAC 22:00 - 23:00 1.00 DRILL TRIP SURFAC 23:00 - 00:00 1.00 RIGMNT RSRV SURFAC 8/28/2002 00:00 - 00:45 0.75 DRILL TRIP SURFAC 00:45 - 02:00 1.25 CEMENT COUT SURFAC 02:00 - 02: 15 0.25 CASE DEOT SURFAC 02:15 - 03:30 1.25 CEMENT COUT SURFAC 03:30 - 04:00 0.50 CASE DEOT SURFAC 04:00 - 05:00 1.00 CASE DEOT SURFAC 05:00 - 06:30 1.50 CEMENT DSHO SURFAC 06:30 - 07:00 0.50 CEMENT LOT SURFAC 07:00 - 07:30 0.50 CEMENT LOT SURFAC 07:30 - 13:30 6.00 DRILL TRIP INTRM1 13:30 - 00:00 10.50 DRILL DRLG INTRM1 8/29/2002 8.00 DRILL DRLG INTRM1 00:00 - 08:00 08:00 - 09:15 1.25 DRILL CIRC INTRM1 Spud Date: 8/25/2002 End: 9/8/2002 Group: Start: 8/25/2002 Rig Release: 9/8/2002 Rig Number: 19 Description of Operations Lay down stab, lead collar and motor, clear tools from rig floor. RU fill up tool, elevators, slips and hang long bails to run 9 5/8" casing. Held safety and opts meeting with crew. Run 61 joints total of 9 5/8", 36#, J-55 casing, ünt #3 40#, L-80), no problems. MU LJ and land casing with shoe @ 2650', FC @ 2568'. RD down fill up tool and mu cement head. Staged pumps up to 5.5 bpm and condition mud for cementing, final pressure 230 psi. Pumped 40 bbls of biozan spacer with nutplug marker, line up to cementers, tested lines to 2500 psi. Dowell mixed and pumped 50 bbls of 10.5 ppg Mudpush XL spacer, 294 bbls of 10.7 ppg lead (7.5 bpm ave. rate) and 50 bbls of 15.7 ppg tail cement (5.0 bpm ave. rate) followed by 20 bbls of wash up water displacement. Continue displacement with rig pumps at 6-7 bpm, pumped 181.6 bbls of 9.6 ppg mud, plugs did not bump, floats held, CIP @ 0924 hrs. RD cement head, running tools, and landing joint, flush riser. ND riser assembly, install FMC Unibody wellhead and test M/M seals to 1000 psi. NU BOP stack and flowline. Set test plug and test BOPE. Tested Pipe and blind rams, choke, kill, manifold and surface safety valves to 250/5000 psi, annular preventer 250/3500 psi. Pull test plug and set wear bushing. AOGCC (Lou Grimaldi) waived witnessing tests. Remove long bails and install drilling bails and elevators. MU bha #2, scribe tools and upload LWD. Pick up 30 joints of 4" drill pipe and RIH. Slip and cut drilling line, service top drive and drawworks. RIH, set down 5k @ 2272'. Wash down - clean out cement stringers/sheath from 2272' to 2368' - 5.8 bpm / 600 psi, observed pieces of top plug back across shakers. Tested casing to 2500 psi fpr 10 min. ok. Increased pump rate to 10 bpm /1500 psi, continue to clean out cement stringers to 2450', firm cement to 2550'. CBU prior to casing test, 10 bpm / 1500 psi. RU and test casing to 2500 psi for 30 min, ok. RD and blow down lines. Drill out cement and float equipment, clean out rathole to 2660', drill 20' of new hole to 2680'. CBU prior to PIT, 12 bpm /1850 psi. RU and perform PIT to 15.9 ppg, AMW=9.5 ppg applied surface pressure= 790 psi. MWD tool failed, no pulse, Flow check well, static. POH change out MWD collar, RIH to 2680', Drill from 2680' to 3800' (3258' tvd). ART =5.75 AST =0.4 Held ROP to 180-200 fph, 14 bpm / 2400 psi, 100 rpm. ECD=10.4- 10.7 ppg. Encountered losses while drilling ahead @ 3450' (2015 hrs), initial rate 60 -70 bph. Monitered well for 5 min, no static losses. Reduced pump rate from 590 gpm to 546 gpm, added 1 ppb Mix II course for 1 hr, losses dropped off to slight - no losses from 2300-0000 hrs. Total mud lost=90 bbls. Drill from 3800' to 4659'. ART =5.1 AST =0.55 546 gpm 1 2650 psi 1100 rpm PUW 160k - SOW 123k - RTW 140k No further losses. Pumped 40 bbls 120 tv sweep 1100 bbls mud 140 bbls 100 tv sweep Printed: 9/26/2002 12:53:26 PM ') ') ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-38 Common Well Name: CD2-38 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 8/29/2002 08:00 - 09:15 1.25 DRILL CIRC INTRM1 09:15 - 13:00 3.75 DRILL WIPR INTRM1 13:00 - 13:45 0.75 DRILL CIRC INTRM1 13:45 - 00:00 10.25 DRILL DRLG INTRM1 8/30/2002 00:00 - 19:30 19.50 DRILL DRLG INTRM1 19:30 - 20:45 1.25 DRILL CIRC INTRM1 20:45 - 00:00 3.25 DRILL WIPR INTRM1 8/31/2002 00:00 - 01 :00 1.00 DRILL WIPR INTRM1 01 :00 - 00:00 23.00 DRILL DRLG INTRM1 9/1/2002 00:00 - 07:45 7.75 DRILL DRLG INTRM1 07:45 - 08:30 0.75 DRILL DRLG INTRM1 08:30 - 11 :00 2.50 DRILL INTRM1 11 :00 - 12:30 1.50 DRILL CIRC INTRM1 Page 3 of 8 Spud Date: 8/25/2002 End: 9/8/2002 Group: Start: 8/25/2002 Rig Release: 9/8/2002 Rig Number: 19 Description of Operations and circ hole clean 640 gpm - 3220 psi - 110 rpm. Large increase in cuttings back with both sweeps, circ untill shakers clean 3x BU. Monitor well, 15 min to static. Wipe hole from 4659' to 3230' 10-20k over. Pulled to 3130' 20-30k over hole began swabbing. Ran back to 3230', establish circ and stage pumps up to 440 gpm. Backream to 3135' work stand with 100 rpm and circ 1.5 x BU. Large increase in small size cuttings at BU circ clean. Wiped hole from 3135' to 2900' 10-15k over, 2900' to 2650' 10-20k over, slight swabbing. Monitor well at shoe, OK. RIH to 4563', no problems. Stage pumps up to 588 gpm precautionary ream from 4563' to 4659' - 100 rpm. Very heavy unloading of cuttings at BU, mud gas cut to 9.1 ppg (0.5 ppg cut) circ untill clean. FCP=3280 psi, initial ECD 11.1 ppg, final ECD 10.4 ppg. Drill from 4659' to 5805'. ART=5.65 AST=0.68 PUW 190k - SOW 132k - ROT 155 588 gpm @ 3020 psi - 10.5 ppg ECD 100 rpm @ 200-220 fph / 100 fph sliding torque- 10500 on btm - 9000 off. Drill from 5805' to 7620'. ART=8.5 AST=4.2 588 gpm /3050 psi / 100 rpm ECD=10.6 ppg Torque on/off 12,000/11,500 Ave rot ROP=180 fph Ave sliding ROP=60 fph Had some difficulty sliding in Albian 97 adding 1 % Lubetex to system and 1 ppb nutplug to suction pit while sliding improved ROP. Backream each stand one time. Pumped 40 bbl120 tv sweep, circ and cond mud, 600 gpm /3200 psi / 100 rpm. Minimal increase in cuttings with sweep back. Monitor well, static. Wipe hole from 7620' to 6955' 10-25k over, 6955' to 4020' 5-15k over. Monitor well, static. RIH to 6000', fill drill pipe. RIH from 6000', no problems, precautionary ream last 95'. Drill from 7620' to 8956' (7103 tvd). ART =5.3 AST =8.4 546 gpm / 2860 psi / 100 rpm PUW 230k - SOW 155k - ROT 185k Pumped 40 bbl 120 tv sweep while drilling down first stand after wiper trip, minimal increase in cuttings back with sweep. Difficulty sliding at start of 6/100 build, increased lubricants from 1 to 2%, average Rap sliding increased from 30 to 60 fph. Backream each stand one time. Drill 8 1/2" hole from 8956' to 9218' (7194 tvd) csg. pt. 546 gpm @ 2890 psi 100 rpm PUW 225k - SOW 155k - ROT 189k Ave sliding ROP=75 fph untill connection @ 9147' @ 0430 hrs. Sliding Rap dropped to 10-15 fph from 9147' to 9182.' The ground check relay circuit caused loss of highline power for 25 min. Spent 20 min. after power back on working drill string free. Continue drilling from 9182' to 9218 (7194 tvd) csg pt. Daily total hrs ART =0.7 AST = 3.3 No improvement in ROP, discussed options, decided to adjust casing point in plan and complete the build section in the 61/8" hole section. Pumped 40 bbls 120 tv sweep and circ hole clean, 600 gpm @ 3200 psi Printed: 9/26/2002 12:53:26 PM ) ) ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-38 Common Well Name: CD2-38 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 9/1/2002 11 :00 - 12:30 1.50 DRILL CIRC INTRM1 12:30 - 15:00 2.50 DRILL WIPR INTRM1 15:00 - 17:00 2.00 DRILL CIRC INTRM1 17:00 - 22:30 5.50 DRILL TRIP INTRM1 22:30 - 00:00 1.50 DRILL PULD INTRM1 9/2/2002 00:00 - 01 :30 1.50 CASE NUND INTRM1 01 :30 - 03:00 1.50 CASE RURD INTRM1 03:00 - 03:30 0.50 CASE SFTY INTRM1 03:30 - 04:15 0.75 CASE PUTB INTRM1 04:15 - 08:00 3.75 CASE RUNC INTRM1 08:00 - 08:30 0.50 CASE CIRC INTRM1 08:30 - 10:45 2.25 CASE RUNC INTRM1 10:45 - 11 :30 0.75 CASE CIRC INTRM1 11:30 -13:15 1.75 CASE RUNC INTRM1 13:15 - 14:15 1.00 CASE CIRC INTRM1 14:15 - 15:30 1.25 CASE RUNC INTRM1 15:30 - 16:00 0.50 CEMENT PULD INTRM1 16:00 - 17:30 1.50 CEMENTCIRC INTRM1 17:30 - 18:15 0.75 CEMENT PUMP INTRM1 18:15 - 19:15 1.00 CEMENT DISP INTRM1 19:15 - 20:30 1.25 WELCTL OBSV INTRM1 Page 4 of 8 Spud Date: 8/25/2002 End: 9/8/2002 Group: Start: 8/25/2002 Rig Release: 9/8/2002 Rig Number: 19 Description of Operations - 100 rpm. Minimal increase in cuttings back with sweep. Monitor well, static. Pumped out to 3 stds to 8925', wiped hole to 7300' 10-20k over. Monitor well, static. RIH worked past tight spot @ 8800', precautionary wash and ream last 90' to bottom. Pumped 40 bbls 120 tv sweep, circ hole clean 600 gpm @ 3250 psi - 100 rpm for 3xBU. Minimal increase in cuttings with sweep back. Monitor well, static. Pump out 4 stds to 8829', POH to 7400' - 5-15k over. Monitor well, static, pump dry job. POH to shoe, hole in good condition, monitor well, static. POH to bha, monitor well, static. Stand back hwdp and dc's. Flush tools with FW, lay down remainder of bha. Found primary cutter on bit cone missing - bonding failure - rung out. Change top pipe rams to 7", pull wear bushing and install test plug and joint. Test 7" rams 250/5000 psi. Pull test plug and install thin wall wear bushing. MU fill-up tool, change out bails for casing, RU elevators, slips and power tongs. Held prejob safety and operations meeting with rig team. PU and run 5 joints of 7",26#, L-80 casing. Thread lockfirst 4 joints, fill casing and test floats, good. Continue to run casing to 4026'. PUW 152k SOW 130k. Stage pumps up to 7 bpm and condition mud untill mud wt. out @ 9.7 ppg, total volume pumped 170 bbls. Maintain mud wt. in at 9.65 ppg, average mud wt. out 9.9 ppg. Initial rate 4 bpm @ 390 psi, final 7 bpm @ 470 psi. Run casing to 6084'. PUW 200 K SOW 160k Stage pumps up to 6.2 bpm CBU+, maintain mud wt. in @ 9.65 ppg. Average mw out 9.9 ppg, max 10.05 ppg, final 9.75 ppg. Initial rate 4.0 bpm @ 530 psi, final 6.2 bpm @ 520 psi, 160 bbls pumped. Run casing to 8016'. PUW 285k SOW 170k. Stage pumps up to 5.2 bpm CBU+, maintain mud wt. in @ 9.65 ppg. Average mw out 9.85 ppg, max 10.05 ppg, final 9.7ppg. Initial rate 3.9 bpm @ 620 psi, final 5.2 bpm @ 470 psi, 245 bbls pumped. Run casing (223 jts total 7", 26#, L-80) MU FMC mandral hanger and LJ, land casing with FS @ 9209', FC @ 9120'. PUW 330k SOW 160k Lay down fill-up tool amd RU cement head. Stage pumps up to 6.0 bpm and condition mud for cementing. lower yp to 15, final circulating presssure 540 psi. PJSM. Line up to Dowell, pumped 5 bbls of FW and tested lines to 3500 psi. Pumped 20 bbls of 8.3 ppg ARCO wash, 50 bbls of 12.5 ppg Mud Push XL spacer, dropped bottom plug, pumped 31 bbls of 15.8 ppg G wI adds, dropped top plug and began displacement with 20 bbls of FW from Dowell. Switched to rig pumps and displaced with 326.7 bbls of 9.65 ppg LSND mud @ 6 - 6.5 bpm I 250 -790 psi, reduced rate to 4.0 bpm last 10 bbls of displacement. Bumped plugs to 1400 psi, floats held. CIP @ 1910 hrs. Full returns throughout job, reciprocated pipe until I last 15 bbls of displacement. Monitor annulus,oObserved slight flowback. shut in well @ 1920 hrs. with pipe rams and monitor pressure for 25 min, zero psi on casing. Open choke no returns to shakers. Open rams, observed slight flow, line up returns to trip tank and monitor well. Gained 0.5 bbls in 8 min Printed: 9/26/2002 12:53:26 PM ) ) ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-38 CD2-38 ROT - DRILLING Doyon Doyon 19 Date Sub From - To Hours Code Code Phase 9/2/2002 1.25 WELCTL OBSV INTRM1 19:15 - 20:30 20:30 - 21 :15 0.75 CASE PTCH INTRM1 21:15-22:15 1.00 CASE NUND INTRM1 22: 15 - 00:00 1.75 WELCTL BOPE INTRM1 9/3/2002 00:00 - 02:30 2.50 WELCTL BOPE INTRM1 02:30 - 05:00 2.50 DRILL PULD INTRM1 05:00 - 10:15 5.25 DRILL TRIP INTRM1 10:15 - 12:15 2.00 RIGMNT RSRV INTRM1 12:15 - 12:30 0.25 DRILL TRIP INTRM1 12:30 - 13:15 0.75 CEMENT DSHO INTRM1 13:15 - 14:15 1.00 CASE DEaT INTRM1 14:15 - 16:00 1.75 CEMENT DSHO INTRM1 16:00 - 16:45 0.75 DRILL DRLG INTRM1 16:45 - 18:00 1.25 CEMENT LOT INTRM1 18:00 - 18:45 0.75 CEMENT FIT INTRM1 18:45 - 20:30 1.75 DRILL CIRC PROD 20:30 - 00:00 3.50 DRILL DRLH PROD 9/4/2002 00:00 - 07:00 7.00 DRILL DRLH PROD 07:00 - 08: 15 1.25 DRILL CIRC PROD 08:15 - 09:00 0.75 DRILL DRLH PROD 09:00 - 10:00 1.00 DRILL OBSV PROD 10:00 - 12:00 2.00 DRILL CIRC PROD Page 5 of 8 Spud Date: 8/25/2002 End: 9/8/2002 Group: Start: 8/25/2002 Rig Release: 9/8/2002 Rig Number: 19 Description of Operations (7.7 bph), gained 0.25 bbls in the next 12 min. (1.25 bph). Concluded well breathing slightly. (Rigged down cement head and casing equipment while monitoring well) LD landing joint and pull thin wall wear bushing. Install and test packoff to 5000 psi for 10 min. (monitor breathing at wellhead) final rate observed 0.5 bph. Set test plug in wellhead, change top pipe rams to 3 1/2" X 6" variables. Begin testing BOPE, AOGCC Jeff Jones on location for tests. Test BOPE 250/5000, Annular Preventer 250/3500 psi. Jeff Jones (AOGCC) witnessed and approved tests. Pull test plug and install wear bushing. MU bha #3, set motor ako @ 1.15, sribe tools, initialize LWD. RIH with flex collars and hwdp, shallow test tools. RIH - PU 117 jts of 4" drill pipe from shed - RIH to 8960', fill pipe every 20 stds. Slip and cut drilling line, service top drive, adjusted drawworks brakes. RIH, tagged cement @ 9060'. Clean out cement to 9090' and circ for csg test. RU and test casing to 3500 psi for 30 min. RD and blow down lines. Clean out cement - wiper plugs -fc @ 9120 - cement to fs @ 9209'. Drill out shoe and clean out rathole to 9218'. Slide straght up and drill from 9218' to 9238', 20' of new hole. Circulate and condition mud for PIT. RU and perform FIT to 12.5 ppg EMW w/ 9.6 ppg mud and 1070 psi apllied - Rd. Pumped 35 bbls of FW w/ safekleen, 50 bbls of viscosified Flo-Pro and displaced well to 9.0 ppg Flo-Pro mud @ 5 bpm - 1380 psi - 50 rpm. Clean surface equipment (15 min). Drill 6 1/8" hole from 9238' to 9385' (7209' tvd). ART =0.6 AST =2.3 Drill from 9385' to 9918' (7219 tvd). ART = 5.1 AST =0.3 210 gpm / 1400 psi / 80-100 rpm POW 200k SOW 150k ROT 170k T orque= 10500 on / 9000 off Lost all returns at 9918', PU off bottom and monitor well, no static losses. Reduced rate to 2 bpm / 540 psi adding 8 ppb Icm to suction pit [MIX II course/fine] losses @ 60 bph. Regained 75% returns with 50 bbls of treated mud around bit @ 3.5 bpm / 640 psi. Monitor well, slight breathing observed, static in 4 min. Drill from 9918' to 9994'. ART= 0.5 AST=O 147-168 gpm /1380-1710 psi / 50 rpm Losses 90-120 bph Lost all returns @ 9994', PU off bottom and monitor well, initial static losses @ 60 bph, increased to 120 bph in 10 min. Keep hole full with trip tank pump across top, resumed pumping down drill pipe @ 2 bpm with 8 ppb Icm while mixing Pill. Pulled up to 9824', pumped 40 bbls of 20 ppb Icm pill {1 0 ppb Mix II coarse - 10 ppb MI seal med/course] at 2 bpm / 300 psi. Regained partial returns with 10 bbls of pill around bit, full returns with 40 bbls of pill out. Increased rate to 4 bpm with full returns. POW 200k SOW 150k Rot 177k torque= 11000 on / 9000 off 12 hour losses to hole= 441 bbls. Printed: 9/26/2002 12:53:26 PM ) ) ConocoPhillips Alaska Operations Summary Report Page 6 of 8 Legal Well Name: CD2-38 Common Well Name: CD2-38 Spud Date: 8/25/2002 Event Name: ROT - DRILLING Start: 8/25/2002 End: 9/8/2002 Contractor Name: Doyon Rig Release: 9/8/2002 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours Code Sub Phase Description of Operations Code 9/4/2002 12:00 - 13:00 1.00 DRILL REAM PROD RIH, set down 10k at 9845', ream from 9845' to 9920' with 2.5 bpm / 1280 psi, losses at 60 bph. Pull up to 9824', monitor well, observed well breathing, flow % indicator dropped from 14-1% in 4 min. 13:00 - 00:00 11.00 DRILL DRLH PROD Drill from 9994' to 10588' (7235 tvd). ART =6.85 AST =1.65 PUW 210k SOW 150k ROT 180k 147 gpm /1420 psi /100 rpm T orque= 13500 on /12500 off Losses while drilling = 80-120 bph. Maintaining 6-8 ppb Icm additions. Total losses to hole last 24 hrs = 1301 bbls. ** Seawater contingency off injection header - rigged up - tested (+/- 4 bpm available). 9/5/2002 00:00 - 12:00 12.00 DRILL DRLH PROD Drill from 10588' to 11500' (7260' tvd). ART=8.3 AST=0.7 151 gpm /1270 psi /105 rpm PUW 219k SOW 141k ROT 177k T orque= 14,400 on /14200 off Losses to hole 50-90 bph. Monitor well breathing during connections. Maintain 4-8 ppb LCM additions. 12:00 - 00:00 12.00 DRILL DRLH PROD Drill from 11500' to 12306', ART=7.5 AST=0.8 151 gpm /1330 psi /105 rpm PUW 240k SOW 135K ROT 180k Torque= 16000 on /15500 off Monitor well breathing during connections. Maintain 4-8 ppb LCM additions. Losses to hole: 24 hrs: 1407 bbls Total = 2708 bbls 9/6/2002 00:00 - 14:00 14.00 DRILL DRLH PROD Drill from 12306' to 13010' TD. (7312' tvd) ART= 8.0 AST= 1.4 147 gpm /1310 psi /100 rpm PUW 215k SOW 145k ROT 185k T orque= 11500 on /10500 off Continue with 3-6 ppb Icm additions /Iosses @ 30-80 bph. Monitor breathing during connections. Drilled through the base of Alpine C sand per plan @ 12900', continued to 13010' per geologist request. 14:00 - 20:00 6.00 DRILL TRIP PROD Monitor well, static in 5 min. Pump out of hole from 13010' to 9824', 3.5 bpm 1150 psi, dynamic losses 40-60 bph, hole in good condition.. Monitor well, static in 5 min., observed well 15 min, static losses @ 5 bph. 20:00 - 21 :30 1.50 DRILL CIRC PROD Pumped 40 bbls 12 ppb Icm pill [8 ppb Mix II fine / 4 ppb MI seal fine] into drill string, pump out to 9728' and displaced 20 bbls out bit. Pump out to 9251' displacing remainder of pill into open hole. Monitor well, static in 5 min. Dynamic losses @ 50 bph. 21 :30 - 00:00 2.50 DRILL CIRC PROD Stage pumps up to 5 bpm /1080 psi / 80 rpm, PUW 205k SOW 165k ROT 187k Circ to clean up casing, stripping LCM, dynamic losses +/- 50 bph. Pumped 40 bbls of 180 tv sweep following 1st BU, circulating sweep around @ midnight. Losses: Last 24 hrs=835 bbls T otal=3543 bbls 9/7/2002 00:00 - 02:00 2.00 DRILL CIRC PROD Circ sweep around, large increase in large increase in sand and Icm back. Pumped 2nd 40 bbl 180 tv sweep around, no increase in cuttings Printed: 9/26/2002 12:53:26 PM ') ) ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-38 Common Well Name: CD2-38 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 9/7/2002 00:00 - 02:00 2.00 DRILL CIRC PROD 02:00 - 02:30 0.50 DRILL OBSV PROD 02:30 - 04:30 2.00 DRILL OTHR PROD 04:30 - 05:30 1.00 DRILL OTHR PROD 05:30 - 05:45 0.25 DRILL OBSV PROD 05:45 - 06:30 0.75 DRILL TRIP PROD 06:30 - 07:30 1.00 DRILL OTHR PROD 07:30 -11:15 3.75 DRILL OTHR PROD 11 :15 - 13:00 1.75 DRILL TRIP PROD 13:00 - 14:30 1.50 WAlTON EQI P PROD 14:30 - 18:30 4.00 DRILL TRIP PROD 18:30 - 19:30 1.00 DRILL PULD PROD 19:30 - 20:15 0.75 CMPL TN RURD CMPL TN 20:15 - 20:30 0.25 CMPL TN 5FTY CMPL TN 20:30 - 00:00 3.50 CMPL TN PULD CMPL TN 9/8/2002 00:00 - 03:00 3.00 CMPL TN RUNT CMPL TN 03:00 - 04:15 1.25 CMPL TN OTHR CMPL TN 04:15 - 06:45 2.50 CMPL TN NUND CMPL TN 06:45 - 07:15 0.50 CMPL TN OTHR CMPL TN 07:15 - 09:30 2.25 CMPL TN FRZP CMPL TN 09:30 - 10:00 0.50 CMPL TN PCKR CMPL TN 10:00 - 11 :30 1.50 CMPL TN DEQT CMPL TN 11 :30 - 12:30 1.00 CMPL TN OTHR CMPL TN Page 70f 8 Spud Date: 8/25/2002 End: 9/8/2002 Group: Start: 8/25/2002 Rig Release: 9/8/2002 Rig Number: 19 Description of Operations with sweep back 5.0 bpm I 1420 psi I 80 rpm. Dynamic losses < 50 bph. Monitor well, static in 8 min. Observed well additional 15 min. static losses @ 5 bph. Pump 40 bbl viscosified brine and displace hole to 9.0 ppg kcl brine, dump returns untill clean. 5.0 bpm I 1320 psi I 80 rpm [40 bph losses]. Monitir well, initial loss rate 45 bph. Mix and pump 40 bbls high vis pill into open hole. Monitor well losses slowed to 30 bph. POH slowly to 8450'. coordinated with Alpine Operations time of planned shut down of high line power. Losses to hole= 30 bph. Pump 40 bbl high vis pill and displace into annulus. Secure rig for power outage. Losses to hole reduced to 20 bph. Take rig off highline power. Alpine operations shut down power to CD2 Pad to upload new logic software into facility systems and upgrade hardware. Monitor well on trip tank, static losses @ 20 bph. Rig back on highline power, POH laying down drill pipe to 6673', static losses stable @ 20 bph. Lost highline power, monitor well on trip tank. Operations advised a problem with utility transmitter, power restored @ 1430 hrs. POH laying down drill pipe to 4764', 120 jts. total. Continue to POH, stand back hwdp and flex collars. Losses stable at 20 bph. Lay down remainder of bha, clear tools from rig floor. Pull wear bushing and ru running tools for 4 1/2" tubing. Held prejob safety and opts meeting with rig crew. MU Completion equipment: WLEG I pup I "XN" nipple 3/725 no-go I 2 jts tbg I pup I Baker 5-3 packer wi millout ext. I pup I 2 jts tbg I pup I KG B-2 GLM I pup - RIH picking up 41/2",12.6 ppf, L-80 tubing total of 95 jts run @ midight. Losses last 24 hrs: 120 bbls of Flo-Pro 512 bbls of brine Total losses: 3620 bbls of Flo-Pro 512 bbls of brine Run 41/2" Completion, 203 jts total, MU hanger & LJ "A", land hanger in wellhead wi WLEG @ 8935' - XN nipple @ 8923' - Packer @ 8820' - GLM @ 8705' - DB-6 nipple @ 2209' RKB. Losses stable @ 20 bph RILDS, LD LJ "A" and install TWC. MU LJ "B" and test M/M hanger seals to 5000 psi. LD LJ "B". ND BOPE, NU & test adapter flange and tree to 5000 psi, Pull TWC. RU circulating manifold and hard lines to wellhead, PJSM. Test lines to 3900 psi, displace well with 125 bbls of 9.2 ppg followed by 176 bbls of diesel for tubing displacement and freeze protect 2000' tvd in annulus. RU lubricator and drop packer setting ball and rod. Pressure up on tubing to set packer and test tubing to 3510 psi, bled off to 3240 psi in 30 min. Bleed off tubing to 1375 psi, pressure test annulus to 3575 psi, bled off to 3510 psi in 30 min. Bleed of annulus and tubing - vac out lines - RD circ manifold and hard lines. Printed: 9/26/2002 12:53:26 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) ConocoPhillips Alaska Operations Summary Report Page 8 of 8 CD2-38 CD2-38 ROT - DRILLING Doyon Doyon 19 Spud Date: 8/25/2002 End: 9/8/2002 Group: Start: 8/25/2002 Rig Release: 9/8/2002 Rig Number: 19 Description of Operations Date Sub From - To Hours Code Code Phase 9/8/2002 12:30 - 13:30 13:30 - 15:00 1.00 CMPL TN OTHR CMPL TN RU lubricator, install BPV and secure wellhead. 1.50 CMPL TN OTHR CMPL TN RU and lay down 33 joints of drill pipe for rig move. Released rig @ 1500 hrs. Losses since midnight=200 bbls of brine. Total for well: 3620 bbls of Flo-Pro mud 712 bbls of kcl brine Printed: 9/26/2002 12:53:26 PM ') ) 157.00 0.25 167.00 104.50 157.00 0.33 S 0.08 E 5974413.19 N 371720.73 E 0.16 0.33 252.00 0.15 210.00 199.50 252.00 0.64 S 0.06 E 5974412.88 N 371720.71 E 0.18 0.60 343.00 0.85 164.00 290.50 343.00 1.40 S 0.19 E 5974412.12 N 371720.82 E 0.83 1.32 383.65 1.15 165.99 331.14 383.64 2.08 S 0.37 E 5974411.43 N 371720.99 E 0.74 2.01 472.47 2.11 157.37 419.92 472.42 4.46 S 1.22 E 5974409.05 N 371721.80 E 1.11 4.50 563.26 3.72 148.26 510.59 563.09 8.50 S 3.41 E 5974404.96 N 371723.92 E 1.84 9.10 654.20 5.55 145.87 601.23 653.73 14.65 S 7.43 E 5974398.74 N 371727.84 E 2.02 16.42 742.48 5.36 147.13 689.11 741.61 21.65 S 12.06 E 5974391.67 N 371732.35 E 0.25 24.78 835.39 7.71 143.98 781.41 833.91 30.34 S 18.08 E 5974382.88 N 371738.22 E 2.56 35.28 924.60 9.16 135.35 869.66 922.16 40.23 S 26.59 E 5974372.84 N 371746.56 E 2.15 48.02 1015.44 14.05 139.41 958.62 1011.12 53.75 S 38.86 E 5974359.11 N 371758.59 E 5.45 65.73 1111.31 19.55 145.78 1050.37 1102.87 75.87 S 55.46 E 5974336.71 N 371774.82 E 6.04 93.07 1206.66 19.53 154.70 1140.24 1192.74 103.48 S 71.25 E 5974308.84 N 371790.13 E 3.13 124.86 1299.54 19.26 159.16 1227.86 1280.36 131.84 S 83.33 E 5974280.28 N 371801.73 E 1.62 155.56 1395.90 24.25 160.17 1317.33 1369.83 165.32 S 95.71 E 5974246.58 N 371813.53 E 5.19 190.92 1492.42 28.43 161.62 1403.81 1456.31 205.79 S 109.68 E 5974205.88 N 371826.81 E 4.38 233.20 1585.26 30.02 162.52 1484.83 1537.33 248.92 S 123.63 E 5974162.52 N 371840.01 E 1.78 277.80 1680.77 32.23 161.88 1566.58 1619.08 295.92 S 138.73 E 5974115.27 N 371854.30 E 2.34 326.36 1779.27 35.17 162.62 1648.52 1701.02 347.97 S 155.37 E 5974062.95 N 371870.06 E 3.01 380.10 1871.17 39.26 162.75 1721.69 1774.19 401.02 S 171.91 E 5974009.62 N 371885.68 E 4.45 434.68 1967.96 42.10 162.61 1795.09 1847.59 461.24 S 190.69 E 5973949.08 N 371903.43 E 2.94 496.63 2061.59 41.95 160.08 1864.65 1917.15 520.62 S 210.74 E 5973889.37 N 371922.46 E 1.82 558.44 2158.16 41.92 160.85 1936.49 1988.99 581.44 S 232.32 E 5973828.19 N 371943.00 E 0.53 622.25 2253.49 40.10 161.23 2008.42 2060.92 640.60 S 252.64 E 5973768.69 N 371962.31 E 1.93 683.99 2346.18 39.88 160.79 2079.43 2131.93 696.92 S 272.03 E 5973712.04 N 371980.72 E 0.39 742.80 2445.32 39.27 162.96 2155.85 2208.35 756.94 S 291.68 E 5973651.70 N 371999.35 E 1.52 804,98 2539.73 38.96 164.21 2229.11 2281.61 814.07 S 308.51 E 5973594.29 N 372015.20 E 0.90 863.29 2599.09 39.42 163.62 2275.11 2327.61 850.11 S 318.91 E 5973558.08 N 372024.98 E 1.00 899.97 2664.26 39.59 162.38 2325.40 2377.90 889.76 S 331.03 E 5973518.23 N 372036.42 E 1.24 940.64 2759.04 39.40 162.58 2398.54 2451.04 947.24 S 349.18 E 5973460.45 N 372053.58 E 0.24 999.88 2855.16 38.52 161.46 2473.28 2525.78 1004.73 S 367.83 E 5973402.65 N 372071.24 E 1.17 1059.36 2951.23 37.88 161.50 2548.78 2601.28 1061.06 S 386.70 E 5973346.00 N 372089.15 E 0.67 1117.93 3046.71 38.89 161.92 2623.62 2676.12 1117.35 S 405.30 E 5973289.40 N 372106.79 E 1.09 1176.34 3143.52 40.74 161.90 2697.98 2750.48 1176.27 S 424.55 E 5973230.16 N 372125.02 E 1.91 1237.37 3237.97 40.47 161.79 2769.68 2822.18 1234.69 S 443.70 E 5973171.43 N 372143.17 E 0.30 1297.90 3333.03 40.16 161.60 2842.17 2894.67 1293.08 S 463.02 E 5973112.71 N 372161.49 E 0.35 1358.50 3428.30 39.75 161.74 2915.19 2967.69 1351.15 S 482.26 E 5973054.32 N 372179.73 E 0.44 1418.78 3523.83 39.33 160.82 2988.87 3041.37 1408.75 S 501.77 E 5972996.39 N 372198.26 E 0.75 1478.77 3619.07 38.61 160.45 3062.91 3115.41 1465.26 S 521.63 E 5972939.55 N 372217.15 E 0.79 1537.96 3715.16 39.50 159.82 3137.53 3190.03 1522.20 S 542.21 E 5972882.27 N 372236.75 E 1.01 1597.87 3808.06 41.12 159.80 3208.37 3260.87 1578.60 S 562.95 E 5972825.52 N 372256.52 E 1.74 1657.38 3906.21 40.78 159.83 3282.50 3335.00 1638.98 S 585.15 E 5972764.77 N 372277.68 E 0.35 1721.08 4000.66 40.08 159.31 3354.39 3406.89 1696.38 S 606.53 E 5972707.02 N 372298.08 E 0.82 1781.78 4096.68 39.57 158.97 3428.14 3480.64 1753.84 S 628.42 E 5972649.18 N 372318.99 E 0.58 1842.77 4193.04 39.22 158.28 3502.60 3555.10 1810.79 S 650.71 E 5972591.86 N 372340.30 E 0.58 1903.50 4287.37 39.10 158.74 3575.75 3628.25 1866.22 S 672.53 E 5972536.07 N 372361.17 E 0.33 1962.66 4381.10 41.52 156.95 3647.22 3699.72 1922.36 S 695.42 E 5972479.55 N 372383.09 E 2.86 2022.96 4476.68 41.71 158.12 3718.68 3771.18 1981.02 S 719.67 E 5972420.48 N 372406.34 E 0.84 2086.12 4573.54 42.74 159.06 3790.40 3842.90 2041.62 S 743.43 E 5972359.48 N 372429.05 E 1.25 2150.76 4669.27 43.15 158.79 3860.48 3912.98 2102.48 S 766.88 E 5972298.23 N 372451.46 E 0.47 2215.48 4764.84 42.65 157.60 3930.49 3982.99 2162.88 S 791.04 E 5972237.43 N 372474.58 E 1.00 2280.13 4861.07 42.84 159.56 4001.16 4053.66 2223.68 S 814.89 E 5972176.23 N 372497.39 E 1.40 2344.98 4956.61 42.83 161.15 4071.22 4123.72 2284.85 S 836.73 E 5972114.69 N 372518.18 E 1.13 2409.22 5051.76 42.22 160.89 4141.35 4193.85 2345.66 S 857.64 E 5972053.53 N 372538.05 E 0.67 2472.71 5146.55 41.63 161.99 4211.87 4264.37 2405.70 S 877.80 E 5971993.16 N 372557.18 E 0.99 2535.15 5242.75 41.55 161.56 4283.82 4336.32 2466.35 S 897.78 E 5971932.17 N 372576.11 E 0.31 2598.05 5338.44 41.05 160.74 4355.71 4408.21 2526.12 S 918.18 E 5971872.06 N 372595.49 E 0.77 2660.37 5433.84 40.85 159.99 4427.77 4480.27 2585.01 S 939.19 E 5971812.82 N 372615.49 E 0.56 2722.20 5528.97 40.54 160.37 4499.89 4552.39 2643.36 S 960.22 E 5971754.12 N 372635.52 E 0.42 2783.57 5624.71 40.30 158.98 4572.78 4625.28 2701.57 S 981.78 E 5971695.55 N 372656.08 E 0.97 2845.06 5720.32 40.35 160.77 4645.68 4698.18 2759.66 S 1003.06 E 5971637.10 N 372676.37 E 1.21 2906.32 5815.50 39.95 161.41 4718.43 4770.93 2817.72 S 1022.95 E 5971578.71 N 372695.26 E 0.60 2966.89 5910.99 39.60 160.83 4791.82 4844.32 2875.52 S 1042.72 E 5971520.58 N 372714.04 E 0.53 3027.18 6006.01 39.66 161 .49 4865.00 4917.50 2932.88 S 1062.29 E 5971462.89 N 372732.62 E 0.45 3086.98 6101.85 39.35 162.26 4938.95 4991.45 2990.82 S 1081.26 E 5971404.64 N 372750.60 E 0.61 3147.01 6196.15 38.89 161.66 5012.11 5064.61 3047.40 S 1099.68 E 5971347.76 N 372768.05 E 0.63 3205.58 6292.84 38.18 161.57 5087.74 5140.24 3104.56 S 1118.68 E 5971290.28 N 372786.07 E 0.74 3264.95 CD2-38 (Final Surveys) Page 1 of 3 ') ) 6482.91 36.55 159.94 5238.79 5291.29 3213.40 S 1156.92 E 5971180.80 N 372822.44 E 0.94 3378.94 6579.02 37.31 161.67 5315.62 5368.12 3267.93 S 1175.89 E 5971125.95 N 372840.48 E 1.34 3435.97 6674.40 37.56 160.53 5391.36 5443.86 3322.78 S 1194.68 E 5971070.79 N 372858.32 E 0.77 3493.19 6769.93 37.56 161.20 5467.09 5519.59 3377.80 S 1213.76 E 5971015.46 N 372876.46 E 0.43 3550.70 6865.22 38.21 162.54 5542.29 5594.79 3433.40 S 1231.97 E 5970959.54 N 372893.71 E 1.10 3608.32 6962.08 37.33 161.81 5618.86 5671.36 3489.88 S 1250.12 E 5970902.76 N 372910.90 E 1.02 3666.68 7057.56 37.53 163.16 5694.68 5747.18 3545.22 S 1267.59 E 5970847.13 N 372927.41 E 0.89 3723.71 7152.83 39.40 164.77 5769.27 5821.77 3602.18 S 1283.94 E 5970789.91 N 372942.79 E 2.23 3781.63 7248.36 39.19 164.91 5843.21 5895.71 3660.57 S 1299.76 E 5970731.25 N 372957.61 E 0.24 3840.58 7343.20 39.02 164.78 5916.80 5969.30 3718.31 S 1315.40 E 5970673.25 N 372972.25 E 0.20 3898.86 7440.08 38.78 164.06 5992.20 6044.70 3776.91 S 1331.74 E 5970614.38 N 372987.59 E 0.53 3958.24 7534.44 40.42 162.98 6064.90 6117.40 3834.58 S 1348.81 E 5970556.43 N 373003.67 E 1.89 4017.13 7629.97 39.55 161.63 6138.10 6190.60 3893.06 S 1367.46 E 5970497.64 N 373021.32 E 1.29 4077.49 7726.22 38.19 162.40 6213.03 6265.53 3950.51 S 1386.11 E 5970439.88 N 373038.99 E 1.50 4136.94 7821.85 38.91 162.99 6287.82 6340.32 4007.41 S 1403.84 E 5970382.69 N 373055.74 E 0.85 4195.47 7917.25 39.55 162.07 6361.72 6414.22 4064.95 S 1421.95 E 5970324.84 N 373072.87 E 0.91 4254.75 8013.33 39.47 162.02 6435.85 6488.35 4123.10 S 1440.80 E 5970266.37 N 373090.71 E 0.09 4314.91 8109.10 38.60 161.93 6510.24 6562.74 4180.46 S 1459.46 E 5970208.71 N 373108.39 E 0.91 4374.28 8204.84 41.81 160.40 6583.35 6635.85 4238.93 S 1479.43 E 5970149.90 N 373127.36 E 3.51 4435.26 8299.44 43.35 160.90 6653.01 6705.51 4299.32 S 1500.64 E 5970089.15 N 373147.53 E 1.67 4498.51 8394.83 44.27 161.24 6721.84 6774.34 4361.79 S 1522.06 E 5970026.33 N 373167.88 E 1.00 4563.69 8490.29 43.01 161.33 6790.92 6843.42 4424.18 S 1543.20 E 5969963.59 N 373187.95 E 1.32 4628.67 8523.75 44.77 160.27 6815.04 6867.54 4446.09 S 1550.83 E 5969941.55 N 373195.20 E 5.70 4651.58 8555.42 46.20 159.65 6837.24 6889.74 4467.30 S 1558.57 E 5969920.21 N 373202.58 E 4.73 4673.94 8585.48 46.29 158.82 6858.03 6910.53 4487.60 S 1566.27 E 5969899.78 N 373209.93 E 2.02 4695.47 8618.99 48.48 159.39 6880.72 6933.22 4510.64 S 1575.06 E 5969876.60 N 373218.32 E 6.65 4719.93 8650.84 50.76 159.98 6901.35 6953.85 4533.39 S 1583.48 E 5969853.70 N 373226.35 E 7.30 4743.96 8680.59 52.90 159.47 6919.73 6972.23 4555.33 S 1591.59 E 5969831.63 N 373234.08 E 7.32 4767.13 8714.33 56.13 158.94 6939.32 6991.82 4581.01 S 1601.34 E 5969805.79 N 373243.40 E 9.66 4794.37 8746.26 58.31 159.13 6956.60 7009.10 4606.08 S 1610.95 E 5969780.56 N 373252.57 E 6.85 4821.00 8776.19 59.05 158.70 6972.16 7024.66 4629.93 S 1620.14 E 5969756.55 N 373261.36 E 2.76 4846.37 8810.52 61.65 158.21 6989.14 7041.64 4657.68 S 1631.10 E 5969728.62 N 373271.84 E 7.67 4876.01 8839.49 63.03 157.06 7002.59 7055.09 4681.41 S 1640.87 E 5969704.73 N 373281.20 E 5.92 4901.53 8870.79 62.79 157.10 7016.85 7069.35 4707.07 S 1651.72 E 5969678.88 N 373291.61 E 0.78 4929.28 8908.21 62.26 157.28 7034.11 7086.61 4737.68 S 1664.59 E 5969648.06N 373303.96 E 1.48 4962.34 8966.67 64.76 155.60 7060.18 7112.68 4785.63 S 1685.51 E 5969599.76 N 373324.05 E 4.99 5014.48 9003.65 66.27 153.98 7075.51 7128.01 4816.07 S 1699.84 E 5969569.07 N 373337.86 E 5.71 5048.09 9029.42 67.96 153.74 7085.53 7138.03 4837.39 S 1710.30 E 5969547.58 N 373347.96 E 6.61 5071.82 9062.24 69.99 153.40 7097.31 7149.81 4864.82 S 1723.94 E 5969519.92 N 373361.12 E 6.26 5102.44 9097.43 72.59 151.61 7108.60 7161.10 4894.38 S 1739.33 E 5969490.11 N 373376.00 E 8.82 5135.76 9130.04 73.16 152.37 7118.20 7170.70 4921.89 S 1753.96 E 5969462.35 N 373390.17 E 2.83 5166.92 9178.86 75.63 152.67 7131.33 7183.83 4963.60 S 1775.66 E 5969420.27 N 373411.14 E 5.09 5213.94 9274.08 82.47 153.27 7149.41 7201.91 5046.83 S 1818.11 E 5969336.33 N 373452.17 E 7.21 5307.35 9369.33 86.98 150.18 7158.16 7210.66 5130.32 S 1863.03 E 5969252.08 N 373495.65 E 5.73 5402.16 9465.47 87.85 149.19 7162.50 7215.00 5213.23 S 1911.51 E 5969168.35 N 373542.70 E 1.37 5498.13 9560.45 89.14 149.87 7164.99 7217.49 5295.06 S 1959.65 E 5969085.71 N 373589.44 E 1.54 5593.00 9655.32 89.32 148.98 7166.27 7218.77 5376.74 S 2007.91 E 5969003.22 N 373636.29 E 0.96 5687.78 9751.05 89.69 149.42 7167.10 7219.60 5458.96 S 2056.92 E 5968920.17 N 373683.89 E 0.60 5783.40 9845.99 89.88 149.81 7167.45 7219.95 5540.86 S 2104.94 E 5968837.46 N 373730.51 E 0.46 5878.27 9940.18 90.49 150.03 7167.15 7219.65 5622.36 S 2152.15 E 5968755.16 N 373776.31 E 0.69 5972.41 10038.55 90.37 149.61 7166.41 7218.91 5707.40 S 2201.60 E 5968669.30 N 373824.30 E 0.44 6070.71 10133.75 88.34 149.68 7167.48 7219.98 5789.54 S 2249.71 E 5968586.35 N 373870.99 E 2.13 6165.83 10229.18 86.86 149.87 7171.48 7223.98 5871.92 S 2297.70 E 5968503.15 N 373917.57 E 1.56 6261.11 10324.59 88.40 151.09 7175.42 7227.92 5954.87 S 2344.67 E 5968419.41 N 373963.12 E 2.06 6356.41 10420.55 88.28 151.13 7178.20 7230.70 6038.85 S 2391.01 E 5968334.65 N 374008.01 E 0.13 6452.32 10514.32 88.59 151.42 7180.76 7233.26 6121.05 S 2436.06 E 5968251.69 N 374051.65 E 0.45 6546.05 10611.41 88.83 150.97 7182.95 7235.45 6206.10 S 2482.83 E 5968165.85 N 374096.96 E 0.53 6643.11 10706.83 88.65 153.19 7185.05 7237.55 6290.39 S 2527.50 E 5968080.81 N 374140.17 E 2.33 6738.50 10801.97 88.59 152.49 7187.34 7239.84 6375.02 S 2570.91 E 5967995.46 N 374182.14 E 0.74 6833.60 10897.11 88.28 153.13 7189.94 7242.44 6459.61 S 2614.37 E 5967910.13 N 374224.14 E 0.75 6928.69 10993.30 88.15 153.79 7192.93 7245.43 6545.62 S 2657.33 E 5967823.40 N 374265.62 E 0.70 7024.79 11088.78 88.28 153.59 7195.91 7248.41 6631.17 S 2699.63 E 5967737.14 N 374306.45 E 0.25 7120.18 11184.14 88.03 153.57 7198.98 7251.48 6716.53 S 2742.04 E 5967651.07 N 374347.39 E 0.26 7215.44 11279.01 88.34 152.97 7201.98 7254.48 6801.21 S 2784.69 E 5967565.66 N 374388.59 E 0.71 7310.24 11375.91 88.40 153.13 7204.74 7257.24 6887.56 S 2828.58 E 5967478.58 N 374431.00 E 0.18 7407.07 11471.63 88.52 153.74 7207.31 7259.81 6973.14 S 2871.38 E 5967392.28 N 374472.32 E 0.65 7502.72 11567.14 88.65 153.38 7209.67 7262.17 7058. 63 S 2913.89 E 5967306.07 N 374513.37 E 0.40 7598.16 CD2-38 (Final Surveys) Page 2 of 3 ) ) 11758.36 88.95 153.09 7213.53 7266.03 7229.82 S 2999.01 E 5967133.45 N 374595.54 E 0.84 7789.25 11853.97 88.95 153.36 7215.28 7267.78 7315.16 S 3042.07 E 5967047.39 N 374637.14 E 0.28 7884.82 11949.24 89.08 153.08 7216.91 7269.41 7400.20 S 3084.99 E 5966961.63 N 374678.60 E 0.32 7980.04 12044.48 88.77 152.23 7218.70 7271.20 7484.78 S 3128.73 E 5966876.31 N 374720.89 E 0.95 8075.26 12139.26 86.74 152.72 7222.41 7274.91 7568.77 S 3172.49 E 5966791.59 N 374763.21 E 2.20 8169.95 12234.59 87.66 152.57 7227.07 7279.57 7653.34 S 3216.25 E 5966706.28 N 374805.51 E 0.98 8265.16 12329.71 87.97 153.22 7230.70 7283.20 7737.95 S 3259.55 E 5966620.94 N 374847.36 E 0.76 8360.19 12425.15 87.36 153.01 7234.59 7287.09 7823.00 S 3302.68 E 5966535.17 N 374889.02 E 0.68 8455.53 12520.13 86.37 153.16 7239.78 7292.28 7907.56 S 3345.60 E 5966449.88 N 374930.50 E 1.05 8550.34 12615.10 88.09 150.54 7244.37 7296.87 7991.19 S 3390.35 E 5966365.50 N 374973.81 E 3.30 8645.19 12711.26 87.72 150.34 7247.89 7300.39 8074.78 S 3437.76 E 5966281.11 N 375019.78 E 0.44 8741.26 12806.46 88.15 150.35 7251.32 7303.82 8157.46 S 3484.83 E 5966197.64 N 375065.43 E 0.45 8836.36 12901.96 87.54 149.93 7254.91 7307.41 8240.22 S 3532.35 E 5966114.08 N 375111.52 E 0.78 8931.75 12936.79 87.17 150.26 7256.51 7309.01 8270.38 S 3549.69 E 5966083.63 N 375128.35 E 1.42 8966.53 13010.00 87.17 7260.13 E { A CD2-38 (Final Surveys) Page 3 of 3 ') AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITVE Re: Distribution of Survey Data for Well CD2-38 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD , M D (if applicable) 13,010.00' MD ) ¿;¿Q)~/7/ 03-0ct-02 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECEIVED OCT 0 9 2002 Alaska Oä & Gas Cons. Commiaeion Anchorage "- \' ~ \ ~ CZ)~ ~qOMS 8Fl OCT 9 Sperry-Sun Drilling Services ,~ Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-38 Job No. AKMW22143, Surveyed: 6 September, 2002 Survey Report 2 October, 2002 .~ Your Ref: API 501032042900 Surface Coordinates: 5974413.52 N, 371720.66 E (70° 20' 17.9855" N, 151002' 27.2557" W) Grid Coordinate System: NAD21 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974413.52 N, 128279.34 W (Grid) Surface Coordinates relative to Structure: 29.33 S, 3.67 E(True) Kelly Bushing: 52. 50ft above Mean Sea Level Elevation relative to Project V Reference: 52. 50ft Elevation relative to Structure: 52. 50ft .~ra"'V-.UI1 D A I L L...t N GS & A V. C e s A Halliburton Company ):F N -Y= Survey Ref: svy9971 Sperry-Sun Drilling Services Survey Report for A/pine CD-2 - CD2-38 Your Ref: AP/501032042900 Job No. AKMW22143, Surveyed: 6 September, 2002 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 343.00 0.850 164.000 290.50 343.00 1.40 S 0.19 E 5974412.12 N 371720.82 E 1.32 MWD Magnetic 383.65 1.150 165.990 331.14 383.64 2.088 0.37E 5974411.43 N 371720.99 E 0.743 2.01 472.47 2.110 157.370 419.92 472.42 4.46 8 1.21 E 5974409.04 N 371721.80 E 1.113 4.50 563.26 3.720 148.260 510.59 563.09 8.508 3.41 E 5974404.96 N 371723.92 E 1.840 9.10 ~ 654.20 5.550 145.870 601.23 653.73 14.65 S 7.43E 5974398.74 N 371727.84 E 2.023 16.42 742.48 5.360 147.130 689.11 741.61 21.65 S 12.06 E 5974391.67 N 371732.35 E 0.254 24.78 835.39 7.710 143.980 781.41 833.91 30.34 8 18.08 E 5974382.88 N 371738.22 E 2.558 35.28 924.60 9.160 135.350 869.66 922.16 40.23 S 26.59 E 5974372.84 N 371746.56 E 2.153 48.02 1015.44 14.050 139.410 958.61 1011.11 53.75 S 38.85 E 5974359.11 N 371758.59 E 5.454 65.73 1111.31 19.550 145.780 1050.37 1102.87 75.87 8 55.46 E 5974336.71 N 371774.82 E 6.042 93.07 1206.66 19.530 154.700 1140.24 1192.74 103.488 71.25 E 5974308.84 N 371790.13 E 3.126 124.86 1299.54 19.260 159.160 1227.86 1280.36 131.838 83.33 E 5974280.28 N 371801.73 E 1.620 155.56 1395.90 24.250 160.170 1317.33 1369.83 165.32 8 95.71 E 5974246.58 N 371813.53 E 5.193 190.92 1492.42 28.430 161.620 1403.81 1456.31 205.79 S 109.68 E 5974205.88 N 371826.81 E 4.381 233.20 1585.26 30.020 162.520 1484.83 1537.33 248.928 123.63 E 5974162.52 N 371840.01 E 1.777 277.80 1680.77 32.230 161.880 1566.58 1619.08 295.92 S 138.73 E 5974115.27 N 371854.30 E 2.340 326.36 1779.27 35.170 162.620 1648.52 1701.02 347.97 S 155.37 E 5974062.95 N 371870.06 E 3.014 380.10 1871.17 39.260 162.750 1721.69 1774.19 401.02 S 171.91 E 5974009.62 N 371885.68 E 4.451 434.68 1967.96 42.100 162.610 1795.09 1847.59 461.24 S 190.69 E 5973949.08 N 371903.43 E 2.936 496.63 2061.59 41.950 160.080 1864.65 1917.15 520.62 S 210.74 E 5973889.37 N 371922.46 E 1.816 558.44 2158.16 41.920 160.850 1936.49 1988.99 581.448 232.32 E 5973828.19 N 371943.00 E 0.534 622.24 .~ 2253.49 40.1 00 161.230 2008.42 2060.92 640.60 8 252.64 E 5973768.69 N 371962.31 E 1.927 683.99 2346.18 39.880 160.790 2079.43 2131.93 696.92 8 272.03 E 5973712.04 N 371980.72 E 0.387 742.80 2445.32 39.270 162.960 2155.85 2208.35 756.94 8 291.68 E 5973651.70 N 371999.35 E 1.524 804.98 2539.73 38.960 164.210 2229.11 2281.61 814.07 8 308.51 E 5973594.29 N 372015.20 E 0.897 863.29 2599.09 39.420 163.620 2275.11 2327.61 850.11 8 318.91 E 5973558.08 N 372024.98 E 0.997 899.97 2664.26 39.590 162.380 2325.40 2377.90 889.768 331.03 E 5973518.23 N 372036.42 E 1.238 940.64 2759.04 39.400 162.580 2398.54 2451.04 947.24 S 349.17 E 5973460.45 N 372053.58 E 0.241 999.88 2855.16 38.520 161.460 2473.28 2525.78 1004.738 367.82 E 5973402.65 N 372071.24 E 1.173 1059.36 2951.23 37.880 161.500 2548.77 2601.27 1061.068 386.70 E 5973346.00 N 372089.15 E 0.667 1117.93 3046.71 38.890 161.920 2623.62 2676.12 1117.35 S 405.30 E 5973289.40 N 372106.78 E 1.093 1176.34 3143.52 40.740 161.900 2697.97 2750.47 1176.278 424.55 E 5973230.16 N 372125.02 E 1.911 1237.37 3237.97 40.470 161.790 2769.68 2822.18 1234.688 443.70 E 5973171.43 N 372143.17 E 0.296 1297.90 3333.03 40.160 161.600 2842.17 2894.67 1293.08 S 463.02 E 5973112.71 N 372161.49 E 0.351 1358.50 .3428.30 39.750 161.740 2915.19 2967.69 1351.15 8 482.26 E 5973054.32 N 372179.73 E 0.441 1418.78 ~--~--_._--_.~_.__._._-----_._.-- 2 October, 2002 - 10:37 Page 20f7 Ð,iIIQllest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for AlpIne CD-2 - CD2-38 Your Ref: API 501032042900 Job No. AKMW22143, Surveyed: 6 September, 2002 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3523.83 39.330 160.820 2988.87 3041.37 1408.75 S 501.77 E 5972996.39 N 372198.26 E 0.754 1478.77 3619.07 38.610 160.450 3062.91 3115.41 1465.26 S 521.63 E 5972939.55 N 372217.15 E 0.794 1537.96 3715.16 39.500 159.820 3137.53 3190.03 1522.20 S 542.21 E 5972882.27 N 372236.75 E 1.014 1597.86 3808.06 41 .120 159.800 3208.37 3260.87 1578.60 S 562.95 E 5972825.52 N 372256.52 E 1.744 1657.38 ~. 3906.21 40.780 159.830 3282.50 3335.00 1638.98 S 585.15 E 5972764.77 N 372277.68 E 0.347 1721.08 4000.66 40.080 159.310 3354.39 3406.89 1696.38 S 606.53 E 5972707.01 N 372298.08 E 0.823 1781.78 4096.68 39.570 158.970 3428.14 3480.64 1753.84 S 628.42 E 5972649.18 N 372318.99 E 0.578 1842.77 4193.04 39.220 158.280 3502.60 3555.10 1810.79 S 650.71 E 5972591.86 N 372340.30 E 0.582 1903.50 4287.37 39.100 158.740 3575.75 3628.25 1866.22 S 672.53 E 5972536.07 N 372361.17 E 0.333 1962.66 4381.10 41.520 156.950 3647.22 3699.72 1922.36 S 695.42 E 5972479.55 N 372383.09 E 2.862 2022.96 4476.68 41.710 158.120 3718.68 3771.18 1981.02 S 719.67 E 5972420.48 N 372406.34 E 0.837 2086.12 4573.54 42.740 159.060 3790.40 3842.90 2041.62 S 743.43 E 5972359.48 N 372429.05 E 1.247 2150.75 4669.27 43.150 158.790 3860.48 3912.98 2102.48 S 766.88 E 5972298.23 N 372451.46 E 0.469 2215.48 4764.84 42.650 157.600 3930.49 3982.99 2162.88 S 791.04 E 5972237.43 N 372474.58 E 0.996 2280.13 4861.07 42.840 159.560 4001.16 4053.66 2223.68 S 814.89 E 5972176.23 N 372497.39 E 1.396 2344.98 4956.61 42.830 161.150 4071.22 4123.72 2284.85 S 836.73 E 5972114.69 N 372518.18 E 1.132 2409.22 5051.76 42.220 160.890 4141.35 4193.85 2345.66 S 857.64 E 5972053.53 N 372538.05 E 0.667 2472.70 5146.55 41.630 161.990 4211.87 4264.37 2405.70 S 877.80 E 5971993.15 N 372557.18 E 0.994 2535.15 5242.75 41.550 161.560 4283.82 4336.32 2466.35 S 897.78 E 5971932.17 N 372576.11 E 0.308 2598.05 5338.44 41.050 160.740 4355.71 4408.21 2526.12 S 918.18E 5971872.06 N 372595.49 E 0.770 2660.37 5433.84 40.850 159.990 4427.77 4480.27 2585.01 S 939.19 E 5971812.82 N 372615.49 E 0.556 2722.20 -~ 5528.97 40.540 160.370 4499.89 4552.39 2643.36 S 960.22 E 5971754.12 N 372635.52 E 0.417 2783.57 5624.71 40.300 158.980 4572.78 4625.28 2701.57 S 981.78 E 5971695.55 N 372656.08 E 0.974 2845.06 5720.32 40.350 160.770 4645.68 4698.18 2759.66 S 1003.06 E 5971637.10 N 372676.37 E 1.213 2906.32 5815.50 39.950 161.410 4718.43 4770.93 2817.72 S 1022.95 E 5971578.71 N 372695.26 E 0.604 2966.89 5910.99 39.600 160.830 4791.82 4844.32 2875.52 S 1042.72 E 5971520.58 N 372714.04 E 0.534 3027.18 6006.01 39.660 161.490 4865.00 4917.50 2932.88 S 1062.29 E 5971462.89 N 372732.62 E 0.448 3086.98 6101.85 39.350 162.260 4938.95 4991.45 2990.82 S 1081.26 E 5971404.64 N 372750.60 E 0.605 3147.01 6196.15 38.890 161.660 5012.11 5064.61 3047.40 S 1099.68 E 5971347.76 N 372768.05 E 0.632 3205.58 6292.84 38.180 161.570 5087.74 5140.24 3104.56 S 1118.68 E 5971290.28 N 372786.07 E 0.737 3264.94 6388.61 37.370 160.510 5163.44 5215.94 3160.04 S 1137.74 E 5971234.48 N 372804.17 E 1.084 3322.85 6482.91 36.550 159.940 5238.79 5291.29 3213.40 S 1156.92 E 5971180.80 N 372822.44 E 0.942 3378.94 ß579.02 37.310 161.670 5315.62 5368.12 3267.93 S 1175.89 E 5971125.95 N 372840.48 E 1.340 3435.97 6674.40 37.560 160.530 5391.36 5443.86 3322.78 S 1194.68 E 5971070.79 N 372858.32 E 0.772 3493.19 6769.93 37.560 161.200 5467.09 5519.59 3a77.80 S 1213.76 E 5971015.45 N 372876.46 E 0.428 3550.70 -------------- -------"----~_._----_.__.--_.._---_._~--~--- 2 October, 2002 - 10:37 Page 3 of7 DrlllQlIest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-38 Your Ref: API 501032042900 Job No. AKMW22143, Surveyed: 6 September, 2002 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6865.22 38.210 162.540 5542.29 5594.79 3433.40 S 1231 ;97 E 5970959.54 N 372893.71 E 1.100 3608.32 6962.08 37.330 161.810 5618.86 5671.36 3489.88 S 1250.12 E 5970902.76 N 372910.90 E 1.019 3666.68 7057.56 37.530 163.160 5694.68 5747.18 3545.22 S 1267.59 E 5970847.13 N 372927.41 E 0.885 3723.71 7152.83 39.400 164.770 5769.27 5821.77 3602.17 S 1283.94 E 5970789.91 N 372942.79 E 2.226 3781.63 7248.36 39.190 164.910 5843.20 5895.70 3660.57 S 1299.76 E 5970731.25 N 372957.61 E 0.239 3840.58 7343.20 39.020 164.780 5916.80 5969.30 3718.31 S 1315.40 E 5970673.25 N 372972.25 E 0.199 3898.86 7440.08 38.780 164.060 5992.20 6044.70 3776.91 S 1331.74 E 5970614.38 N 372987.59 E 0.528 3958.24 7534.44 40.420 162.980 6064.90 6117.40 3834.58 S 1348.81 E 5970556.43 N 373003.67 E 1.885 4017.13 7629.97 39.550 161.630 6138.10 6190.60 3893.06 S 1367.46 E 5970497.64 N 373021.32 E 1 .286 4077.49 7726.22 38.190 162.400 6213.03 6265.53 3950.51 S 1386.11 E 5970439.88 N 373038.99 E 1.500 4136.94 7821.85 38.910 162.990 6287.82 6340.32 4007.41 S 1403.84 E 5970382.69 N 373055.74 E 0.845 4195.47 7917.25 39.550 162.070 6361.72 6414.22 4064.95 S 1421.95 E 5970324.84 N 373072.86 E 0.907 4254.75 8013.33 39.470 162.020 6435.85 6488.35 4123.10 S 1440.80 E 5970266.37 N 373090.71 E 0.090 4314.91 8109.10 38.600 161.930 6510.24 6562.74 4180.46 S 1459.46 E 5970208.71 N 373108.39 E 0.910 4374.28 8204.84 41.810 160.400 6583.35 6635.85 4238.93 S 1479.43 E 5970149.90 N 373127.36 E 3.508 4435.26 8299.44 43.350 160.900 6653.01 6705.51 4299.32 S 1500.64 E 5970089.15 N 373147.53 E 1.667 4498.51 8394.83 44.270 161.240 6721.84 6774.34 4361.79 S 1522.06 E 5970026.33 N 373167.88 E 0.996 4563.68 8490.29 43.010 161.330 6790.92 6843.42 4424.18 S 1543.20 E 5969963.59 N 373187.95 E 1.322 4628.67 8523.75 44.770 160.270 6815.04 6867.54 4446.09 S 1550.83 E 5969941.55 N 373195.20 E 5.700 4651.58 8555.42 46.200 159.650 6837.24 6889.74 4467.30 S 1558.57 E 5969920.21 N 373202.58 E 4.726 4673.94 8585.48 46.290 158.820 6858.03 6910.53 4487.60 S 1566.27 E 5969899.78 N 373209.93 E 2.017 4695.47 --. 8618.99 48.480 159.390 6880.72 6933.22 4510.64 S 1575.06 E 5969876.59 N 373218.32 E 6.654 4719.93 8650.84 50.760 159.980 6901.35 6953.85 4533.39 S 1583.48 E 5969853.70 N 373226.35 E 7.296 4743.96 8680.59 52.900 159.470 6919.73 6972.23 4555.33 S 1591.59 E 5969831.63 N 373234.08 E 7.318 4767.12 8714.33 56.130 158.940 6939.32 6991.82 4581.01 S 1601.34 E 5969805.79 N 373243.40 E 9.658 4794.37 8746.26 58.310 159.130 6956.60 7009.10 4606.08 S 1610.94 E 5969780.56 N 373252.57 E 6.846 4821.00 8776.19 59.050 158.700 6972.16 7024.66 4629.93 S 1620.14 E 5969756.55 N 373261.36 E 2.760 4846.37 8810.52 61.650 158.210 6989.14 7041.64 4657.68 S 1631.10 E 5969728.62 N 373271.84 E 7.674 4876.01 8839.49 63.030 157.060 7002.59 7055.09 4681.41 S 1640.86 E 5969704.73 N 373281.20 E 5.920 4901.53 8870.79 62.790 157.100 7016.85 7069.35 4707.07 S 1651.72 E 5969678.88 N 373291.61 E 0.775 4929.28 8908.21 62.260 157.280 7034.11 7086.61 4737.68 S 1664.59 E 5969648.06 N 373303.95 E 1 .479 4962.34 8966.67 64.760 155.600 7060.18 7112.68 4785.63 S 1685.51 E 5969599.76 N 373324.05 E 4.990 5014.48 9003.65 66.270 153.980 7075.51 7128.01 4816.07 S 1699.84 E 5969569.07 N 373337.86 E 5.707 5048.09 ~029.42 67.960 153.740 7085.53 7138.03 4837.39 S 1710.30 E 5969547.58 N 373347.96 E 6.614 5071.82 9062.24 69.990 153.400 7097.31 7149.81 4864.82 S 1723.94 E 5969519.92 N 373361.12 E 6.260 5102.43 ~---------_._._._._--,_._-------_._-- 2 October, 2002 - 10:37 Page 4 of7 DrillQuÐst 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-38 Your Ref: API 501032042900 Job No. AKMW22143, Surveyed: 6 September, 2002 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9097.43 72.590 151.610 7108.59 7161.09 4894.38 S 1739.33 E 5969490.10 N 373376.00 E 8.820 5135.76 9130.04 73.160 152.370 7118.20 7170.70 4921.89 S 1753.96 E 5969462.34 N 373390.16 E 2.831 5166.92 9178.86 75.630 152.670 7131.33 7183.83 4963.60 S 1775.66 E 5969420.27 N 373411.14 E 5.094 5213.94 9274.08 82.470 153.270 7149.41 7201.91 5046.83 S 1818.11 E 5969336.33 N 373452.17 E 7.210 5307.35 9369.33 86.980 150.180 7158.16 7210.66 5130.32 S 1863.03 E 5969252.08 N 373495.65 E 5.731 5402.16 9465.47 87.850 149.190 7162.50 7215.00 5213.23 S 1911.51 E 5969168.35 N 373542.70 E 1.370 5498.13 9560.45 89.140 149.870 7164.99 7217.49 5295.06 S 1959.65 E 5969085.71 N 373589.44 E 1.535 5593.00 9655.32 89.320 148.980 7166.27 7218.77 5376.73 S 2007.91 E 5969003.22 N 373636.29 E 0.957 5687.78 9751.05 89.690 149.420 7167.10 7219.60 5458.96 S 2056.92 E 5968920.17 N 373683.89 E 0.601 5783.40 9845.99 89.880 149.810 7167.45 7219.95 5540.86 S 2104.94 E 5968837.46 N 373730.51 E 0.457 5878.27 9940.18 90.490 150.030 7167.15 7219.65 5622.36 S 2152.15E 5968755.16 N 373776.31 E 0.688 5972.41 10038.55 90.370 149.610 7166.41 7218.91 5707.40 S 2201.60 E 5968669.30 N 373824.30 E 0.444 6070.71 10133.75 88.340 149.680 7167.48 7219.98 5789.54 S 2249.71 E 5968586.35 N 373870.99 E 2.134 6165.83 10229.18 86.860 149.870 7171.48 7223.98 5871.92 S 2297.70 E 5968503.15 N 373917.57 E 1.564 6261.11 10324.59 88.400 151.090 7175.42 7227.92 5954.87 S 2344.67 E 5968419.41 N 373963.12 E 2.059 6356.41 10420.55 88.280 151.130 7178.20 7230.70 6038.85 S 2391.01 E 5968334.65 N 374008.01 E 0.132 6452.32 10514.32 88.590 151.420 7180.76 7233.26 6121.05 S 2436.06 E 5968251.69 N 374051.65 E 0.453 6546.05 10611.41 88. 830 150.970 7182.95 7235.45 6206.10 S 2482.83 E 5968165.85 N 374096.96 E 0.525 6643.11 10706.83 88.650 153.190 7185.05 7237.55 6290.39 S 2527.50 E 5968080.81 N 374140.17 E 2.334 6738.50 10801.97 88.590 152.490 7187.34 7239.84 6375.02 S 2570.91 E 5967995.46 N 374182.14 E 0.738 6833.60 10897.11 88.280 153.130 7189.94 7242.44 6459.61 S 2614.37 E 5967910.13 N 374224.14 E 0.747 6928.69 10993.30 88.150 153.790 7192.93 7245.43 6545.62 S 2657.33 E 5967823.40 N 374265.62 E 0.699 7024.79 11088.78 88.280 153.590 7195.91 7248.41 6631.17 S 2699.63 E 5967737.14 N 374306.45 E 0.250 7120.18 11184.14 88.030 153.570 7198.98 7251.48 6716.53 S 2742.04 E 5967651.07 N 374347.39 E 0.263 7215.44 11279.01 88.340 152.970 7201.98 7254.48 6801.21 S 2784.68 E 5967565.66 N 374388.59 E 0.712 7310.24 11375.91 88.400 153.130 7204.74 7257.24 6887.56 S 2828.58 E 5967478.58 N 374431.00 E 0.176 7407.07 11471.63 88.520 153.740 7207.31 7259.81 6973.14 S 2871.37 E 5967392.28 N 374472.32 E 0.649 7502.72 11567.14 88.650 153.380 7209.67 7262.17 7058.63 S 2913.89 E 5967306.07 N 374513.37 E 0.401 7598.16 11662.93 88.890 153.890 7211.73 7264.23 7144.44 S 2956.42 E 5967219.55 N 374554.42 E 0.588 7693.88 11758.36 88.950 153.090 7213.52 7266.02 7229.82 S 2999.01 E 5967133.45 N 374595.54 E 0.841 7789.25 1 i 853.97 88.950 153.360 7215.28 7267.78 7315.16 S 3042.07 E 5967047.39 N 374637.14 E 0.282 7884.82 1 949.24 89.080 153.080 7216.91 7269.41 7400.20 S 3084.99 E 5966961.62 N 374678.60 E 0.324 7980.04 12044.48 88.770 152.230 7218.70 7271.20 7484.78 S 3128.73 E 5966876.31 N 374720.89 E 0.950 8075.26 12139.26 86.740 152.720 7222.41 7274.91 7568.77 S 3172.49 E 5966791.59 N 374763.21 E 2.203 8169.95 1 ~~234.59 87.660 152.570 7227.07 7279.57 7653.33 S 3216.25 E 5966706.28 N 374805.51 E 0.978 8265.16 ---.-.-.-------.----- 2 October, 2002 - 10:37 Page 50f7 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for AlplneCD-2 - CD2-38 Your Ref: AP/501032042900 Job No. AKMW22143, Surveyed: 6 September, 2002 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) 12329.71 87.970 153.220 7230.70 7283.20 7737.95 S 3259.55 E 5966620.94 N 374847.36 E 0.757 8360.19 12425.15 87.360 153.010 7234.59 7287.09 7823.00 S 3302.61 E 5966535.17 N 374889.02 E 0.676 8455.53 12520.13 86.370 153.160 7239.78 7292.28 7907.56 S 3345.60 E 5966449.88 N 374930.50 E 1.054 8550.34 12615.10 88.090 150.540 7244.37 7296.87 7991.19 S 3390.35 E 5966365.50 N 374973.81 E 3.297 8645.19 12711.26 87.720 150.340 7247.89 7300.39 8074.78 S 3437.76 E 5966281.11 N 375019.78 E 0.437 8741.26 c-~ 12806.46 88.150 150.350 7251.32 7303.82 8157.45 S 3484.83 E 5966197.64 N 375065.43 E 0.452 8836.36 12901.96 87.540 149.930 7254.91 7307.41 8240.22 S 3532.35 E 5966114.08 N 375111.52 E 0.775 8931.75 12936.79 87.170 150.260 7256.51 7309.01 8270.38 S 3549.69 E 5966083.63 N 375128.35 E 1.423 8966.53 13010.00 87.170 150.260 7260.13 7312.63 8333.87 S 3585.96 E 5966019.53 N 375163.53 E 0.000 9039.62 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.5' MSL. Northings and Eastings are relative to 1944' FNL, 1517' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1944' FNL, 151 T FEL and calculated along an Azimuth of 151.830° (True). Magnetic Declination at Surface is 24.856°(24-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 13010.000., The Bottom Hole Displacement is 9072.62ft., in the Direction of 156.718° (True). Comments ~, Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 13010.00 7312.63 8333.87 S 3585.96 E Projected Survey 2 October, 2002 - 10:37 Page 60f7 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Alplnè CD-2 - CD2-38 Your Ref: API 501032042900 Job No. AKMW22143, Surveyed: 6 September, 2002 North Slope, Alaska Alaska North Slope Survey tool program for CD2-38 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description è- 0.00 343.00 0.00 343.00 343.00 13010.00 343.00 Tolerable Gyro(CD2-38 Gyro) 7312.63 MWD Magnetic(CD2-38) . ..- ---_.~--_. 2 October, 2002 - 10:37 Page 70f7 DrillQ(est 3.03.02.002 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-38 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00 I MD 'MD (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, DEFINITVE Survey Manager Attachment(s) ) c9öé)- /1/ 03-0ct-02 RECEIVED OCT 0 9 2002 AI_a or; & Gas Cons. Commi88ion Anchorage ~ ¡- -- J " ru. G ~ O. Sperry-Sun Drilling Services ~ Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-38 Gyro Job No. AKF022143, Surveyed: 6 September, 2002 Survey Report 2 October, 2002 ~. Your Ref: API 501032042900 Surface Coordinates: 5974413.52 N, 371720.66 E (70020' 17.9855" N, 151002' 27.2557" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974413.52 N, 128279.34 W (Grid) Surface Coordinates relative to Structure: 29.33 S, 3.67 E(True) Kelly Bushing: 52. 50ft above Mean Sea Level Elevation relative to Project V Reference: 52. 50ft Elevation relative to Structure: 52. 50ft Ein--It"Y-SLr1 DAIL.LING SÊAVlces A Halliburton Company DEF/N rnYE Survey Ref: 5vy9970 Alaska North Slope Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 0.00 0.000 0.000 -52.50 0.00 157.00 0.250 167.000 104.50 157.00 252.00 0.150 210.000 199.50 252.00 343.00 0.850 164.000 290.50 343.00 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-38 Gyro Your Ref: AP/501032042900 Job No. AKF022143, Surveyed: 6 September, 2002 Local Coordinates Northings Eastings (ft) (ft) O.OON 0.33 S O.64S 1.40 S O.OOE 0.08E 0.06E 0.19 E Global Coordinates Northings Eastings (ft) (ft) 5974413.52 N 5974413.18 N 5974412.88 N 5974412.12 N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.5' MSL. Northings and Eastings are relative to 1944' FNL, 1511' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1944' FNl, 1511' FEl and calculated along an Azimuth of 151.830° (True). Magnetic Declination at Surface is 24.856°(24-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 343.00ft., The Bottom Hole Displacement is 1.41ft., in the Direction of 172.327° (True). Survey toollJroøram for CD2-38 Gvro From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) r--- Survey Tool Description 0.00 343.00 343.00 Tolerable Gyro 0.00 2 October, 2002 - 10:41 Page 20f2 371720.66 E 371720.73 E 371720.71 E 371720.82 E Dogleg Rate (0/100ft) 0.159 0.183 0.828 Vertical Section North Slope, Alaska Comment 0.00 Tolerable Gyro 0.33 0.60 1.32 DrillQllest 3.03.02.002 Approval to Commence injection into CD2-38 ) ) Subject: Approval to Commence injection into CD2-38 Date: Tue, 8 Oct 2002 13:52:52 -0800 From: "Clifford L Crabtree" <ccrabtr@ppco.com> To: winton - aubert@admin.state.ak.us, tom - maunder@admin.state.ak.us CC: "Chris R Pierson" <crpiers@ppco.com> 2 " I'll ConocoPhillips requests approval to begin injection operations in CD2-38. The attached bond log for CD2-38 provides evidence of cement integrity. The attached PDF provides proximity information compared to surrounding wells. Other pertinent details follow: API Number: 50-103-20429 Packer: Baker S-3 8,820' MD (6,994' TVD ss) Tubing tail 8,936' MD (7,047' TVD ss) @ 65 degrees Top of Alpine C sand 9,109' MD (7,112' TVD ss) @ 73 degrees Bottom of logged interval 9,114' MD (7,114' TVD ss) 7" Casing Shoe 9,209 MD (7,138' TVD ss) PBTD 13,010 MD (7,260' TVD ss) """,. Full returns were reported during the cement job. Bond appears to be excellent across the logged interval:" Tubing and Casing were pressure tested to 3500 psi on 9/08/02 during r completion operations. Regards Cliff Crabtree Phillips Alaska Inc.- Alpine Subsurface Development Office: (907) 265-6842¡ Cell: (907) 240-5357 Email: ccrabtr@ppco.com¡ Fax:: (907) 265-1515 (See attached file: CD2-38 (1320) .pdf) (See attached file: SCMT_9105687_FIN.zip) Name: CD2-38 (l320).pdf ICD2-38 (1320).pdfl Type: Portable Document Format (application/pdt) Encoding: base64 - - -..-._--- . -~-------------~-------.-----.-.-..--.. -.. .-_u_---..----..----.--.- .---. ..-. -.- ------------.--. ---.. ----.._._.-.-.- --. --- - - ._--_.----------~-----.-----.-.-.-.-- -_.- ---- .---.-.-_n_n_-.-_-.---.-.-------.- ------.--- ,: : Name: SCl\tfT 9105687 FIN.zip! ~MT~~~~~~~~~:::j ttX. L ~ DnV'¿ A-p f to 'l f-, l M:¡ E/~w:.L Wj D.J-.... Cc or Pt1?~'-<'''1 k nvj~-- 1~/liPIOL. l1-'~ ~ ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner In, . ,," OhI1, , 5UBJECr:""""M,','"""e",.""c,'",h",',',~nical,lntegritY Tests THRU: Tom Maunder ffl' I '" Phillips P.I. Supervisor \\( -o')CÐ2 rS CRU FROM: Chuck Scheve Alpine Petroleum Inspector NON. CONFIDENTIAL f4""'VÞ DATE: November 6, 2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well CD2-16 Type Inj. S T.V.D. 6929 Tubing 255 255 255 255 Interval I P.T.D. 202-144 Type test P Test psi 1732 Casing 1200 2125 2tOO 2,100 P/F f Notes: Well CD2-29 Type Inj. S T.V.D. 6974 Tubing 520 520 520 520 Interval I P.T.D. 202-148 Type test P Test psi 1744 Casing 1450 2200 2050 2050 P/F f Notes: Well CD2-38 Type Inj. S T.V.D. Tubing 255 255 255 255 Interval I P.T.D. 202-171 Type test P Test psi Casing 1150 1775 1750 1750 P/F f Notes: Well CD2-44 Type Inj. S T.V.D. Tubing 120 120 120 120 Interval I P.T.D. 202-165 Type test P Test psi Casing 125 1950 1925 1925 P/F f Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year CYCle s = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details I traveled to Phillips CD210cation in the Alpine Field and witnessed the initial MIT on wells CD2-16, CD2-29, CD2-38 and CD2-44. The pr~testtubing and casing pressures were, observed and found to be stable; The standard annulus pressure test was then performed with all 4 wells demonstrating good mechanical integrity. M.I.T.'s performed: ~ Attachments: Number of Failures: Q Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. MIT CRU CÐ2 11-6-02 CS.xls 11/15/2002 ) ) CD2-38 Details of 7" Cement Job Run casing (223 jts total 7",26#, L-80) MU FMC mandral hanger and LJ, land casing with FS @ 9209', FC @ 9120'. PUW 330k SOW 160k Lay down fill-up tool and RU cement head. Stage pumps up to 6.0 bpm and condition mud for cementing. lower yp to 15, final circulating presssure 540 psi. PJSM. Line up to Dowell, pumped 5 bbls of FW and tested lines to 3500 psi. Pumped 20 bbls of 8.3 ppg ARCO wash, 50 bbls of 12.5 ppg Mud Push XL spacer, dropped bottom plug, pumped 31 bbls of 15.8 ppg G wI adds, dropped top plug and began displacement with 20 bbls of FW from Dowell. Switched to rig pumps and displaced with 326.7 bbls of 9.65 ppg LSND mud @ 6 - 6.5 bpm I 250 - 790 psi, reduced rate to 4.0 bpm last 10 bbls of displacement. Bumped plugs to 1400 psi, floats held. CIP @ 1910 hrs. Full returns throughout job, reciprocated pipe until last 15 bbls of displacement. Monitor annulus, Observed slight flowback. shut in well @ 1920 hrs. with pipe rams and monitor pressure for 25 min, zero psi on casing. Open choke no returns to shakers. Open rams, observed slight flow, line up returns to trip tank and monitor well. Gained 0.5 bbls in 8 min (7.7 bph), gained 0.25 bbls in the next 12 min. (1.25 bph). Concluded well breathing slightly. (Rigged down cement head and casing equipment while monitoring well) ~ : Prelim: CO2-53 (CO2-53) i ) ') -3498- -4664- \ \ \ ~ +' ~ -5829- 1: 0 ~ ~ :; 0 00 -6995- -8161- -9327- ! C02-41 (C02-41) I UJV"" 6600 )' CO.2.-48 (..C02-48) I 6800 hQOO Prelim: CO2-58 (CO2-58 PBI) I /UVV 6500 6600 6700 6800 'Î'~ 6900 .2-47) ~7)i Prelim: C02-36 (C02-36) \. i Ii, 7100 1'2.()() Prelim: CO2-58 (CO2-58) I 0 1166 4664 2332 West(-)Æast(+) [ft] 3498 5829 ) ~j~lJf (ill ~ iÆ~iÆ£)[«!Æ ) A.I,A.~1iA OIL AND. GAS CONSERVATION COMMISSION Vem Johnson Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 TONY KNOWLES, GOVERNOR 333 W. TH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Unit CD2-38 Phillips Alaska, Inc. Permit No: 202-171 Surface Location: 1944' FNL, 1517' FEL, Sec. 2, TIIN, R4E, UM Bottomhole Location: 243' FSL, 2098' FWL, Sec. 12, TIIN, R4E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced service well. The 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). Sincerely, (/}/AA . ~h' t:x ~p~ ~~chsli Taylo.;v-O' Chair BY ORDER OF THE COMMISSION DATED this~day of August, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1b. Type of Well Exploratory Service X / Development Gas 5. Datum Elevation (DF or KB) DF52' 6. Property Designation ADL 380075 7. Unit or property Name Colville River Unit 8. Well number ') 1a. Type of Work 2. Drill X Re-Entry Name of Operator Phillips Alaska, Inc. Address P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface Redrill Deepen 3. 4. 1944' FNL, 1517' FEL, Sec. 2, T11N, R4E, UM At target (=7" casing point) 1721' FNL, 326' FWL, Sec. 12, T11N, R4E, UM At total depth 243' FSL, 2098' FWL, Sec. 12, T11 N, R4E, UM 12. Distance to nearest 13. Distance to nearest well Property line CD2-39 / 1944' FNL 380075 feet 11.4' at 250' MD 16. To be completed for deviated wells Kickoff depth 400 feet Maximum hole angle ) WGA- f/Z-i/O 1- ~ Ø-u/~ Stratigraphic Test Development Oil Single Zone X Multiple Zone 10. Field and Pool Colville River Field / Alpine Oil Pool $200,000 15. Proposed depth (MD and lVD) 13063' MD 2560 7252' TVD 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Maximum surface 2556 / psig At total depth (lVD) feet CD2-38 ./ 9. Approximate spud date 9/10/2002 / 14. Number of acres in property Feet 88.8° 18. Casing program l Settin./Q Depth size Specifications Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 16" 62.5# H-40 Weld 77' 37' 37' 1141 1141 12.2511 9.625" 36# J-55 BTC 2637' 371 371 26741 2390' 8.5" 7" 26# L -80 12.6# L-80 BTC-M 9265' IBT mod 8880' N/A 4.5" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot Approved by Form 10-401 Rev. 7-24-89 37' 32' 37' 32' 93021 8912' 72081 7110' feet feet Plugs (measured) feet feet Junk (measured) 11. Type Bond (see 20 AAC 25.025) Statewide Number #59-52-180 Amount feet 3258 at psig 7200' TVD.SS Quantity of cement (include stage data) Pre-i nstalled 523 Sx Arcticset III L & 230 Sx Class G 121 Sx Class G Tubing ':;:.,¡> t:,:~~åspfeq ~~thC True Vertical depth Cemented BOP Sketch Refraction analysis Diverter Sketch Seabed report 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~~.{... ~ Title Drilling Team Leader .? Commission Use Only Permit Number J ~ I API number q I Approval date ..a \ -""I ,., , I See cover letter for 2. <:) 2... - // 60- /I'?--? - 2. 07'2 / - 0 ~ ~ Other requirements Conditions of approval Samples required Yes (fuþ Mud log required Yes & Hydrogen sulfide measures Yes @ Directional survey required @ No Required working pressure for BOPE M M M""'-:. t- 1) I) - L- c ' . 2 3M 5M 10. 15 '~QOyC [V JOOO f'~ ( . Other: ,vtJ:T I WL rectlAÄ N.J, (J.e-r z-oMc '1.5, D~';(k\lz.)) &Vè-ý+4 ryCM.' ~Ì"'L~ w¿.JVl'd. \)1glnal SIgned By . by order of rx "'\ I~ Cammy Oechsll Taytor Commissioner the commission Date ~ j 716\,...>2- &.Jbmit in triplicate Jfi¡~¡1 Drilling program X 20 MC 25.050 requirements X Date ð( is I" 1-- L ) ) CD2-38 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) ,12-1/411 Hole 19-518" Casina Interval Event Risk Level Conductor Broach Low Well Collision medium Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVO Lost Circulation Low Low ,8-1/2" Hole 17" Casina 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 10.4 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 (ECO) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned well bore. 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 Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) 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 9.0 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 0 fu vi II I ,"'C\L. ) ) Alpine: CD2-38 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 16. 17. 18. 19. 20. 21. 22. Procedure Move on Doyon 19. Drill 12- ~" hole to the surface casing point as per the directional plan. Run and cement 9-5/8" surface casing. Install and test BOPE to 5000 psi. / Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. /~ Drill 8-~1I hole to intermediate casing point in the Alpine Sands. (LWD Program: GR/RES/PWD) / Run and cement 7" casing as per program. Top of cement> 500 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. BOPE test to 5000 psi. / /' Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore/~ having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. /' Run 4-~ 12.6#, L-80 tubing with DB injection nipple, gas lift mandrel and packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. /' Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Circulate tubing to diesel and install freeze protection in the annulus. / Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi 1 30 mins. Set BPV and secure well. Move rig off. ~A~'~ :' ~ I G , N I ~ ) ') Well Proximitv Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-39 will be the closest well to CD2-38, 11.4' at 250. MD. Accounting for survey / tool inaccuracies, the ellipse separation between these wells will be 7' at 250' MD. Drilling 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 Pumping Operations: Incidental fluids developed from drilling operations on well CD2-38 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The CD2-38 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze ,/ protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD2-38 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the below the base of the Schrader Bluff Formation (C-40). These 300- 400. thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2390') + 1,500 psi = 2,991 psi = 1,081 psi Pore Pressure / 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 850/0 of 850/0 of OD (ppf) Grade Range Type Collapse Collapse Burst Burst .,/ 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2.992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi $ U 1 \vï .~ .~ .- CD2-38 DRILLING FLUID PROGRAM Density PV YP Funnel Viscosity Initial Gels 10 minute gels API Filtrate HPHT Fluid Loss at 160 PH KCL Surface Hole: ) ) SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 ~" Section - 6 1 18" point - 12 ~" 8.8 - 9.6 ppg 9.6 - 9.8 ppg ./ 9.0-9.3 ppg 10 - 25 10 -15 20 - 60 15 - 25 25 - 30 100 - 200 4-8 10 - 15 <18 12 - 20 NC-10cc/30 min 4 - 12 cc/30 min (drilling) 12 - 14 cc/30 min 8.5-9.0 9.0 -10.0 9.0-9.5 6% A standard high viscosity fresh water I gel spud mud is recommended for the surface interval. Keep flowline viscosity at :t 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 I 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 wellbore 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 60/0 KCI, with :t 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. .J h I ",j¡ I í V j ,,~ ) Colville River Field CD2-38 Injection Well Completion Plan 16" Conductor to 114' . 4-1/2" Camco DS Nipple (3.812') at 2000' TVD = 2166' MD I 9-5/8" 36 ppf J-55 STC Surface Casing @ 2674' MD /2390' TVD cemented to surface 4-1/2" 12.6 ppf L-80 1ST M tUbing run with Jet Lube Run'n'Seal pipe dope Cameo KBG-2 GLM (3.909" DRIFT ID) wi dummy Updated 08/13/02 Packer Fluid mix: 9.? ppg KCI Brine with ?OOO' TVD diesel ca.p Tubing suspended with diesel Completion MIl TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco DS6 nipple 2166' 2000' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco KSG2- GLM (3.909" ID) 8700' 6996' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) Baker 83 Packer wI millout extension 8800' 7054' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) HES "XN" (3.725")-62° inc 8900' 7104' 4-1/2", 12.6#/ft, 1ST-Mod 10' pup joint WEG 8912' 7110' J TOC @ +1- 8522' MD 16873' TVD (>500' MD above top Alpine) . ï:(:~.;".;<,::~."t~~ Baker 83 Packer WI millout extension at +1- 8800' MD <200' TVD from top of Alpine Top Alpine at 9022' MD /7153' TVD Well TD at 130641 MDI 72521 TVD I , 1/ I ¡ 78 26 ppf L-80 STC Mod Production Casing @ 9302/7208' TVD @+/- 87° ) I:) IQ.... I ':¡, A L 1, ~ll¡í~þ\ ) ') CD2-38 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 ASP Drilling (in) MDrrVD(ft) (lbs. I gal) (psi) (psi) 16 114/114 10.9 52 53 9 5/8 2674 I 2390 14.5 1081 1563 7" 9302 I 7208 16.0 32~ 2556 N/A 13064 I 7252 16.0 32 2) N/A \../ . NOTE: The Doyon 195000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]0 Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Iblgal 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 1. ASP CALCULATIONS 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 Drilling below surface casing (9 5/8") 2. 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) = 3262 - (0.1 x 7208) = 2541 psi 3. Drilling below intermediate casing (7') ASP = ~\:- (0.1 x D) , = ~~~)- (0.1 x 7252') = 2556 psi / ~. j I G". ,. i~ 'A I - ,11 .fIJ'~ \tøa Alpine. CD2-38 Well Cementinq Requirements 95/8" Surface Casine: run to 2674' MD /2390' TVD. Cement from 2567' MD to 2067' (500' of till) with Class G + Adds @ 15.8 PPG, and from 2067' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1602' MD). Lead slurry: System: Tail slurry: System: (2174'-1659') X 0.3132 fe/ft X 1.5 (50% excess) = 241.9 ft3 below permafrost 1659' X 0.3132 fe/ft X 4 (300% excess) = 2078.4 ft3 above permafrost Total volume = 241.9 + 2078.4 = 2320.3 ft3 => 523 Sx @ 4.44 ft3/sk / /' 523 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% SOOl accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant . 500' X 0.3132 felft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 felft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fe/sk / 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % SOOl accelerator @ 15.8 PPG yielding 1.17 fe Isk / 7" Intermediate Casin2 run to 9303' MD / 7208' TVD Cement from 9303' MD to +/. 8522' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (9203' - 8522') X 0.1268 ft3fft X 1.4 (40% excess) = 120.9 fe annular vol. 80' X 0.2148 fefft = 17.2 fe shoe joint volume Total volume = 120.9 + 17.2 = 138.1 ft3 => 121 Sx @ 1.15 felsk / System: 121 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 ft3/sk /' 1 By Weight Of mix Water, all other additives are BWOCement Orl1ff"~IJll .~ ' ä"Î . !I. ~.[~ > . I .~ l:,~ ¡ M 1;1 ¡¡ ";!æ!J c:::> :::c:J ~~~ ~") ~"7~;'""~---,,"'::7-:J "::::C' ,'.'3 ~"'.-F.;.;,;~ i~ Ii _~~t~_1t C \Y¡bnit 0 oplJ; Alaska e .;: -2, Slot CD2-38 " ~-38 - CD2-38 (wp02) Revised: 7 August, 2002 ~ PROPOSAL REPORT 8 August, 2002 ~. Surface Coordinates: 5974413.52 H, 371720.66 E (70020' 17.9855" H, 151002' 27.2557" W) Surface Coordinates relative to Project H Reference: 974413.52 H, 128279.34 W (Grid) Surface Coordinates relative to Structure: 29.33 S, 3.67 E (True) Kelly Bushing: 52.00ff above Mean Sea Level 7~12':~T;'Y fi!j..,11 D:O;:~ï"I~~~~..~~~1e:.1I ... H~~~~if Proposal Ref: pr09948 Colville River Unit Measured Sub-5ea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 0.00 0.000 0.000 -52.00 0.00 100.00 0.000 0.000 48.00 100.00 200.00 0.000 0.000 148.00 200.00 300.00 0.000 0.000 248.00 300.00 400.00 0.000 0.000 348.00 400.00 500.00 2.000 145.000 447.98 499.98 600.00 4.000 145.000 547.84 599.84 700.00 6.000 145.000 647.45 699.45 800.00 8.000 145.000 746.70 798.70 900.00 10.000 145.000 845.47 897.47 1000.00 12.853 jEi~Jï;;i~~. 1100.00 15.760 1200.00 18.695 1268.12 20.705 1300.00 21.648 1400.00 24.61~".:,,_151;565 n', 1.68 1373.68 1500.00 27.~'- '-:15EL510: - 1411.47 1463.47 1600.00', 30.559 159.284 1498.87 1550.87 1659.94 ':"32.348:':' --:'159.686 1550.00 1602.00 1700.06:. '..00.$39':" " 159.933 1583.62 1635.62 1800.odi~. 36.523 160.487 1665.49 1717.49 1900.00 39.508 160.969 1744.27 1796.27 1914.70 39.947 161.034 1755.57 1807.57 2000.00 39.947 161.034 1820.97 1872.97 2100.00 39.947 161.034 1897.63 1949.63 C~.-' 2200.00 39.947 161.034 1974.30 2026.30 -. 2300.00 39.947 161.034 2050.96 2102.96 2400.00 39.947 161.034 2127.62 2179.62 2429.19 39.947 161.034 2150.00 2202.00 2500.00 39.947 161.034 2204.29 2256.29 t>&~ ~'''-'<~-n 8 August, 2002 - 11 :47 Sperry-Sun Drilling Services Proposal Report for Plan: CD2-38 - CD2-38 (wp02) Revised: 7 August, 2002 local Coordinates Northings Eastings (ft) (ft) O.OON O.OON O.OON O.OON O.OON 52.37 S 74.06 S 100.64 S 121.52 S 132.05 S 168.21 S 209.01 S 254.34 S 283.63 S 304.07 S 358.08 S 416.21 S 425.10 S 476.89 S 537.61 S 598.34 S 659.06 S 719.78 S 737.50 S 780.50 S 0.00 E 35.55 E 47.38 E 60.42 E 69.97 E 74.63 E 89.97 E 106.40 E 123.88 E 134.84 E 142.36 E 161.78 E 182.09 E 185.15 E 202.95 E 223.82 E 244.69 E 265.56 E 286.42 E 292.51 E 307.29 E Page 2 of 10 "-'< -":<;:. ~~~;'ic:,f1;. ~~i~f7,;t:: 0.00 SHL(1944' FNL& 1517' FEL, Sec. T11 N-R4E) Global Coordinates Northings Easti (ft) 5974413.52 N 5974412.07 N 5974407.74 N 5974400.51 N 5974390.41 N 5974377.45 N 5974360.55 N 5974338.67 N 5974311.86 N 5974290.82 N 5974280.21 N 5974243.80 N 5974202.73 N 5974157.10 N 5974127.63 N 5974107.06 N 5974052.72 N 5973994.25 N 5973985.32 N 5973933.22 N 5973872.15 N 5973811.08 N 5973750.01 N 5973688.94 N 5973671.12 N 5973627.87 N 371721.64 E 371724.56 E 371729.44 E 371736.26 E 371745.01 E 371755.31 E 371766.77 E 371779.35 E 371788.55 E 371793.02 E 371807.74 E 371823.47 E 371840.17 E 371850.63 E 371857.79 E 371876.29 E 371895.61 E 371898.51 E 371915.43 E 371935.25 E 371955.08 E 371974.90 E 371994.73 E 372000.51 E 372014.55 E 0.000 0.000 0.000 0.000 2.000 2.000 2.000 2.000 2.000 01'/ 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ...~;:,.~~~~'" orth Slope, Alaska Alpine CD-2 Comment 0.00 0.00 0.00 0.00 Begin Dir @ 2.00/1ooft (in 12-1/r Hole) : 400.00ft M D, 400.ooft TVD 1.73 6.93 15.58 27.68 43.21 Increase in Dir Rate @ 3.0° /100ft : goo.OOft MD, 897.47ftTVD 62.95 87.65 117.24 140.16 W. Sak 151.64 190.76 234.48 282.69 313.69 Permafrost 335.26 ----' 392.04 452.88 462.15 End Dir, Start Sail @ 39.95° : 1914.70ft MD, 1807.57ft TVD 516.22 579.60 642.98 706.36 769.74 788.24 C-40 833.12 Dril/Quest 2.00.09.006 Colville River Unit Measured Depth (ft) 2600.00 2674.41 2690.07 2700.00 2800.00 2900.00 3000.00 3100.00 3168.78 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000 00 4100 00 4200.0~. Incl. Azim. 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 39.947 161.034 Sperry-Sun Drilling Services Proposal Report for Plan: C02-38 - C02-38 (wp02) Revised: 7 August, 2002 orth Slope, Alaska Alpine CD-2 Sub-Sea Vertical local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Easting (ft) (ft) (ft) (ft) (ft) 2280.95 2332.95 841.22 S 328.16 E 5973566.80 N 2338.00 2390.00 886.41 S 343.69 E 5973521.36 N fi1yWfl;;~. .,,~;~;;;;t:~~~ 2350.00 2357.62 2434.28 2510.94 2587.61 2664.27 2717.00 2740.94 0.92 7.58 3354.25 3430.91 3507.58 430000. 39.947 "161.034 3584.24 4400.0Œ¥~)) 39.947 161.034 3660.90 4500.00 39.947 161.034 3737.57 4564.48 39.947 161.034 3787.00 4600.00 39.947 161.034 3814.23 4700.00 39.947 161.034 3890.90 4800.00 39.947 161.034 3967,56 <:::> 4820.14 39.947 161.034 3983.00 4854.05 39.947 161.034 4009.00 J~) 4900.00 39.947 161.034 4044.23 ~,- ~?) "'~-;;.. (.,:;,;1: ~:::":::f~,:".ðO 2817,60 28$;6Ó:~it:;":~11 .28 S 2894.26>g~~6"\~l.,.:;;L" 1327.00 S 2970~",,~,-'<~3 .' 1387.72 S ,W>4~59 . ':?~ 3091is9 1448.45 S ':'h5~12~~õ.:!'i: 3176.26 1509.17 S ~itw~~, -?;:~~;:-¡ 39.947 16.1.034",' 39.947. ,,~61.b34'.. 39.~4t '}6f-ð34' .' , 39 94~ 161 .034 ". 39.947':~""161 034': r-- 8 August, 2002 - 11 :47 895.92 S 346.95 E ..,"'-' 5~51 t;~N 1:::: :'ftjEQ~:J~=::.~ 1 .11 S~~~~:j:i' 411.6:rt: 5973322.52 N 1 S 432.50 E 5973261.45 N S 446.85 E 5973219.45 N 453.36 E 5973200.38 N 2402.00 2409.62 2486.28 2562.94 2639.61 2716.27 2769.00 2792.9~f~~~ ' 3252.92 1569.89 S 3329.58 1630.61 S 3406.25 1691.33 S 3482.91 1752.06 S 3559.58 1812.78 S 3636.24 1873.50 S 3712.90 1934.22 S 3789.57 1994.94 S 3839.00 2034.10 S 3866.23 2055.67 S 3942.90 2116.39 S 4019.56 2177.11 S 4035.00 2189.34 S 4061.00 2209.93 S 4096.23 2237.83 S ~~~~: 474.23 E 5973139.31 N 495.10 E 5973078.24 N 515.97 E 5973017.17 N 536.83 E 5972956.10 N 557.70 E 5972895.03 N 578.57 E 5972833.96 N 599.44 E 5972772.89 N 620.30 E 5972711.82 N 641.17 E 5972650.75 N 662.04 E 5972589.68 N 682.91 E 5972528.61 N 703.77 E 5972467,54 N 724.64 E 5972406.47 N 738.10 E 5972367.10 N 745.51 E 5972345.40 N 766.38 E 5972284.33 N 787.24 E 5972223.26 N 791.45 E 5972210.96 N 798.52 E 5972190.25 N 808.11 E 5972162.19 N Page30f10 52.24 E 0.000 372054.21 E 0.000 372074.03 E 0.000 372093.86 E 0.000 372113.68 E 0.000 372133.51 E 0.000 372147.14 E 0.000 372153.33 E 0.000 372173.16 E 0.000 372192.98 E 0.000 372212.81 E 0.000 372232.64 E 0.000 372252.46 E 0.000 372272.29 E 0.000 372292.11 E 0.000 372311.94 E 0.000 372331.76 E 0.000 372351.59 E 0.000 372371.42 E 0.000 372391.24 E 0.000 372411.07 E 0.000 372423.85 E 0.000 372430.89 E 0.000 372450.72 E 0.000 372470.54 E 0.000 372474.54 E 0.000 372481.26 E 0.000 372490.37 E 0.000 Comment .000 .000 896.50 943.67 9-5/8" Csg Pt ... Drill out 8-112" Hole 2674.41ft MD. 2390.00ftTVD 9-5/8" Casing 953.59 C-30 959.88 1023.26 '---" 1086.65 1150.03 1213.41 1257.00 C-20 1276.79 1340.17 1403.55 1466.93 1530.31 1593.69 1657.07 1720.45 1783.83 1847.22 1910.60 1973.98 ~ 2037.36 2100.74 2141.61 K-3 Marker 2164.12 2227.50 2290.88 2303.65 Basal K-3 Sand 2325.14 K-2 Marker 2354.26 Ori/lOuest 2.00.09.006 Colville River Unit Measured Depth Incl. Azim. (ft) 4980.58 39.947 161.034 5000.00 39.947 161.034 5100.00 39.947 161.034 5200.00 39.947 161.034 5300.00 39.947 161.034 5400.00 39.947 161.034 5500.00 39.947 161.034 5600.00 39.947 161.034 5700.00 39.947 161.034 5800.00 39.947 161.034 5900.00 39.947 161.034 6000.00 39.947 161.034 6100.00 39.947 161.034 6200.00 39.947 161.034 6300.00 39.947 161.034 Sperry-Sun Drilling Services Proposal Report for Plan: CD2-38 - CD2-38 (wp02) Revised: 7 Augusts 2002 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Easti (ft) Sub-Sea Vertical Depth Depth (ft) (It) 4106.00 4158.00 4120.89 4172.89 4197.55 4249.55 4274.22 4326.22 4350.88 4402.88 4427.55 4479.55 4504.21 4556.21 4580.87 4632.87 4657.54 4709.54 4734.20 4786.20 2286.76 S 2298.55 S 2359.28 S 2420.00 S 2480.72 S 824.93 E 828.98 E 849.85 E 870.71 E 891.58 E 5972112.98 N 5972101.12 N 5972 5 N 8N N =:.< -~ E~:1: !~~~'~j¡~i)i:;~~~:~~ ~ 212~.61 S~;~;i';:'975.05~E 5971673.63 N -- 3 S 995.92 E 5971612.56 N 4810.87 4862.87 ",f1¥f)'!!f,;,,,-, 4887.53 493~.~B-f~"~-? S ~~6:~~ .!J~::;:(~~t:~:~;~J¡f ~27 :;~ ~ 511"l4~~.- 'sì, .~ 2 3087.94 S 6400.00 39.947 161.034 :.619.(t9 .°' 5246.19 3148.66 S 6500.00 39.947 161,~~ .:5270.8&-. 5322.85 3209.38 S 6600.00 39.947 1 e,1'~Ò34>--.: 7.51 5399.51 3270.11 S 6700.00 39.947. . . 161~O34.. 24.18 5476.18 3330.83 S 6800.0j) 39;947'" 1ôf004 . - 5500.84 5552.84 3391 .55 S 6877.16.. . "~.947:.'" '''161.034 5560.00 5612.00 3438.41 S 6900.00.. 99~947 .,.161.034 5577.51 5629.51 3452.27 S 7000.00 . 39.947 "161.034 5654.17 5706.17 3512.99 S 7100.0d*\f) 39.947 161.034 5730.84 5782.84 3573.72 S 7200.00 39.947 161.034 5807.50 5859.50 3634.44 S 7300.00 39.947 161.034 5884.16 5936.16 3695.16 S 7400.00 39.947 161.034 5960.83 6012.83 3755.88 S 7490.23 39.947 161.034 6030.00 6082.00 3810.67 S 7500.00 39.947 161.034 6037.49 6089.49 3816.60 S <:::) 7600.00 39.947 161.034 6114.16 6166.16 3877.33 S ~ ~\._""} -~~- {;:) "''<.''r-';:----:_~:'':J 8 August, 2002 - 11 :47 r-- 1016.79 E 5971551.49 N 1037.65 E 5971490.42 N 1058.52 E 5971429.35 N 1079.39 E 5971368.28 N 1100.26 E 5971307.21 N 1121.12 E 5971246.14 N 1141.99 E 5971185.07 N 1162.86 E 5971124.00 N 1183.73 E 5971062.93 N 1204.59 E 5971001.86 N 1220.70 E 5970954.73 N 1225.46 E 5970940.79 N 1246.33 E 5970879.72 N 1267.20 E 5970818.65 N 1288.07 E 5970757.58 N 1308.93 E 5970696.51 N 1329.80 E 5970635.44 N 1348.63 E 5970580.34 N 1350.67 E 5970574.37 N 1371.54 E 5970513.30 N Page 4 of 10 372589.50 E 372609.32 E 372629.15 E 372648.98 E 372668.80 E 372688.63 E 372708.45 E 372728.28 E 372748.10 E 372767.93 E 372787.76 E 372807.58 E 372827.41 E 372847.23 E 372867.06 E 372882.36 E 372886.88 E 372906.71 E 372926.54 E 372946.36 E 372966.19 E 372986.01 E 373003.90 E 373005.84 E 373025.66 E orth Slope, Alaska Alpine CD-2 _ft},~~- I F{ête~:~j~::<,¿Section Comment "~;--, (°f(Qoft) -'- .--- ~'.~~--'- .,. .000 2405.33 Base K-2 Cycle .000 2417.64 0.000 2481.02 0.000 2544.41 0.000 2607.79 ~' 0.000 2671.17 0.000 2734.55 0.000 2797.93 0.000 2861.31 0.000 2924.69 0.000 2988.07 0.000 3051.45 0.000 3114.83 0.000 3178.21 0.000 3241.60 0.000 3304.98 0.000 3368.36 0.000 3431.74 0.000 3495.12 0.000 3558.50 0.000 3607.41 Albian 97 0.000 3621.88 0.000 3685.26 0.000 3748.64 0.000 3812.02 0.000 3875.40 0.000 3938.79 0.000 3995.97 Albian 96 0.000 4002.17 0.000 4065.55 Dríl/Quest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: C02-a8 - C02-38 (wp02) Revised: 7 August, 2002 Colville River Unit Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 7700.00 39.947 161.034 6190.82 7800.00 39.947 161.034 6267.48 7900.00 39.947 161.034 6344.15 8000.00 39.947 161.034 6420.81 8100.00 39.947 161.034 6497.48 8200.00 39.947 161.034 6574.14 8227.21 39.947 161.034 6595.00 8300.00 39.947 161.034 6650.80 8400.00 39.947 161.034 6727.47 8500.00 39.947 161.034 6804.13 8508.02 39.947 161.034 6810.28 8555.60 42.738 160.126 8600.00 45.348 159.361 8631.96 47.230 158.852 8700.00 51.243 157.864 Vertical Depth (ft) 6242.82 6319.48 6396.15 6472.81 6549.48 6626.14 6647.00 6702.80 6779.47 6856.13 local Coordinates Northings Eastings (ft) (ft) 3938.05 S 3998.77 S 4059.49 S 4120.21 S 4180.94 S ~-øJ~{t¿ÿ"~- orth Slope, Alaska Alpine CD-2 Global Coordinates Northings Easti (ft) .. . ~¡~,~~;"lt~:P Comment 1392.40 E 1413.27 E 1434.14 E 1455.01 E 1475.87 E .000 4128.93 .000 4192.31 0.000 4255.69 0.000 4319.07 0.000 4382.45 "-" 0.000 4445.83 0.000 4463.08 HRZ 0.000 4509.21 0.000 4572.59 0.000 4635.97 5970452.23 N 5970391.16 N. 5970 .09 N 2N N :E:!: ~ft~."~;¡~f~:;!~~:E ~ 43ß~.10 S.~;J",,""c1538.4lfE 5970024.74 N S 1559.34 E 5969963.67 N 6862.2~y~W~. 68~~Z?~~:~~~é~' :487 :~~ ~ . .. 4508.87 S 4556.75 S a 8705.75 51.583 157 .7~~, 7000.00 8771.36 55.460 15Cr940.. '. 7039.00 8800.00 57.155.' ,~.156.596 7054.89 8900'9~~Þ, 63;077 :- 1ß5~.4ð1. 7104.69 8930._1'4\;),,64.876 fS5.175 7118.00 . . 8972.31( .'. :67 ~$Ç7 " 154.757 7083.00 7135.00 9000.00; ;. 69.008 . 154.490 7093.28 7145.28 9022.22i1J?! 70.326 154.279 7101.00 7153.00 9100.00 74.944 153.568 7124.21 7176.21 9200.00 80.883 152.697 7145.14 7197.14 9300.00 86.824 151.855 7155.84 7207.84 9302.00 86.943 151.838 7155.95 7207.95 9302.96 87.000 151.830 7156.00 7208.00 ::tt~- .. ~. t; """, ~..; 8 August, 2002 - 11 :47 4560.91 S 4609.59 S 4631.49 S 4710.67 S 4735.44 S 4770.24 S 4793.44 S 4812.23 S 4878.88 S 4966.07 S 5054.04 S 5055.80 S 5056.64 S 373144.62 E 373150.01 E 373164.44 E 373184.27 E 373204.09 E 1561.02 E 5969958.77 N 373205.69 E 0.000 4641.06 Begin Dir @ 6.0o/100ft: 8508.02ft "./ MD, 6862.28ft TVD 1571.47 E 5969928.96 N 373215.63 E 6.000 4672.12 Base HRZ 1582.16E 5969899.83 N 373225.82 E 6.000 4702.69 1590.40 E 5969878.11 N 373233.70 E 6.000 4725.61 K-1 Marker 1609.42 E 5969829.90 N 373251.89 E 6.000 4776.79 1611.11E 5969825.71 N 373253.51 E 6.000 4781.26 Kuparuk 1631.42 E 5969776.70 N 373272.99 E 6.000 4833.76 LCU-Miluveach 1640.82 E 5969754.64 N 373282.01 E 6.000 4857.50 1676.04 E 5969674.87 N 373315.86 E 6.000 4943.93 1687.41 E 5969649.90 N 373326.82 E 6.000 4971.14 Miluveach A 1703.67 E 5969614.84 N 373342.47 E 6.000 5009.49 Alpine D 1714.67 E 5969591.45 N 373353.08 E 6.000 5035.14 ---' 1723.68 E 5969572.51 N 373361.76 E 6.000 5055.95 Alpine C 1756.31 E 5969505.30 N 373393.25 E 6.000 5130.12 1800.49 E 5969417.38 N 373435.93 E 6.000 5227.83 1846.72 E 5969328.63 N 373480.65 E 6.000 5327.21 1847.66 E 5969326.85 N 373481.56 E 6.000 5329.21 7" Csg Pt... Drill out 6-1/8" Hole: (1721' FNL& 326' FWL, Sec. 12- T11N-R4E) 1848.12 E 5969326.00 N 373482.00 E 6.000 5330.16 TARGET (Heel) Begin Dir @ 3.0o/100ft: 9302.96ft MD, 7208.00f TVD 7" Casing Target - CD2-38 (Heel), Current Target PageSof10 OrHlQuest 2.00.09.006 a ~ ~< ~-z..: Colville River Unit Measured Depth (ft) Incl. Azim. 9381.43 89.354 151.835 9400.00 89.354 151.835 9500.00 89.354 151.835 9600.00 89.354 151.835 9700.00 89.354 151.835 9800.00 89.354 151.835 9900.00 89.354 151.835 10000.00 89.354 151.835 10100.00 89.354 151.835 10200.00 89.354 151.835 10300.00 89.354 151.835 10400.00 89.354 151.835 Sub-Sea Depth (ft) 7158.50 7158.71 7159.83 7160.96 7162.09 7163.21 7164.34 7165.47 7166.60 7167.72 7168.85 7169.98 Vertical Depth (ft) 7210.50 7210.71 7211.83 7212.96 7214.09 7215.21 7216.34 Sperry-Sun Drilling Services Proposal Report for Plan: CD2-38 - CD2-38 (wp02) Revised: 7 August, 2002 Local Coordinates Northings Eastings (ft) (ft) 5125.78 S 5142.15 S 5230.30 S 5318.46 S 5406.61 S 5494.76 S¡ 5582.92 S .~tl 7217.47 5J?2~t()7 S 7218.60 j1?159~ S ~~i;~I~S!! ..= 6111.84 S 6199.99 S 6288.14 S 6376.30 S 6464.45 S 10500.00 89.354 151.835 10600.00 89.354 151.835 10700.00 89.354 151.835 10800.00 89.354 151~~; ;;;;:;t~!, ~;:~;,~~~~ç~. 11200." ,""" . c"S1.a3š' 11300. 151.835 11400.0 151.835 11500.00 89.354 151.835 11600.00 89.354 151.835 11700.00 89.354 151.835 11800.00 89.354 151.835 11900.00 89.354 151.835 12000.00 89.354 151.835 12100.00 89.354 151.835 12200.00 89.354 151.835 12300.00 89.354 151.835 12400.00 89.354 151.835 8 August, 2002 - 11 :47 7176.74 7177.87 7178.99 7180.12 7181.25 7182.38 7183.50 7184.63 7185.76 7186.88 7188.01 7189.14 7190.27 7191.39 7192.52 7228.74 7229.87 7230.99 7232.12 7233.25 7234.38 7235.50 7236.63 7237.76 7238.88 7240.01 7241.14 7242.27 7243.39 7244.52 6552.60 S 6640.76 S 6728.91 S 6817.06 S 6905.22 S 6993.37 S 7081.52 S 7169.68 S 7257.83 S 7345.98 S 7434.14 S 7522.29 S 7610.44 S 7698.60 S 7786.75 S . ,.,.,<;*;:.;.;,=,~ '. ~7:.. . -~-':--: ~ -~- - -:.., .-.' orth Slope, Alaska Alpine CD-2 Global Coordinates .~~/:~g~. "~'Yer\fid~i' Nor::;ngs Ea~:;'\Å(¥;o~~.r~r~~:t~fé.>$eCtiOn Comment 1885.14 E 1893.90 E 2413.09 E 2460.29 E 2507.49 E 2554.68 E 2601.88 E 2649.08 E 2696.28 E 2743.48 E 2790.68 E 2837.88 E 2885.08 E 2932.27 E 2979.47 E 3026.67 E 3073.87 E 3121.07 E 3168.27 E 3215.47 E 3262.66 E 3309.86 E Page 6 of 10 5969256.24 N 5968706.03 N 5968617 .09 N 5968528.14 N 5968439.19 N 5968350.24 N 5968261.30 N 5968172.35 N 5968083.40 N 5967994.45 N 5967905.50 N 5967816.56 N 5967727.61 N 5967638.66 N 5967549.71 N 5967460.76 N 5967371.82 N 5967282.87 N 5967193.92 N 5967104.97 N 5967016.02 N 5966927.08 N 5966838.13 N 5966749.18 N 5966660.23 N 5966571.29 N 72.00 E 373617.68 E 373663.37 E 373709.05 E 373754.73 E 373800.42 E 373846.10 E 373891.79 E 373937.47 E 373983.15 E 374028.84 E 374074.52 E 374120.20 E 374165.89 E 374211.57 E 374257.26 E 374302.94 E 374348.62 E 374394.31 E 374439.99 E 374485.67 E 374531.36 E 374577.04 E 374622.73 E 374668.41 E 374714.09 E 374759.78 E 374805.46 E 374851.14 E 374896.83 E ".. 0.000 5427.16 .000 5408.59 End Dir, Start Sail @ 89.35° : 9381.43ftMD,7210.50ftTVD 0.000 5527.15 0.000 5627.15 0.000 5727.14 0.000 5827.13 0.000 5927.13 0.000 6027.12 0.000 6127.11 0.000 6227.11 0.000 6327.10 0.000 6427.09 0.000 6527.09 0.000 6627.08 0.000 6727.08 0.000 6827.07 0.000 6927.06 0.000 7027.06 0.000 7127.05 0.000 7227.04 0.000 7327.04 0.000 7427.03 0.000 7527.02 0.000 7627.02 0.000 7727.01 0.000 7827.01 0.000 7927.00 0.000 8026.99 0.000 8126.99 0.000 8226.98 0.000 8326.97 0.000 8426.97 ~ --' Dril/Quest 2.00.09.006 a ~ =." Sperry-Sun Drilling Services Proposal Report for Plan: C02-38 - C02-38 (wp02) Revised: 7 August, 2002 Colville River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 12500.00 89.354 151.835 7193.65 7245.65 7874.90 S 12600.00 89.354 151.835 7194.77 7246.77 7963.06 S 12700.00 89.354 151.835 7195.90 7247.90 8051.21 S 12800.00 89.354 151.835 7197.03 7249.03 8139.36 S 12900.00 89.354 151.835 7198.16 7250.16 8227.52 S 13000.00 89.354 151.835 7199.28 7251.28 8315.67 S 13063.63 89.354 151.835 7200.00 7252.00 8371.76 Global Coordinates Northings Easti (ft) 5966482.34 N 5966393.39 N 5966 N N N All data is in Feet (US) unless otherwise stated. Directi Vertical depths are relative to RKB = 52' MSL. are relative to True North. stings are relative to 1944' FNL, 1517' FEL. The Dogleg Severity is in Degrees per Vertical Section is from 1944' F.N~,~ ulated along an Azimuth of 151.830° (True). Based upon Minimum CUIV~~:'~pe ~uiåtons. at a Measured Depth of 13063.63ft., The Bottom Ie Di~e~ is"9122:13ft . in the Direction of 156.598° (True). 8 August, 2002 - 11 :47 Page 70t10 375170.93 E 375200.00 E f!!$.flj;~, '. ;~:c:~~~.\~eitic£âl <~\ ~e":~ß~;;.~Section '~Sc}~~~~ft) .000 8526.96 .000 8626.95 0.000 8726.95 0.000 8826.94 0.000 8926.94 0.000 9026.93 0.000 9090.56 orth Slope, Alaska Alpine CD-2 Comment _.J TARGET (Toe) Total Depth: 13063.63ft MD, 7252.00ftTVD (24: FSL & 2098' FWL, See 12-T11N- R4E) 6-118" Open Hole Target- CD2-38 (Toe), Current Target ~ OrillQuest 2.00.09.006 C) '"",", /SHl (1944' FNL & 1517' FEl, Sec. 2-T11 N-R4E) 0 ------ - ,'~>..3;\~t~1 m Phillips Alaska, Inc. Colville River Unit CD2 Pad CD2-38 (wp02) ~egin Oil' @ 2.0"/10011 (in 12-1/4" Hole) : 400.00ft MD, 400.00ft TVD '\-s>'" .. -Increase n Dlr Rate @ 3.0'I100ft: 000.000 MD. 897.47ft TVD I 1200 - j;[''f¡¡~J4¡{--J5''P ----_. - .----- ..- -._-- - ---- ~ -.-. - ---- - _. - - - I -~!:!!!!!.(l'!fL- IM1JJ:ttf1}) -- ~ - ---- -. -.- --- - - - - - -- - --- I \ -w-~. :::J en ~ N It) II en ~ fE. ~,'-,',':I}",.......K,--'" '~-U",,~..\ A-,:', ,,"',:' I!!!!I,' ",',,',',-',-,', ..,"" ,:::--i"l~ ~ . '... ".'''~~:-fl-! §ffJ:-:~klÑ)J"":~:..i~J!.~lIï;f!J¡ A HA.U~ft~ eom~!i End Dir. Start Sail @ 39.95°: 1914.7Oft MD, 1807.57ft TVD Reference is True North Current Well Properties 9-518" Csg PI... Drill out 8-1/2" Hole: 2674.41ft MD, 2390.00ft TVD IT;,.II -'l.1.0].lfirJ V ~---- 2400 -TiíŒTij't j'~-'-w;:'é-;¡P¡:--- I 2674.4/1 MD -j'}ï;rJÎ: ~+q--~:~~~~w_---- -.....-r ~- ._-----~--~--------- ---------------- Well: Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure: Ref. Geographical Coordinates : 5974413.52 N, 371720.66 E 29.33 S, 3.67 E 70Q 20' 17.9855" N, 15P 02' 27.2557" W 1944' FNl & 1517' FEl. Sec. 2- T11 N-R4E 52.000 above Mean Sea level True North Feet (US) Plan: CD2-38 ~~ ~- ~ ----- -- -- ~-- -- ~ ---~ --.... RKB Elevation: North Reference : Units: 3600 - I ¡t;;~;.~~-=~-= . -~- . I Approved Plan (1M 2) --. - ---------- - -~~ - ...-....-~ ...- -- -~~ J:: Õ. Q) c ro 0 "" Q; > "'- -~ --- --- - ~-....-- -- -- - -~ -... ~-----~-- ~ ......-...-- ~ -- -- I f?-D.~ I tffi~.:~~'Y 'l: ~'\ '\~...¡\) W'¡an n tö'ò¡¡Jl.. ~c''\rJ:;';J''j.' ~\) 'T--'------------------56ñJìiiTm .------..--- tJ.\)' ~". '1'{' !;)~ I f:fòC)..-p. 1)..6 0.<&-,-",,,,,-0. 1?-,\of:J . ,A,'ú,'ún -"^,' ~..'òfi;), '(¡~" 'b- '?,'?:.<:J>- ~ ~'Y' , 0'" o\,\\;)(J ~{J,'\ .~'I..'. ~ ¡---'--------"'----------'----'-----6iiS2.flft nv--------- - '-::r-- - --- 'õ~ . ..";',\,\fJ. ~'b'ò'\ ~ ¡.,~ @ . y'°'@ ''!<> (f¡':S 'b'fJ . I è~~ ~fô,-'\\'ò..<:>\y,=. @<!J¡' ~ \)~'~i\~P''$ ~'#~ '-----" T-"----'-~--"----'-----'----~---'--~- PJqo.....~-<;\.y.._ø -ç)of.'<Õ'Ø (jff47J(fl jTf) - , - - . Cf5 ':f.f2!C- . ~ø 7200 _:;::~:t~E1;~~~?:j,~mÍc~=¥~~;.;tC~--~.:~::~;=:C~~-_. --=-= 'i#W .,/ ~c:.:~' '. CD2.J8 (Heelj 7208.00 TVD 72(}8.M lTD. 5056.64 S. 1848,l1li' ~ 4800 - 6000 - :::-;;..0 'í/ð't<t~..J.\) ,-,;\ \. '\ 'f' -~ ç:~~~?~~~:Bec'\Y '0(?s:- _.,,~' ')IJ~ .'\ ~~ê~~~9... ~ '.~^r:s ~ \ CD1.38 (J'oei '!- 7251.1'1(1 Tvri > / 8371. 76 5.,3623.09 E . ,#, \, ~ II -fi S ~<>'" .'~ ,#'" e' ji ~ 0 1200 2400 3600 4800 6000 7200 8400 Scale: 1 inch = 120011 ~ ;:::'--t ~ ",~f $ DrillQuest 2.00.09.006 -1200 I 0 -- - ---- "- 9-518" Csg PI. 2674.411 MD 2390.00 TVD -1200 - -2400 - -3800 - (/) g> ;6 0 Z -4S00 - -6000 - -7200 - ~ 0 ~ II 13 -8400- c :;: ~ t'J (/) I -1200 Scale: 1 inch = 1200ft OrillQuest 2.00.09.006 ) Phillips Alaska, Inc. Colville River Unit CD2 Pad CD2-38 (wp02) 0 ! 3600 I End Oil', Start Sail @ 39.95": 1914.701t MD, 1807.57ft TVO 9-518" Csg PI ... Drill out 8-1/2" Hole: 2674.41ft MD, 2390.OOIt TVD 5p&tI'''Y-~1I1 tr~:fc~~~'rr.U~_M'-!i~~"~~'V'~~-"~ ,...~--,_. ..,~,c.~.!!"'.iiII'~">,~",-,,,"5\_C,,"..,1im.Ii!.;,,,~ .A ti¡;¡lm~ît;ml C:Oim.ît1!11' 4800 I 6000 I Scale: 1 inch = 1200ft Reference is True North Current Well Properties 1200 2400 I I SHL (1944' FNl & 1517' FEl, Sec. 2-T11N-R4E) _.__~in~@2.~/100ft~::-1/4"HoIe)~400.00lt~.~~ft.:v~ - --- - ---- -- -- - -- -- 0 Increase in Dir Rate @ 3.0"/1OO1t : 900.00ft MD, 897.47ft TVO Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structu re : Ref. Geographical Coord nates : RKB Elevation : North Reference: Un its : Plan: CD2-38 5974413.52 N, 371720.66 E 29.33 S, 3.67 E 70° 2C1 17.9855" N, 151" 02' 27.2557" W 1944' FNL & 1517' FEL, Sec. 2-T11N-R4E 52.00ft above Mean Sea Level Tru e North Feet (US) Approved Plan (wp02) Begin Oil' @ 6.0o/1ooft : 8508.02ft MO, 6862.28ft TVD 7" Csg Pt... Drill out 6-1/8" Hole: (1721' FNl & 326' FWl, Sec. 12-T11N-R4E) TARGET (H€.el) 8egb Dìr @ 3.0"/10011: 9302.06ft MD. 720ROOfI TVD End Dir. Start Sail @ 89.35": 9381.43ft MD, 7210.5Oft TVD CV2.J8 (fleet) / 72()8JHJ TVD, 505fi.64 $, 1848.12 E i 0 I 2400 I 3600 I 1200 Eastings ,,/ / / /// CD2-38 ({'Ie I 7.!52.(}() rVD. Sin 7ó S, 36:!3.1J9 E I 4800 I 6000 0 - -1200 - -2400 - -3600 §> :.ë t: 0 Z - -4800 - -6000 - -7200 8 c-J " - -8400 -g :;: iÐ "8 (J) r¡ ) Sperry-SuD Anticollision Report ) Company: Phillip:; Alæka Inc. Field: Colville River Unit Reference Site: Alpine CD2 Reference Well: Plan: C02,.38 Reference Wellpatb: CD2~38 GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MO Interval: 50.000 ft Depth Range: 36.100 to 13064.217 ft Maximum Radius: 1503.052 ft ~te: 8/8/2002 Time: 15:34:25 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan: CD2-38. TrueNorth CD2~38 @ 52' AKB 52.0 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Cæing Survey Program for Definitive Well path Date: 7/24/2002 Validated: No Version: 2 Planned From To Survey Toolcode Tool Name ft ft 36.100 1300.000 Planned: C02-38 (wp02) V1 CB-GYRO-SS Camera bæed gyro single shot 1300.000 13066.620 Planned: C02-38 (wp02) V1 MWO MW 0 - Standard Casing Points 1\'ID TVD Diameter Hole Size NaD1e ft ft in in 2674.449 2390.000 9.625 12.250 95/8" 9303.240 7207.974 7.000 8.500 7" 13064.200 7252.248 4.500 6.125 4-1/2" SW11D1ary " " Reference Ctr-ctr. No-Go ¡ <--.-..-----....-- ()ffset Well path --;.-.-.----------> Offset Allowable Sit~ Well Well path MD MD Distance Area Deviation Warning ft ft tt ft ft Alpine CO2 C02-14 C02-14 V1 446.566 450.000 239.676 7.393 232.283 Pæs: Major Risk Alpine CO2 C02-15 C02-15 V1 399.992 400.000 230.075 No Offset Errors Alpine CO2 C02-15 C02-15PB1 V1 399.992 400.000 230.075 7.795 222.280 Pass: Major Risk Alpine CO2 C02-15 C02-15PB2 V2 399.992 400.000 230.075 7.795 222.280 Pæs: Major Risk Alpine CO2 C02-17 C02-17 VO 446.951 450.000 210.857 7.742 203.116 Pæs: Major Risk Alpine CO2 C 02-19 C02-19 V6 494.437 500.000 186.852 8.267 178.612 Pæs: Major Risk Alpine CO2 CD2-20 C02-20 VO 36.100 32.000 179.645 No Offset Stations Alpine CO2 C02.22 C02-22 V1 495.341 500.000 158.695 8.015 150.693 Pæs: Major Risk Alpine CO2 C02-24 C02-24 VO 447.906 450.000 139.786 7.693 132.096 Pæs: Major Risk Alpine CO2 C02-24 C02-24PB1 V1 447.906 450.000 139.786 7.693 132.096 Pass: Major Risk Alpine CO2 CD2-25 CD2-25 V1 448.055 450.000 129.877 7.747 122.131 Pass: Major Risk Alpine CO2 C02-26 C02-26 V4 249.995 250.000 119.653 4.522 115.133 Pass: Major Risk Alpine CO2 CD2-26 C02-26PB1 V2 496.262 500.000 112.313 8.268 104.070 Pass: Major Risk Alpine CD2 CD2-26 C02-26PB2 V2 486.691 490.100 111 .580 No Offset Errors Alpine CO2 CD2-32 C02-32 PB1 VO 449.089 450.000 59.663 7.748 51.915 Pass: Major Risk Alpine CO2 C02-32 C02-32 VO 449.089 450.000 59.663 7.748 51.915 Pass: Major Risk Alpine CO2 C02-33 C02-33 V2 498.431 500.000 49.545 8.006 41.560 Pass: Major Risk Alpine CO2 C02-33 C02-33A V1 498.431 500.000 49.545 8.006 41 .560 Pass: Major Risk Alpine CO2 CD2-33 C02-34B V1 498.431 500.000 49.545 8.006 41.560 Pass: Major Risk Alpine CO2 C02-34 C02-34 V3 249.967 250.000 41.082 5.137 35.946 Pæs: Major Risk Alpine CO2 C02-34 C02-34PB1 V2 249.967 250.000 41.082 5.137 35.946 Pass: Major Risk Alpine CD2 C02-35 C02-35 VO 499.123 500.000 27.866 8.269 19.613 Pass: Major Risk Alpine CO2 C02-39 C02-39 V1 249.989 250.000 11.361 4.355 7.007 Pass: Major Risk Alpine CO2 C02-39 C02-39PB1 VO 249.989 250.000 11.361 4.355 7.007 Pass: Major Risk Alpine CO2 C02-41 C02-41 V8 802.035 800.000 16.887 11.480 5.574 Pass: Major Risk Alpine CO2 C 02-42 C02-42 VO 852.218 850.000 29.329 11 .913 17.453 Pass: Major Risk Alpine CO2 C D2-42 C02-42PB1 VO 852.218 850.000 29.329 11.913 17.453 Pass: Major Risk Alpine CO2 C02-45 C02-45 V1 349.965 350.000 69.592 6.088 63.505 Pass: Major Risk Alpine CO2 C02-46 C02-46 V2 1106.514 1100.000 44.042 15.190 28.859 Pass: Major Risk Alpine CO2 C02-47 C02-47 V2 349.955 350.000 91.449 6.135 85.315 Pass: Major Risk Alpine CO2 C02-48 C02-48 V1 1211.908 1200.000 27.799 17.974 9.866 Pass: Major Risk Alpine CO2 C02-49 C02-49 V1 1159.839 1150.000 102.514 16.679 86.224 Pass: Major Risk Alpine CO2 CO2-50 CO2-50 V2 1166.560 1150.000 112.864 17.436 95.501 Pass: Major Risk Alpine CO2 CD2-50 C02-50PB1 V2 1166.560 1150.000 112.864 17.436 95.501 Pass: Major Risk Alpine CO2 Plan: CD2-28 Plan: CD2-28 PB1 V1 PI 349.954 350.000 100.787 7.221 93.567 Pass: Major Risk Alpine CO2 Plan: CD2-28 Plan: C02-28 VO Plan: 349.954 350.000 100.787 7.112 93.676 Pass: Major Risk Alpine CO2 Plan: C02-16 Plan: C02-16 V4 Plan: 399.931 400.000 220.260 8.017 212.243 Pass: Major Risk Alpine CO2 Plan: C02-23 Plan: C02-23 V1 299.963 300.000 151.065 5.854 145.211 Pass: Major Risk Alpine CO2 Plan: C02-23 Plan: C02-23PB1 V10 299.963 300.000 151.065 5.963 145.102 Pass: Major Risk Alpine CO2 Plan: C02-29 C02-29 V3 Plan: C02-29 448.641 450.000 90.247 8.988 81.259 Pass: Major Risk Alpine CO2 Plan: C02-31 Plan: C02-31 PB1 VO PI 399.957 400.000 70.414 7.413 63.001 Pass: Major Risk Alpine CO2 Plan: C02-37 Plan: CD2-37 PB1 V2 PI 299.968 300.000 10.168 6.122 4.046 Pass: Major Risk Or;:" rl¡ f t~'J,):; ) (~ompllny: Phitlip$ Alaska Inc. Field: . Colville River Unit . Rëference Site: Alpine CO2 Reference Well: Plan: CD2-38 Reference Wcllpatb: CD2-38 Summary <..~.-':"------_.' Offset \\'ellpath . --"'------------->' . Site Well WeUpath Alpine CD2 Alpine CD2 Alpine CD2 Plan: CD2-37 Plan: CD2-43 Plan: CD2-44 Sperry-Sun Anticollision Report Plan: CD2-37 VO Plan: Plan: CD2-43 PB1 VO Plan: CD2-44 V3 Plan: ~te: 81812002 Ti,ttJe: 15:34:25 Page: 2. (;o-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan: CD2-38. True North- CD2,38 @ 52' AKB 52.0 Db: Oracle ~eference Offset Ctr-Clr No-Go Allowable MD Mt> Distance Area Dedation ' Warning ft ft ft ft ft 299.968 300.000 10.168 6.013 4.155 Pass: Major Risk 36.100 36.100 50.243 No Offset Stations 1055.316 1050.000 35.364 18.357 17.188 Pass: Major Risk WI'LLDETAIL~ NillJ< ,.N/.S +FJ-W NonhÍ1g [",ling r..<tiftKle IongilU<k Sk>t Plan; CIYl.38 .Z1.7.ïŒ1 28.3:!.J SlJ14413.52 371'120.66 70'2O'17.986N 151,,(r.2'Zì.256W NiA A!"ITI-COLLISION SETIJNGS Interpolation Method:MD Interval: 50.000 Depth Range Froro: 36.100 To: 13064.2lì Maxirown Range: 1503.052 Reference: Plan: CD2-38 (wp02) C>kuI.;tiœ àfelbcd: Mininum Cmv.ture ==; ~~~~t>derNarth w.::=~ ~c~;.J.$ing 0.000 From Colour 0 ~'il u} JI h) '.1 II) "'III) 111'llj -ISO OCDZ.-Z6 (lXJ:l~~' ._~. ~~~\1- WA 'f'''T\'- ~).\).. .111) - - rl..A\\.C~v 11111') =- . _<.9 .I''',') ---=: "1111\)- ~, 1111) ;llIiI) :.IIIII} IIIIIIJI) I:' (,) J'IIU) 1111) -HX> --50 -0 -50 ;::;. I & -11 & Iso ~ "I.. -184 CD2-38 (wp02) Approved Plan --- --- Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] COMPA1<'YDErAILS P~~~grm-. Klt>uuk WELlPATHDBTAILS CP2.38 Rig: Do}Ðn 19 Ref Da1um: CD'l-38@5ZRKD 52.(O:;Jt v.s~: ~ +~ ~D l5l.8S. 0.((1) OJ)),) ToMD 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 10000 12000 14000 16000 18000 1', "[,1 Colour 1.. \ID I) ~".} - JIIII Jill) ---- f.I'11 t..II)-.Io:!lli ,,,") 111111)-1'(111 I "-III) -'III JII -'~ il h) :' III 11!lli, ..~ III' :"OI.'I)-"III!ll .,11 II) """'""'-<;"'''''''".-.. ..1,1,_11 I JIIIIt)- ,'11111 '11111)-;"11111 1.11111) ~'I,,'I) - .;"01.1~1! ~IIII) 1"11111) l..:'lil!l) .JIll II) -36 '-' ".Iilll, -30 -20 .,,", ~ Sj. ¡ ~<£PB1) -10 -20 ~30 -36 S~ MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 36.100 0.00 0.00 36.100 0.000 0.000 0.00 0.00 0.000 2 400.000 0.00 0.00 400.000 0.000 0.000 0.00 0.00 0.000 3 900.000 10.00 145.00 897.465 -35.652 24.%4 2.00 145.00 43.212 4 1914.795 39.95 161.03 1807.645 -425.153 185.178 3.00 20.49 462.227 5 8508.354 39.95 161.03 6862.322 -4429.129 1561.201 0.00 0.00 4641.777 6 9303.240 87.00 151.83 7208.000 -5057.047 1848.288 6.00 -12.47 5330.865 CD2-38 (Heel) 7 9381.715 89.35 151.83 7210.4% -5126.188 1885.310 3.00 0.11 5409.294 8 13064.217 89.35 151.83 7252.000 -8372.429 3623.418 0.00 0.00 9091.562 CD2-38 (Toe) Travelling Cylinder Azimuth (1FO+AZI) [deg] vs C.:entre to Centre Separation [20ft/in] ) ') 8P1.WiPS. . . '~..'.i...............i.............'.. SIiI. Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 13, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-38 Dear Sir or Madam: / Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore WAG (water alternating gas) injection well from the Alpine CD2 drilling pad. The intended spud date for this well is September 10, 2002. It is intended that Doyon Rig 19 be used to drill the well. ./ CD2-38 will be drilled to penetrate the Alpine reseNoir at horizontal. After setting 711 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 work and facilities work that will allow the well to begin injection. / Note that it is planned to dril,l the surface hole without a diverter. There have been 38 wells drilled on CD1 pad and 22 surface holes drilled on CD2 pad with no significant indication of gas or shallow gas hydrates. 22 wells on CD2 have surface casing shoes within a 2000' radius of the planned surface casing shoe of CD2-38. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: . Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). . Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). . A proposed drilling program, including a request for approval of annular pumping operations. . A drilling fluids program summary. . Proposed completion diagram. . Pressure information as required by 20 ACC 25.035 (d)(2). . CD2-38 Cementing Requirements. 1. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. ) If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~:w/<--- . Vern Johnson Drilling Engineer Attachments cc: CD2-38 Well File / Sharon Allsup Drake A TO 1530 Chip Alvord A TO 868 Cliff Crabtree A TO 848 Meg Kremer A TO 844 Nancy Lambert Lanston Chin Anadarko - Houston Kuukpik Corporation e-mail : Tommy_Thompson @ anadarko.com ~ = 1 ~ ~W.:." ~::t ,J ¡' '.:.1:1 ~~::t.. :I.:.1.~::t:'" .I~:- ~ ~8}..:.ttltj::t.. "!' II ~ = r81I.11.~ r8} ~1~[~W.:....::t :11'1'.:.1:J ~a: [8]..1 (,..ref = 11111 (8.a'~::t :11 'å~4W.:." .::t:J 1''.:.1:1 ~ AEVEST BANK : ~r ",:' :',:,::: \", :' 1,1,:" ,'JII~::;~ I, ,,:'i~\(I:,:: ::,:'1" \ :,:,.";i\'Y::' "\;\1"",;,::,\,.',,, ),~'I~'\: "":1:": ' ., ',I,('~~'" ",I::,'" ' \ : ;' , ,I' ':'., "'. P.' hl.l."¡'PP~'."!':A.1!:'~ßij:~',,.,.;¡.'..n., ,C. . " ' AnQ~ora:aø '\';I'AK" 9'~61 ø "ii,' ,I~~" ~~:',,'..,, "1,'",,1' I: ',\"'ll,1 J1474: ':::, .::,:,:,;:1,.:, '.: "".".;" 1\::i:,I.,,;,.;,:,:,:, ,¡;\:':,' /,,\il" ',:,','.: ':r:":I?,.I'~"'~ ~i)i';r;:? :;:It;:::( 'i:::?!',"':' ''':';,I':,,';:,¡ ,I, ,1'1,',. Q7 / 15A200,2q,O,ø.O~,~:""" .'i :"1 '\il"\",\',,JO\q\\~QØ,~il'" 110, "\'"""::,,\;;: ", ',' I . I :,'"',1\:,,.' "'\',\::: ' ,,,:'.\ ", I' ,<' \~'~',:\:'. ',1""" \;.:'.,'" 1',\;,:\ 'I'I!!' '\\\:ì\:,' ';'1;1'\\1 '(:::,;\\,\\~;, ,'-'\\\:V::I,:". ,',''\ ",1'\1' , r. A¥ :æo:: THE ORDER OF , ::1,',\: I:, . , ;-.,EX;Aÿ-':ÇL¥i, ":.1/"(:,\,;,,1(;' ~!~"if:1ØØ 'ITS ';Do¡b::~.:rS~""a.nÖ" ,øø "eerø~;s"¡"i!!i:i:lt ,:,:',:,'\'\': ,!'," !, ,:,':', ,,:,,:;\::,',' ~I::':';"'\" '';,\;,:,,':\;:': I' ,\,':t\::",:i;~,'\Y\' STATE Of,ALASKA',,/,";.AÇåcc ,..,'.::11",::"" ,), 3~.~ ~'.L' 7'l'H ..AVENtJ:E ;SUIT,~:'.1ØØ, ANCHORAGE, AK996Øl ,,',' n."'::"i' ,"", ~'A'). i;}~ fØI ~1, ~;"iv:¿~/ 'i 'ij:j~~~¿~ "':;~,ii III 0 0 00 0 0 5 0 III I: ~ 0 3 ~ 00 8 2 31: 00 5 ~ 5 2 0 III -, -,- ) ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME~~U C02.-3? PTD# 202..-/7 J CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE "CLUE" The permit is for a new well bore segment of existing well Permit No, API No. Production should continue to be reported as a function. of the original API number stated above. In accordance with 20 AAC 25.005(f), 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 (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full. compliance with 20 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 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 07/10/02 C\j ody\templates ". r 0 h <;-. r- or e-ø /A.J2ß... tz..l ~.~ a.r I to It <. '. ~ .~/¿oIO L L« to 'L ~t~ I~ sc1Æc1.,,-l-e \ Wr; ¡4- i/2A 10 1 . (){l Ct)2- ~f fAr'~ J-n'/Ù"f. "WELL PERMIT CHECKLIST COMPANY Ih / / J /¡ J WELL NAMECluGlJ Ã'" .$ ~ PROGRAM: Exp - Dev - Redrll - Re-Enter - Serv -A- Wellbore seg - FIELD & POOL 12 ð 100 INIT CLASS 1- td.bJ' ¡ ,IlJ GEOL AREA ðÞ<7 (j UNIT# 0 S rJ.~1? 0 ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . P N " 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N PO/" 01.- J. ") 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N D.J..-J..-- '§ll::t'tÇ><-. 9. Operator only affected party.. . . . . . . . . . . . . .". . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . W N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #-L!lA ø N ~t7 'l - I tv ~v ,- I (Pr.? to 1- " I (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. (!) N CIJ 2-'-111 ClJ.2.. J 7 C/)2. -]7' ,ENGINEERING 15. Conductor s~ring provided. . . . . . . . . . . . . . . . . . . â)N /(¡,u (i) IIi./- '. I 16. Surface casing protects all known USDWs. . . . . . . . . . . éJ;? N A j ct!: 17. CMT vol adequate to circulate on conductor & surf csg. . . . . ~l N ~'1 . e,.¿ CRte" ç . 18. CMT vol adequate to tie-in long string to surf csg. . . j@h-l)lQ...eý'l..tr" 19. CMT will cover all known productive horizons. . . . . . . . . . . M' rJ ~ t<.'w<f1 ¿, ........ 20. Casing designs adequate for C: T, B & permafrost. . . . . . . ; N [) ,c. 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . .. N D-</{ ~ -,. 22. If a re-drill, has a 10-403 for abandonment been approved. . . '-y:"'--t:t"'N'Ik 23. Adequate wellbore separation proposed.. . . . . . . . . . . . (:;¡) N 24. If diverter required, does it meet regulations. . . . . . . . . . v.1"-'L1/ ~ý V Rj I.U'$ re..ó . 25. Drilling fluid program schematic & equip list adequate. . . . . N IYl Cl¥. rn J,..j. q I ~ y:Jp l' 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N " r ,/JA I.,. f- ¡. APPR DATE 27. BOPEpressratingappropriate;testto f:'G'ìOO psig. N tn~P l55~ fIt. ,'tAll tA.7 .te~ 3500 f!i. I I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . Y. N ltiGA- -i 2. OL 29. Work will occur without operation shutdown. . . . . . . . . . . I ti-,. 30. Is presence ofHzS gas probable.. . . . . . . . . . . . . . . . ~ 31. Mechanical condition of wells within AOR verified. . . . . . . . N 32. Permit can be issued w/o hydrogen sulfide measures. . . . . rYN 33. Da~a ~resented. on potential overpressure zones. . . . . . . . 7 A) ...LJ 34. Seismic analysIs of shallow gas zones. . . . . . . . . . . . . Y ptv. /, . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . N 36. Contact name/phone for weekly progress reports. . . . . . . . Y N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER RP~ TEM JDH JIf:- JBR APPR DATE (Service Well Only) GEOLOGY APPR DATE A?: ~/¡~~ (Exploratory Only) Rev: 07/12/02 COMMISSIONER: COT DTS Og/~(O<- Comments/lnstructions: SFD- WGA \tJ GA- MJW G:\geology\permits\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically organize this category of information. lit. Sperry-Sun Dri ,)ng Services LIS Scan Utility ) ~Od -I"I J \ '(p1 q $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 02 15:16:41 2003 Reel Header Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/06/02 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. . . . . . . . . . . . . . . . . . . . . 03/06/02 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 CD2-38 501032042900 Phillips Alaska, Inc. Sperry Sun 15-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW2214300000 M. HANIK D. BURLEY MWD RUN 4 MW2214300000 M. HANIK D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 11N 4E 1994 1517 MSL 0) .00 52.50 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 2649.0 6.125 7.000 9208.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. ) ') 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 100 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 200 MADE NO FOOTAGE AND IS NOT PRESENTED. 5. MWD RUNS 300 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS,ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) AND PRESSURE WHILE DRILLING (PWD). 6. MWD RUN 400 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS,ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD) AND AT BIT INCLINATION (ABI). 7. GAMMA RAY ON MWD RUN 400 HAS BEEN CORRECTED FOR KCL MUD. 8. MWD IS CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 9/26/01. ALL MWD LOG HEADER DATA RETAIN ORIGINAL DRILLERS DEPTH REFERENCE. 9. MWD RUNS 100 - 400 REPRESENT WELL CD2-38 WITH API #50-103-20429-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13,010 MD, 7312 TVD. SROP = SGRC = SEXP = SESP = SEMP = SEDP = SFXE = $ SMOOTHED SMOOTHED SMOOTHED SMOOTHED SMOOTHED SMOOTHED SMOOTHED RATE OF PENETRATION WHILE DRILLING. GAMMA RAY COMBINED. PHASE SHIFT DERIVED RESISTIVITY PHASE SHIFT DERIVED RESISTIVITY PHASE SHIFT DERIVED RESISITIVTY PHASE SHIFT DERIVED RESISTIVITY FORMATION EXPOSURE TIME (EXTRA SHALLOW SPACING) . (SHALLOW SPACING) . (MEDIUM SPACING) . (DEEP SPACING) . File Header Service name........... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPM RPX RPD RPS FET ROP $ 1 clipped curveSj all bit runs merged. .5000 START DEPTH 2625.0 2639.0 2639.0 2639.0 2639.0 2659.5 2660.5 STOP DEPTH 12949.5 12957.0 12957.0 12957.0 12957.0 12957.0 13009.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- ) BASELINE DEPTH $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 3 2625.0 4 9162.5 MERGE BASE 9218.0 13009.5 # 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 FPH 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 2625 13009.5 7817.25 20770 2625 13009.5 ROP MWD FPH 0.7 555.51 138.939 20699 2660.5 13009.5 GR MWD API 28.5 374.56 90.9268 20650 2625 12949.5 RPX MWD OHMM 0.28 1330.08 8.47221 20550 2639 12957 RPS MWD OHMM 0.33 1471.06 9.32929 20550 2639 12957 RPM MWD OHMM 0.11 2000 10.7391 20550 2639 12957 RPD MWD OHMM 0.58 2000 14.087 20550 2639 12957 FET MWD HOUR 0.3 59.13 1.04636 20509 2659.5 12957 First Reading For Entire File......... .2625 Last Reading For Entire File. ......... .13009.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation. ..... .03/06/02 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...... .03/06/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 2 header data for each bit run in separate files. 3 .5000 START DEPTH 2625.0 2639.0 2639.0 2639.0 2639.0 2659.5 2660.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9162.0 9154.0 9154.0 9154.0 9154.0 9154.0 9218.0 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: 01-SEP-02 Insite 66.37 M~mory 36.6 73.2 TOOL NUMBER 136692 134758 8.500 2649.0 LSND 9.70 41.0 8.8 450 5.8 1.850 .958 1.800 2.200 72.0 145.4 72.0 72.0 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 Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 2625 9218 5921.5 13187 2625 9218 ROP MWD030 FT/H 0.7 555.51 162.462 13111 2660.5 9218 GR MWD030 API 35.62 374.56 112.59 13075 2625 9162 RPX MWD030 OHMM 0.29 29.03 4.90552 13031 2639 9154 RPS MWD030 OHMM 0.4 26.6 5.00145 13031 2639 9154 RPM MWD030 OHMM 0.11 2000 5.79959 13031 2639 9154 RPD MWD030 OHMM 0.58 2000 9.70756 13031 2639 9154 FET MWD030 HOUR 0.3 47.28 0.927376 12990 2659.5 9154 First Reading For Entire File......... .2625 Last Reading For Entire File......... ..9218 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 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...... .03/06/02 Maximum Physical Record. .65535 File Type................ ~) 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 GR RPS RPD RPM RPX FET ROP $ 3 ) header data for each bit run in separate files. 4 .5000 START DEPTH 9162.5 9198.0 9198.0 9198.0 9198.0 9198.0 9218.5 STOP DEPTH 12949.5 12957.0 12957.0 12957.0 12957.0 12957.0 13009.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO 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: 06-SEP-02 Insite 6.02 Memory 82.5 90.5 TOOL NUMBER 91360 162742 6.125 9208.0 FIo Pro 9.00 50.0 8.6 22000 4.2 .090 .043 .160 .140 69.0 152.0 69.0 69.0 $ ) ) # 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9162.5 13009.5 11086 7695 9162.5 13009.5 ROP MWD040 FT/H 0.85 326.52 98.4151 7577 9218.5 13009.5 GR MWD040 API 28.5 115.5 53.5342 7575 9162.5 12949.5 RPX MWD040 OHMM 0.28 1330.08 14.6535 7519 9198 12957 RPS MWD040 OHMM 0.33 1471.06 16.8298 7519 9198 12957 RPM MWD040 OHMM 0.18 2000 19.2997 7519 9198 12957 RPD MWD040 OHMM 3.43 1950.91 21.677 7519 9198 12957 FET MWD040 HOUR 0.39 59.13 1.25192 7519 9198 12957 First Reading For Entire File...... ;.. .9162.5 Last Reading For Entire File.......... .13009.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/06/02 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. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................, )NOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. ') Scientific Technical Services