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Home My WebLink About201-159ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 CD2-15 50103203860000 2011590 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com New Plugback Esets 7/31/2024 Well Name API Number PTD Number ESet Number Date CD2-15 PB1 50-103-20386-70-00 201-159 T39326 4-26-2002 CD2-15 PB2 50-103-20386-71-00 201-159 T39327 4-26-2002 1D-42L1 PB1 50-029-22979-70-00 205-078 T39328 8-3-2005 2N-304 PB1 50-103-20382-70-00 201-130 T39329 9-12-2001 Mitre 1 PB1 50-103-20409-70-00 202-026 T39330 7-23-2002 C-26L1 PB1 50-029-22634-70-00 203-076 T39331 9-17-2003 C-26L1 PB2 50-029-22634-71-00 203-076 T39332 9-17-2003 C-26L1 PB3 50-029-22634-72-00 203-076 T39333 9-17-2003 MPU E-32 PB1 50-029-23261-70-00 205-065 T39334 7-7-2005 S-04L1 PB1 50-029-23148-70-00 203-053 T39335 7-14-2005 S-04L1 PB2 50-029-23148-71-00 203-053 T39336 7-14-2005 MPU S-05 PB1 50-029-23100-70-00 202-137 T39337 6-2-2003 B-03 PB1 50-883-20095-70-00 198-059 T39338 11-6-2003 07-28B PB1 50-029-21770-70-00 209-037 T39339 6-29-2009 16-23A PB1 50-029-22050-70-00 201-054 T39340 6-2-2003 W-34A PB1 50-029-21867-70-00 203-058 T39341 2-6-2004 SP30-W01 PB1 50-629-23476-70-00 212-142 T39342 11-14-2012 V-207L4 PB1 50-029-23390-71-00 208-070 T39343 9-11-2008 W-215 PB1 50-029-23172-70-00 203-131 T39344 9-12-2003 CD2-15 PB1 50-103-20386-70-00 201-159 T39326 4-26-2002 CD2-15 PB2 50-103-20386-71-00 201-159 T39327 4-26-2002 T R A N S M I T T A LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – CRU DATE: 12/19/2023 Transmitted: North Slope, Colville River Unit Colville CD1-01A 50-103-20299-01 212099_CD1-01A_PERF_23Jul22 212099_CD1-01A_WFL_23May2022 CD1-04 50-103-20346-00 200117_CD1-04_PLUG_27Aug2022 CD1-33 50-103-20357-00 222105_CD1-33_Puncher_21Sep2022 CD1-48A 50-103-20592-01 212004_CD1-48A_LDL_28Jul2022 CD2-02 50-103-20513-00 205109_CD2-02_LDL_11Oct2022 205109_CD2-02_LDL_12Jul2022 205109_CD2-02_Patch_07Nov2022 205109_CD2-02_PLUG_23Aug2022 CD2-15 50-103-20386-00 201159_CD2-15_LDL_06Oct23 CD2-310 50-103-20826-00 220028_CD2-310_DHSIT_10Aug2022 220028_CD2-310_USIT_25Apr2022 CD2-404 50-103-20530-00 206054_CD2-404_Patch_30Dec2021 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38291 T38292 T38293 T38294 T38295 T39296 T38297 T38734 200-212 CD2-15 50-103-20386-00 201159_CD2-15_LDL_06Oct23 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:54:09 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-09-28_21169_CRU_CD2-15_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21169 CRU CD2-15 50-103-20386-00 Caliper Survey w/ Log Data 28-Sep-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 201-159 T38024 10/3/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.03 10:42:34 -08'00' 5HJJ-DPHV%2*& )URP6PLWK7UDYLV77UDYLV76PLWK#FRQRFRSKLOOLSVFRP! 6HQW7XHVGD\-XQH30 7R5HJJ-DPHV%2*&:DOODFH&KULV'2*&%URRNV3KRHEH/2*&'2$$2*&&3UXGKRH%D\ 6XEMHFW&58)RUPV $WWDFKPHQWV0,7&58&' 6,7(676[OV[0,7&58&'3$'6,7(676SDJH[OV[ 0,7&58&'3$'6,7(676SDJH[OV[ ƚƚĂĐŚĞĚ͕ƉůĞĂƐĞĨŝŶĚϭϬͲϰϮϲĨŽƌŵƐĨŽƌD/dƐĐŽŵƉůĞƚĞĚĂƚZh͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐŽƌŶĞĞĚ ŵŽƌĞŝŶĨŽƌŵĂƚŝŽŶ͘ dƌĂǀŝƐ^ŵŝƚŚ tE^/ŶƚĞƌǀĞŶƚŝŽŶΘ/ŶƚĞŐƌŝƚǇŶŐŝŶĞĞƌ ϵϬϳͲϲϳϬͲϰϬϭϰ dƌĂǀŝƐ͘d͘^ŵŝƚŚΛĐŽŶŽĐŽƉŚŝůůŝƉƐ͘ĐŽŵ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2031870 Type Inj N Tubing 4060 4060 4060 4060 Type Test P Packer TVD 6912 BBL Pump 1.0 IA 1980 3010 2960 2960 Interval 4 Test psi 1728 BBL Return 1.1 OA 200 200 200 200 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2051320 Type Inj N Tubing 950 950 950 950 Type Test P Packer TVD 6955 BBL Pump 4.4 IA 100 2000 1920 1920 Interval 4 Test psi 1739 BBL Return 3.1 OA 290 300 300 300 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2030730 Type Inj N Tubing 2475 2475 2475 2475 Type Test P Packer TVD 6961 BBL Pump 2.6 IA 75 1900 1840 1840 Interval 4 Test psi 1740 BBL Return 1.6 OA 61 75 75 75 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2011590 Type Inj N Tubing 825 825 825 Type Test P Packer TVD 7008 BBL Pump 3.0 IA 1500 2025 1600 Interval 4 Test psi 1752 BBL Return OA 490 500 490 Result F Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2021480 Type Inj N Tubing 1725 1725 1725 1725 Type Test P Packer TVD 6975 BBL Pump 2.8 IA 50 2490 2400 2390 Interval 4 Test psi 1744 BBL Return 2.2 OA 120 220 220 220 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD2 PAD Miller / Weimer 06/13/22 Notes: Notes: CD2-07 CD2-11 CD2-15 CD2-29 Notes: CD2-12 Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0613_MIT_CRU_CD2-pad_5wells      J. Regg; 8/11/2022 III, MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 11,2018 TO: Jim Regg P.I.Supervisor e7 151/ SUBJECT: Mechanical Integrity Tests t CONOCOPHILLIPS ALASKA,INC. CD2-15 FROM: Brian Bixby COLVILLE RIV UNIT CD2-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD2-15 API Well Number 50-103-20386-00-00 Inspector Name: Brian Bixby Permit Number: 201-159-0 Inspection Date: 6/5/2018 Insp Num: mitBDB180610163421 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD2-15 Type Inj "TVD 7008 Tubing 2290 2290 2290 2290 " PTD 2011590 Type Test SPT Test psi 1752 - IA 860 3100 - 3020 ' 3015 ' BBL Pumped: 1.9 BBL Returned: I.8 p OA 600 820 820 - 820 - Interval 4YRTST P/F P Notes: S%ANNE° JUN 2 2 Lula Monday,June 11,2018 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD2-15 (PTD# 201-159) failed MITIA Date:Tuesday, June 14, 2022 11:06:42 AM Attachments:CD2-15 90-day TIO.pdf CD2-15.pdf From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Monday, June 13, 2022 5:06 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD2-15 (PTD# 201-159) failed MITIA Chris— Alpine injection well CRU CD2-15 (PTD# 201-159) failed a diagnostic MITIA today. The well was shut- in for reservoir management at the time of the MITIA failure. It will remain shut-in awaiting diagnostics and a path forward. We will submit appropriate paperwork if a repair plan can be identified. A well schematic and 90-day TIO plot are attached. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com Annular Communication Surveillance 15 Well Name:CCD2-15 Start Date:15-Mar-2022 13 Days:90 End Date:13-Jun-2022 50 60 70 80 90 100 110 120 130 140 150 0 200 400 600 800 1000 1200 1400 1600 1800 15-Mar-2218-Mar-2221-Mar-2224-Mar-2227-Mar-2230-Mar-222-Apr-225-Apr-228-Apr-2211-Apr-2214-Apr-2217-Apr-2220-Apr-2223-Apr-2226-Apr-2229-Apr-222-May-225-May-228-May-2211-May-2214-May-2217-May-2220-May-2223-May-2226-May-2229-May-221-Jun-224-Jun-227-Jun-2210-Jun-2213-Jun-22Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 15-Mar-2218-Mar-2221-Mar-2224-Mar-2227-Mar-2230-Mar-222-Apr-225-Apr-228-Apr-2211-Apr-2214-Apr-2217-Apr-2220-Apr-2223-Apr-2226-Apr-2229-Apr-222-May-225-May-228-May-2211-May-2214-May-2217-May-2220-May-2223-May-2226-May-2229-May-221-Jun-224-Jun-227-Jun-2210-Jun-22Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:CD2-15 haggea Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET A-1 INJ VLV 1/24/2020CD2-15 boehmbh Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD)… 114.0 Wt/Len (l…Grade Top Thread Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 36.6 Set Depth (ftKB) 2,655.7 Set Depth (TVD)… 2,371.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.2 Set Depth (ftKB) 9,829.3 Set Depth (TVD)… 7,232.6 Wt/Len (l… 26.00 Grade L-80 Top Thread MBTC Casing Description OPEN HOLE OD (in) 6 1/8 ID (in) 6.12 Top (ftKB) 9,829.0 Set Depth (ftKB) 14,161.0 Set Depth (TVD)…Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 32.5 Set Depth (ft… 9,307.8 Set Depth (TVD) (… 7,069.6 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 32.5 32.5 0.00 HANGER FMC TUBING HANGER 4.500 2,137.92,001.4 43.63 NIPPLE CAMCO DB NIPPLE 3.812 9,197.3 7,008.2 54.17PACKER BAKER S-3 PACKER 3.875 9,295.0 7,062.8 57.74 NIPPLE HES XN NIPPLE 3.725 9,306.5 7,068.9 58.21 WLEG BAKER WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 2,138.02,001.5 43.63 VALVE 3.81" DB LOCK, A-1(SN; HYS-38) 1/24/2020 2.312 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 9,082.4 6,939.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 12/28/2001 Notes: General & Safety End Date Annotation 8/26/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 CD2-15, 5/25/2020 10:39:36 AM Vertical schematic (actual) OPEN HOLE; 9,829.0-14,161.0 PRODUCTION; 35.2-9,829.3 WLEG; 9,306.5 NIPPLE; 9,295.0 PACKER; 9,197.3 GAS LIFT; 9,082.3 SURFACE; 36.6-2,655.7 VALVE; 2,138.0 NIPPLE; 2,137.9 CONDUCTOR; 37.0-114.0 HANGER; 32.5 WNS INJ KB-Grd (ft) 43.73 Rig Release Date 10/30/2001 CD2-15 ... TD Act Btm (ftKB) 14,161.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032038600 Wellbore Status INJ Max Angle & MD Incl (°) 93.75 MD (ftKB) 10,404.63 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: WRDP MEMORANDUM To: Jim Regg 1 P.I. Supervisor ~ l~ 71 Z2~(fl FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-15 COLVILLE RIV IJNIT CD2-15 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J ~:e-- Comm Well Name: COLVILLE RIV UNIT CD2-ls Insp Num: mitJJ100719120822 Rel Insp Num: API Well Number: s0-103-20386-00-00 Permit Number: 201-159-0 Inspector Name: Jeff Jones Inspection Date: 6/11/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well cDZ-IS ~ Type Inj. w TVD coos ' IA looo zsoo - 2~ao ~ z~ao P.T.D 2011s90~ TypeTeSt SPT Test psi I~sz OA vo I6o I6o I6o InteYVa14YRTST P~F P ~ Tubing 2040 2040 2040 2040 Notes: 1.7 BBLS diesel pumped. 1 well inspected; no exceptions noted. Monday, July 26, 2010 Page 1 of 1 ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission f17 333 West 7th Avenue, Suite 100 sCANMEJ) A?R 2 '720u b 9 Anchorage, AK 99501 dv 0 \..,. ~. 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, ~.'f:~--_/ 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 C02-2 205-109 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 CD2-15 201-159 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 3 318/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . ~ ConocoPhillips Alaska :: 'J P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 J<! March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 5cANNEO þ.?R () 5 2.007 .9vÖ\' \5'q Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water trom 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 C02-2 205-1 09 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 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg '7"J\ /,-:1 (...7./~"IOi_ , t:'¿;,. J. ~v P.I. Supervisor \" /! DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CO2-I 5 COLVILLE RIV UNIT CO2-I 5 d-0\' \~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ;.1B~ Comm Well Name: COLVILLE RIV UNIT CD2-15 API Well Number 50-103-20386-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060827 I 93442 Permit Number: 201-159-0 Inspection Date: 8/27/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CO2-I 5 Type Inj. w TVD 7008 IA 1150 2520 2520 2520 P.T. 2011590 TypeTest SPT Test psi 1752 OA 550 700 700 700 / Interval 4YRTST P/F P ,/ Tubing 2150 2150 2150 2150 Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. NON-CONFIDENTIAL SCANNED SEP 082006 Wednesday, August 30,2006 Page I of I . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc '1~ N~v '~'"'> DATA SUBMITTAL COMPLIANCE REPORT 10/22/2003 MD 14161 -- TVD 7228 r Completion Date 10/30/2001 .r- Completion Status WAG IN Current Status WAGIN S!l~ .)"' 6 (t- ;Z~.,. API No. 50-103-20386-00-00 ~-- Permit to Drill 2011590 Well Name/No. COLVILLE RIV UNIT CD2-15 Operator CONOCOPHILLIPS ALASKA INC ---"----'-'---.-- -,----- --------------------'-'-"------- ----_._---------------------- "'------,-_.._------"" ------- --- "'---------------------"---'------ REQUIRED INFORMATION ~ 'i~ --= Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Data f~ Electr Digital Dataset Med/Frmt Number Name C u4 0790LlSVerificatior) ( Log Log Run Scale Media No 1 Interval Start Stop 2636 9840 OH/ CH Received Comments Open 4/2612002 ;hiS includes PB1and PB J Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y 1 ¡(J Chips Received? ~ Y I N - Formation Tops fJ/N I&N Daily History Received? Analysis Received? ~ , --..----------,.. ...----- (, -- Comments: Iu ~ ..:...., -~ V~ ~ IJ'-'\..t C j..Jll/ G ~ I c.. c '- ~ V1V'41 (-~ \J ~V' ~u.\I~ ~~/ ¡O ¡1 L./ ~ ~ "------ ---- --- -- -- ----'--' - -- ~ ~FJ." ^ (N 1.... r>tr c:mPlianc-=-~:viewed By: ...._--_....~ Ü -- Date: -1 ct_....._~ ~ Ii ~ 3. '\, , { ) ConocÓPh ¡IIi ps January 10, 2003 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal, Fourth Quarter, 2002 Dear Commissioner: { Randy Thomas aol-/5C¡ Greater Kuparuk Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RL Thomas @ ppco.com Please find attached the fourth quarter 2002 annular disposal for the Kuparuk, Alpine and Cook Inlet Fields. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2002, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2002. Please call me at 265-6830 should you have any questions. Sincerely, ,-'-=> . \~ R. Thomas Greater Kuparuk Team Leader RT/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental B. Morrison / R. Overstreet Sharon Allsup-Drake Well Files R E C E tV E D \ ", N -1 ¡~; ()OO~~ ",e." I,) L Alaska Oil & Gas ~~~~~>comm\ss\on , Ar\ch(.~! CI\:h> Annular Disposal dil,dng t~e fourth quarter of 2002: 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 CD2-26 15244 100 0 15344 380 . 13902 29626 September October CD2-38, CD2-44, CD2-29, 2002 2002 CD2-13 CD2-34 22895 100 0 22995 372 0 23367 Oct 2002 Dec 2002 CD2-13, CD2-37, CD2-35 CD2-48 11281 100 0 11381 375 0 11756 Dec 2002 Dec 2002 CD2-28, CD2-45 3S-07 18155 100 0 18255 216 0 18471 Dec 2002 Dec 2002 3S-09,3S-14,3S~10 3S-l8 206 100 0 306 0 0 306 . Dec 2002 Dec 2002 3S-18 I Total Vol . toA Iif hich D' 1 Authorizat' Exvired d ' the fi th fer 2002 J - l uar ~ 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 CD2-39 29466 100 0 379 29945 Open, Freeze Protected October Sept 2002 CD2-15, CD2-47, CD2- 2001 44 CD2-l4 30597 100 0 376 31073 Open, Freeze Protected November March CD2-45, CD2-47, CD2- 2001 2002 32, lC..14 32115 100 0 0 32215 Open, Freeze Protected October January 1C-109, 1R-36, 1C-24 2001 2002 2P -438 30331 100 0 212 30643 Open, Freeze Protected October December 2P-420, 2P-415, 2P-429 2001 2001 CD2-l5 31181 100 0 371 31652 Open, Freeze Protected March 2002 September CD2-50, CD2-25, CD2- 2002 44 CD2-47 26874 100 0 375 27349 Open, Freeze Protected December January CD2-34, CD2-26 2001 2002 CD2-45 22514 100 0 377 22991 Open, Freeze Protected January February CD2-49, CD2-17 2002 2002 Cook Inlet A larD' ld ' the~ th ter 2002 & ~ 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 Hansen #1 472 100 0 572 0 67224 67796 January October Hansen # 1 2002 2002 - ) - ) ~ Kuparuk and Alpine Annular Disposal during the third quarter of2002: 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 CD2-32 12701 100 0 12801 379 18636 31816 June 2002 July 2002 CD2-19, CD2-23, CD2-41 CD2-50 31530 100 0 31630 370 0 32000 July 2002 Sept 2002 CD2-41, CD2-19, CD2-16, CD2- 38 lC-18 27969 100 0 28069 379 4276 32724 June 2002 July 2002 1C-104 CD2-39 1966 100 0 2066 379 27500 29945 Oct. 2001 Sept2002 CD2-15, CD2-47, CD2-44 CD2-15 10459 100 0 10559 371 20722 31652 March Sept 2002 CD2-50, CD2-25, CD2-44 2002 CD2-26 13802 100 0 13902 380 0 14282 Sept 2002 Sept 2002 CD2-38, CD2-44, CD2-29 ( Cook Inlet Annular Disposal durinJ the third £j uarter of 2002: 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 Hansen #1 52255 100 0 52355 0 14869 67224 January Sept 2002 Hansen # 1 2002 .I Total Volumes into Annulifor which Disposal Authorization Expired durinR the third quarter 2002: 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 CD2-24 33524 100 0 375 33999 Open, Freeze Protected July 2001 Oct 2001 . CD2-33, CD2-39, CD2- 14, CD2-15 lC-26 34160 100 0 0 34260 Open, Freeze Protected August September lC-123, lC-119, lC-102 2001 2001 2N -332 31453 100 0 325 31878 Open, Freeze Protected August 2001 Sept 2001 2N-348, 2N-350 lC-16 32017 100 0 0 32117 Open, Freeze Protected Sept 2001 Oct 2001 lC-102, lC-131, lC-125 R ECEIVED OCT 2 4 2002 Alaska Oil& Gas Goos. Commission Anchorage ao J.. J 5<1 A L D' Ld ' h d if 2002 ( nnu ar lsposa urzng t e secon quarter 0 . . 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 CD2-15 10176 100 0 10276 371 10446 21093 March April CD2-25, CD2-50 2002 2002 2P-420 9479 100 0 9579 150 0 9729 April May 2002 2P-427, Heavenly 2002 2P-415A 26238 100 0 26338 52 4943 31333 March April 2P-431, 2P-422A, 2P-427, 2002 2002 Heavenly, Grizzly, 2P-441 CD2-49 27474 100 0 27574 386 0 27960 April May 2002 CD2-46, CD2-22, CD2-50 2002 CD2-17 14962 100 0 15062 372 0 15434 May 2002 June 2002 CD2-48, CD2-46 ID-l1 32102 100 0 32202 235 0 32437 May 2002 June 2002 1D-103 CD2-32 18536 100 0 18636 379 0 19015 June 2002 June 2002 CD2-19, CD2-41 lC-IS 4176 100 0 4276 379 0 4655 June 2002 June 2002 1C-104 ~ L ~ I A l'fi h' hD' LA h ' E ' dd ' h d 2002 (, ora 0 urnes lnto nnu l or W lC lsposa ut orzzatlon xplre urzng t e secon quarter 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 IJ -09 24202 100 0 330 24632 Open, Freeze Protected May 2001 May 2001 11-10 lC-17 33139 100 0 160 33399 Open, Freeze Protected May 2001 June 2001 1C-133, 1C-121, 1C- 123, lC-127 CD2-42 33507 100 0 385 33992 Open, Freeze Protected June 2001 October CD2-24, CD2-33, CD2- { 2001 15 \ 2P-417 30965 100 0 887 31952 Open, Freeze Protected October March 2P-422, Grizzly, 2P-451, \ 2001 2002 2P-441, 2P-448, 2P- 422A, 2P-420 lC-27 31766 100 0 153 32019 Open, Freeze Protected June 2001 July 2001 1C-127, 1C-117, 1C- 111, 1C-123 ( f '\ /"",\ " " ~,J '\ \f "" ì , \ \ '" ) ( l( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 November 18,2001 RE: MWD Formation Evaluation Logs - CD2-15, AK-MM-11163 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: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AI( 99518 00/-/ /)'1 1 LIS formatted CD Rom with verification listing. API#: 50-103-20386-00. RECE'VED ÞJJR 2 6 2002- AI- Oil & Gas Cons. Commission Ancboœge ( ( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn. : Lisa Weepie 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 November 18,2001 RE: MWD F onnation Evaluation Logs - CD2-15 PB2, AK-MM-11163 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: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 dO/-/S~ 1 LIS fonnatted CD Rom with verification listing. API#: 50-103-20386-71. -~ RECEIVED /' Pi) r'\ 6 ,..0 /-,. ., t. - ¿ O? JU - artra 0/1 & Gas Cons Comm' Anchoragë ISiOn ( i( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 November 18, 2001 RE: MWD Formation Evaluation Logs - CD2-15 PB1, AK-MM-11163 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: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ¿JOJ- /5 j 1 LIS formatted CD Rom with verification listing. API#: 50-103-20386-70. RECEIVED f. Cp ? ( ?OO? r\; ,\ ..... U ....\J - AI- Oil & Gas Cons. Commission Anchorage 03/07/02 SchlUmberger NO. 1885 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine '-c- Well Job# Log Description Date BL Sepia Color Prints CD ,-~ CD2-15 ~O)-I_c¡q 22094 SCMT 02123/02 1 CD2-17 aO~-Olc; 22096 SCMT 02123/02 1 CD2-49 .-::JnJ -::JlJ CJ 22095 SCMT 02111/02 1 , , SIGNEDC~ a - - G-- (!P~ ) RECEIVED DATE: i;.'-"'f-' ., J LuO2 .1 \. \ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. MaeilaÐiI& Gas Cons. Commisston Anchorage f MEMORANDUM ( State of Alaska Alaska Oil and Gas Conservation Commission /; TO: Cammy O. Taylor (}J\ DATE: Chair _\<l-. r( ~~BJECT: Mechanical Integrity. Tests THRU: Tom Maunder ~ dùÒ~ Operator í(:; (. ~ Petroleum Engineer\-\Cll..ç\\, Pad or platform {\\ V \\,-L Well Name C b - ~ FROM: Lou Grimaldi Unit Petroleum Inspector Field c.~\ ~'\ \\~ "\")~';C ,- NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well CD2-15 Type Inj. S T.V.D. 7008 Tubing 1228 1220 1220 1220 Interval I P.T.D. 2011590 Type test P Test psi 1752 Casing 1300 2000 1975 1950 P/F P Notes: Well CD2-17 Type Inj. S TV.D. 6968 Tubing 750 755 755 755 Interval I P.T.D. 2020150 Type test P Test psi 1742 Casing 1300 1875 1850 1825 P/F P Notes: Well CD2-26 Type Inj. S TV.D. 7003 Tubing 1620 1620 1620 1620 Interval I P.T.D. 2012490 Type test P Test psi 1751 Casing 850 1875 1875 1875 P/F P Notes: Observed pretest condo for thirty minutes (500 psi D. P.) Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N == NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V::. Required by Varianc€~ W= Test during Workover 0= Other (describe in notes) Test's Details The wells were on injection and ready to be tested when I arrived this morning. All wells pressured up quickly with no gas cap evident. Rick Alexander (lead operator) conducted the tests and had all pertinent info on hand The three injectors all passed their initial MIT's. Total Time during tests: 3 hours cc: Dethlefs/Nezatickv (PAl) M.I.T's performed: Three Attachments: None Number of Failures: None M IT report form 5/12/00 L.G. MIT Alpine CD2-15,17,26 3-9-02 LG.xls 3/11/02 .' ",. . L .\ ~ PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 9951 G-O360 R. Thomas Phone(9O7)26~O Fax: (907) 265-6224 ~ January 16, 2002 . Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner: \ " Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 200 1, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 200 1. Please call me at 265-6830 should you have any questions. Sincerely, ~ R. Thomas Greater Kuparuk Team Leader RT/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental: Engel I Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files ~€.c€. \\I€'O 1"',. ') (\\)1. ~ ,-" L. \) j ~ ~ .,; ro\SS\ot\ CÇ$\s.com O'~ &. Gas n,e ~\'ðS~3 ~ f.\t\c'\o~3\' . A I D' ld . th fi t if 2002 ~OI'IS1 nnu ar lsposa unng e lrs quarter 0 . . 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 2P-417 25534 100 0 25634 887 5431 31952 October March 2P-448, 2P-422A, Grizzly #1, 2001 2002 2P-451, 2P-441, 2P-420 CD2-14 16138 100 0 16238 376 14459 31073 November March CD2-32, CD2-47, CD2-45 2001 2002 lC-14 9626 100 0 9726 0 22489 32215 October January 1R-36, 1C-24, 1C-109 2001 2002 CD2-15 10346 100 0 1 0446 371 0 .1 10817 March March CD2- 50 2002 2002 CD2-4 7 16459 100 0 .16559 375 10415 27349 December January CD2-34, CD2-26, 2001 2002 CD2-45 22514 100 0 22614 377 0 22991 January February CD2-49, CD2-17 2002 2002 2P-415A 4843 100 0 4943 52 0 4995 March March Grizzly #1, 2P-431, 2P-441 2002 2002 CD2- 26 0 0 0 0 380 0 380 -- -- Freeze protect only for CD2-26 CD2-49 0 0 0 0 386 0 386 Feb 2002 Feb 2002 Freeze protect only ( J'¡ L ~ L A l'fi hO hDo LA h ° E ° dd ° h fio 2002 ora 0 urnes into nnu lor W lC lsposa ut onzatlon x/Jlre unn¡¿ t e lrst quarter . 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 ID-32 23162 100 0 337 23599 Open, Freeze Protected January February ID-39 2001 2001 IJ -03 30024 100 0 0 30124 Open, Freeze Protected March 2001 May 2001 11-09, 11-14, 11-10 ( QI~' ~ ol-{-,c¡ lO( " qs q ~.JJl to I-' f{:D lO t . 11 Q<Ö-/I1 lÖ,-~ ~1 ~'B 0 l"";o I 'lg- ~ '), ,OJ"" ~Q:)-I w- ), l ~QF ;r1)-- ( too-,., Annular Disposal durin/. the fourth quarter of 2001.. 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 ~í CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 200 1 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 l-J. lC-16 12338 100 0 12438 0 19679 32117 Sept 2001 October 1C-131, lC-125, 1C-I02 , 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 ~..., CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 i 2001 2001 , IC-14 22389 100 0 22489 0 0 22489 Oct 2001 Nov 2001 1C-109 '~ 2P-438 30331 100 0 30431 212 0 30643 Oct 200 1 Dec 2001 2P-420, 2P-415, 2P-429 ~ CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only ! CD2-47 10315 100 0 10415 375 0 10790 Dec2001 Dec2oo1 CD2- 34 '- Total Volumes into Annuli for which Disposal Authorization Expired during the fourth ~ uarter 2001.. 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 ,\~ 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec2ooo 2L-317, 2L-307 lj:1 10-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 ID-42, ID-34 IB CDl-31 6698 100 0 392 7190 Open, Freeze Protected Feb 200 1 March CDI-14 2001 ~þ 2N-305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect volumes only "13 10-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec2ooo ID-32, ID-40A 3C¡ 2N-349A 0 0 0 0 0 Open, Freeze Protected -- -- -- faIi 10-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 ID-37, ID-39 ::Þ i» en ~ m q ~ ::J>G) :::)Q) 9-(1) 0("') õ3° CQ:::) CD~ ("') ° 3 3 8f s- :::) \ ( C- Þ Z l:-.:I Ãf 0 m - < m 0 c.r.) "" <:::) a l'...1 (' ( 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 January 25,2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-15 and CD2-15PB 1 (201-159) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-15 and the plugback operations on CD2-15PB 1. If you have any questions regarding this matter, please contact me at 265-6120 or Vem Johnson at 265-6081. Sincerely, 1) .(. ~ OtÄ cfc.:lvord Alpine Drilling Team Leader PAl Drilling GCA/skad R. E:..J C"~. . E.' ,";¡'~ ~, \,1 Eo"," D" " \,.m- ".~ """'" ~ ,. ._~ H~t\' c~ I') ')no"" ".JJt"H1~ .¿, 0 Lu L .Alaska Oil & Gas Cons. Commission Anchorage ORiGINAL ( STATE OF ALASKA ( ALA~t<A OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended D Abandoned D Service 0 WAG Injector y' .. -- 7. Permit Number ~ffiÐ 201-159 , 8. API Number !~ tè. : ! ,.. :~.....: 50-103-20386-00 1716' FNL, 1545' FEL, Sec. 2, T11N, R4E, UM (ASP: 371696, 5974642),:-':i~7:;~~!~~~;:~:j~~i-~ At Top Producing Interval ! :'.<r::; , j ....La t 3.t' . lîJ '; 401' FSL, 1731' FEL, Sec. 34, T12N, R4E, UM (ASP: 366266, 5976854)\' w~-, c ,-~", AtTotal Depth ~ ..,t',~:,!,:c.. .~ ¡ GJ2 ; 890' FNL, 1375' FWL, Sec. 34, T12N, R4E, UM (ASP: 364157, 5980881) L::::..(.~.-...~::.-,:,~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 37' feet AOL 380075/387212 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore October 5,2001 October 28,2001 October 30,2001 N/A feet MSL 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 14161'MO/7228'TVO 14161'MO/7228'TVO YES 0 No 0 N/A feetMD 22. Type Electric or Other Logs Run GR/Res 23. 9. Unit or Lease Name Colville River Unit 10. Well Number CO2-15 I CO2-15PB1 & CO2-15PB2 11. Field and Pool Colville River Field Alpine Oil Pool 16. No. of Completions 1 21. Thickness of Permafrost 1558' MO 16" WT. PER FT. 62.5# 36# 26# GRADE H-40 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2656' Surface 9829' HOLE SIZE CEMENTING RECORD 42" 300 sx AS 1 AMOUNT PULLED CASING SIZE 9.625" 12.25" 7" 8.5" 399 sx AS III Lite, 240 sx Class G 132 sx Class G 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) 9307' PACKER SET (MD) 9197' open hole completion ,/ rSW'-- /tjlb/ n1j,') r .I 7"'3~"? .~ 72-rg -n-"'þ ¿_:::::::'t ._~ I . . .4 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N~ N~ 2. i,62-- PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL Test Period> Flow Tubing Casing Pressure Calculated press. psi 24-Hour Rate> 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. 27. Date First Production Date otTest Hours Tested GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) RECE\VED N/A '~\I q }i' Î nIl) J .À !ì~ ~, ,) . 'c' "I c. 0 "~'¡&' ¡""~sC(JOs Commission i\\aSì\a Uli ",'-< .~.. . , ,Aocho~age - Form 1 0-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate OR I GINAlwoMS BFL FEB 2 2002 (,~ 29. GEOLOGIC MARKEl 30. .' ( FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. CD2-15 Top Alpine D Top Alpine C Base Alpine 9554' 9605' 9700' 7173' 7189' 7212' 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 ~ L M.... . Chip Alvord Title Alcine Drillina Team Leader Date --4 2-5'{ ?2- 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. Ite"" 28: If no cores taken, indicate "none". Form 10-407 f (' PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-15 Common Well Name: CD2-15 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 10/4/2001 09:00 - 15:30 6.50 MOVE DMOB MOBMIR 15:30 - 19:00 3.50 MOVE RURD MOBMIR 19:00 - 21:30 2.50 MOVE RURD MOBMIR 21 :30 - 22:00 0.50 MOVE SFTY MOBMIR 22:00 - 23:00 1.00 WELCT BOPE MOBMIR 23:00 - 00:00 1.00 MOVE RURD MOBMIR 10/5/2001 9.50 DRILL DRLG SURFAC 00:00 - 09:30 09:30 - 11 :30 2.00 DRILL TRIP SURFAC 11:30 -12:30 1.00 RIGMNT RSRV SURFAC 12:30 - 13:00 0.50 DRILL TRIP SURFAC 13:00 - 00:00 11.00 DRILL DRLG SURFAC 10/6/2001 00:00 - 13:30 13.50 DRILL DRLG SURFAC 13:30 - 14:30 1.00 DRILL CIRC SURFAC 14:30 - 16:30 2.00 DRILL TRIP SURFAC 16:30 - 17:00 0.50 DRILL CIRC SURFAC 17:00 - 19:30 2.50 DRILL TRIP SURFAC 19:30 - 19:45 0.25 DRILL PULD SURFAC 19:45 - 22:00 2.25 DRILL TRIP SURFAC 22:00 - 22:30 0.50 DRILL REAM SURFAC 22:30 - 00:00 1.50 DRILL DRLG SURFAC 1017/2001 00:00 - 01 :30 1.50 DRILL CIRC SURFAC 01 :30 - 07:00 5.50 DRILL TRIP SURFAC 07:00 - 09:00 2.00 CASE RURD SURFAC 09:00 - 09:15 09:15 - 14:00 0.25 CASE 4.75 CASE SFTY SURFAC RUNC SURFAC 14:00 - 14:45 0.75 CEMEN PULD SURFAC Page':1 of 8 Spud Date: 10/5/2001 End: 10/30/2001 Group: Start: 10/4/2001 Rig Release: 10/30/2001 Rig Number: 19 Description of Operations Move rig to well CD2-15. Center rig over hol e and move in support modules. Connected water, air and steam lines, high line power 0 n @ 1430 hours, Rig accepted @ 1530 hours NU Divertor System, riser and flowline. Tak e on mud in pits. MU BHA #1, plug in and program MWD. Held Pre-Spud meeting with Rig Team Perform Divertor and Accumulator tests, Ch uck Sheve (AOGCC) waived witnessing test. MU UBHO sub and 1 stand of 8" collars. Fill Conductor and check for leaks. Repair leak on Riser/Annular flange Spud well, drill 12-1/4" hole from 114' to 88 8', lost 400 psi pump pressure. ART=2.6 A ST=4.1 Trouble shoot surface equipment, unable to prove source of pressure loss. POH and insp ect tools, OK. Go through fluid ends of mud pumps. Remov ed rock from #1 pump suction valve/seat. RIH to 888'. Drill from 888' to 1892'. ART=3.7 AST=4.1 Drill from 1892' to 2520', ROP dropped to 2 0 fph, unable to improve rate. ART=7.9 AST =2.2 Circulate hole clean, 630 gpm, 125 rpm. POH, tight from 2290' to 1718', 50-75k over, slight swabbing. Backream from 1718' to 1652', no problems, circ 1.5 BU, 630 gpm, 120 rpm. POH, tight from 1615' to 1272', 25-50k over. Continue to POH, no other problems. Change bit, heel row on bit #1, dull. MU BHA #2 and RIH to 2324', no problems. Precationary ream from 2324' to 2520'. Drill from 2520' to 2666', casing point. ART =1.4 AST=O Pumped low/high vis sweeps and circ hole cl ean, monitor well, static. POH, wiped through tight spots @ 2380',22 66',1913',1755' and 1513' 40-50k over. Mo nitor well at hwdp, static. Stand back hwdp and 8" DC's, lay down remainder of BHA. CI ear tools from and clean rig floor. RU to run 9-5/8" casing, change out bails, M U fill-up tool and rig up running tools. Held pre job safety meeting with crew. ran 61 joints of 9-5/8", 36#, L-80 casing. M U hanger and landing joint, land casing @ 2 666', FC @ 2567'. Lay down fill-up tool and MU cement head. Printed: 1/11/2002 3:25:36 PM ~ ....... ~ <pHi Llj'¡;s'~ 1m. 'V' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/7/2001 10/8/2001 10/9/2001 10/10/2001 (' ( PHilliPS ALASKA INC. Operations Summary Report CD2-15 CD2-15 ROT - DRILLING Doyon Doyon 19 From - To Hours Code Sub Phase Code 14:45 - 16:15 16:15 - 18:00 18:00 - 19:00 19:00 -19:30 19:30 - 21 :00 21 :00 - 00:00 00:00 - 08:00 08:00 - 09:00 09:00 - 11 :30 11 :30 - 12:30 12:30 - 14:30 14:30 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 17:30 17:30 - 18:00 18:00 - 18:30 18:30 - 19:00 19:00 - 19:30 19:30 - 00:00 00:00 - 09:00 09:00 - 09:30 09:30 - 10:30 1 0:30 - 11 :30 11 :30 - 12:00 12:00 - 00:00 00:00 - 10:30 1.50 CEMENl CIRC SURFAC 1.75 CEMEN" PUMP SURFAC 1.00 CEMEN" PULD SURFAC 0.50 CEMENl RURD SURFAC 1.50 WELCTL NUND SURFAC 3.00 WELCTL NUND SURFAC 8.00 DRILL 1.00 DRILL 2.50 DRILL OTHR INTRM1 OTHR INTRM1 PULD INTRM1 1.00 RIGMNT RURD 2.00 DRILL PULD 0.50 CEMENl GOUT 0.50 DRILL CIRC 1.00 DRILL DEaT INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 1.00 CEMENl DSHO INTRM1 0.50 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 4.50 DRILL 9.00 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL 0.50 DRILL 12.00 DRILL 10.50 DRILL DRLG INTRM1 CIRC INTRM1 FIT INTRM1 CIRC INTRM1 DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 WIPR INTRM1 TRIP INTRM1 REAM INTRM1 DRLG INTRM1 DRLG INTRM1 Page 2 of 8 Spud Date: 10/5/2001 End: 10/30/2001 Group: Start: 10/4/2001 Rig Release: 10/30/2001 Rig Number: 19 Description of Operations Staged pumps up to 10 bpm and conditioned mud for cementing. Reciprocated pipe 160k PUW, 140k SOW, final pressure 520 psi, full returns throughout. Pumped 40 bbls of Biozan spacer with nut pi ug marker, swith to cement line and pressur e test lines to 2500 psi. Pumped 50 bbls of 12.5 ppg spacer, mix and pump 313 bbls of 10.7 ppg lead and 49.5 bbls of 15.8 ppg tail slurry. Displaced cement with 20 bbls of F W from cementers and 179 bbls of mud with rig pumps @ 10 bpm. Bumped plugs, floats h eld, CIP @ 1800 hours. RD cement head, landing joint, elevators an d long bails. Flush diverter system and flowline with fres h water. ND Diverter system. Install wellhead, test M/M seals to 1000 psi. NU BOP Stack. Test BOPE - pipe rams, choke & kill line val ves, choke manifold valves floor valves, IB OP, blind rams to 250 psi low & 5000 psi hi gh - Hydril to 250 psi low & 3500 psi high - Change IBOP & repair choke manifold valve # 4 - retest ok - LID test plug - Install wear bushing M/U BHA # 3 - 8 1/2" - RIH wi HWDP - to 10 76' - change to 4" tools PJSM - Cut & slip drill line RIH - P/U 54 jts. 4" drill pipe f/ pipe shed Clean out cmt stringers fl 2492' to 2535' Circulate hole clean for casing test Rig up & pressure test 9 5/8" casing to 2500 psi for 30 mins. Drill cmt - wiper plugs - float collar - cmt - drill out shoe - clean out rat hole to 2666' Drill 20' new hole fl 2666' to 2686' Circulate for F.I.T. Rig up & perform F.I.T. to 16.2 ppg EMW Change over to 9.2 ppg LSND mud Drill 8 1/2" hole f/ 2686' to 3268' - 2806' T VD - ADT 3.4 ART 3.4 Drill 8 1/2" hole f/ 3268' to 4223' - 3498' T VD ADT - 5.7 ART - 5.0 AST - .7 Circ hole clean for wiper trip Monitor well - static - wiper hip fl 4223' to 2604' - hole slick RIH fl 2604' to 4127' Safety ream fl 4127' to 4223' Dril18 1/2" hole f/ 4223' to 5560' - 4446' T VD -ADT-7.3 AST-.2 ART-7.1 Drill 8 1/2" hole fl 5560' to 6611' 5681' TV Printed: 1/11/2002 3:25:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/10/2001 10/11/2001 10/12/2001 10/13/2001 10/14/2001 ( (' PHilliPS ALASKA INC. Operations Summary Report CD2-15 CD2-15 ROT - DRILLING Doyon Doyon 19 Sub From - To Hours Code Code Phase 00:00 - 10:30 10:30 - 11 :30 11 :30 - 13:30 13:30 - 14:30 14:30 - 15:00 15:00 - 00:00 00:00 - 18:30 18:30 - 20:00 20:00 - 22:00 22:00 - 23:30 23:30 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 05:00 05:00 - 05:30 05:30 - 06:30 06:30 - 07:30 07:30 - 09:00 09:00 - 15:30 15:30 - 16:30 16:30 - 18:00 18:00 - 19:00 19:00 - 21:00 21 :00 - 22:00 22:00 - 00:00 10.50 DRILL 1.00 DRILL 2.00 DRILL 1.00 DRILL 0.50 DRILL 9.00 DRILL 18.50 DRILL 1.50 DRILL 2.00 DRILL 1.50 DRILL 0.50 DRILL 24.00 DRILL 24.00 DRILL 1.50 DRILL 1.00 DRILL 2.50 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL 1.50 DRILL 6.50 DRILL 1.00 DRILL 1.50 DRILL 1.00 DRILL 2.00 DRILL 1.00 CASE 2.00 CASE DRLG INTRM1 CIRC INTRM1 WIPR INTRM1 TRIP INTRM1 REAM INTRM1 DRLG INTRM1 DRLG INTRM1 crRC INTRM1 WIPR INTRM1 TRIP INTRM1 REAM INTRM1 DRLG INTRM1 DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 WIPR INTRM1 CIRC INTRM1 WIPR INTRM1 TRIP INTRM1 CIRC INTRM1 TRIP INTRM1 TRIP INTRM1 PULD INTRM1 OTHR INTRM1 OTHR INTRM1 RURD INTRM1 RUNC INTRM1 Page 3 018 Spud Date: 10/5/2001 End: 10/30/2001 Group: Start: 10/4/2001 Rig Release: 10/30/2001 Rig Number: 19 Description 01 Operations D - ADT 6.8 AST 1.5 ART 5.3 Circulate hole clean for wiper trip Monitor well - static - Wiper trip f/ 6611' to 4227' - 25 stds - hole slick Monitor well - static - RIH f/ 4227' to 6515' Safety wash & ream fl 6515' to 6611' Drill 8 1/2" hole f/ 6611' to 7470' - 5804' TV D - ADT 5.8 ART 4.7 AST 1.1 * NOTE : Will conduct safety meeting with all crews 10/11/01 to review all resent i ncidents Dril18 1/2" hole fl 7470' to 8902' - 6821' T VD ADT 11.2 AST 1.4 ART 9.8 Pump hi vis sweep - bump mud wt. to 9.8 pp g - circulate & condo for wiper trip - 580 gp m&110RPM Wiper trip f/ 8902' to 6610' - 5 to 10 K dra g Monitor well - static - RIH fl 6610' to 8806' Safety ream fl 8906' to 8902' - Circulate bt m sup Dril18 1/2" hole fl 8902' to 9580' - 7180' T VD ADT 12.3 AST 9.9 ART 2.4 Dril18 1/2" hole f/ 9580' to 9825' 7233' TV D - ADT 10.7 AST - 10 ART.7 Dril18 1/2" hole fl 9825' to 9840' - 7234' T VD ADT.8 AST.8 Pump sweep & circ hole clean Wiper trip f/ 9840' to 8800' - pump out & ba ck ream Circulate btms up f/ 8800' Contiune wI wiper trip f/ 8800' to 8320' - ho Ie in good condition - monitor well - static RIH f/ 8320' to 9840' - safety ream from 977 2 ' to 9840' Pump hi vis sweep & circulate hole clean Monitor well - static - TOOH wet to 7940' - pump dry job & continue TOOH - flow check @ 9 5/8" shoe - static - TOOH to BHA - work various tight spot fl 6547' to 5942' - pulled 10 - 20 over Stand back 4" & 5" HWDP, jars, flex collars Break out bit, down laod MWD, LID motor, s tab, MWD, & bit - clean up rig floor Plu stack washer & flush BOP - blow down t op drive Pull bushing - drain stack - set test plug - P JSM - change top pipe rams to 4 1/2" x7" - b ody test door to 3500 psi - pull test plug - i nstall thin wall wear bushing - change top d rive junk sub to 4 1/2" IF Rig up to run 7" casing PJSM - Begin running 7" 26# L-80 MBTC cas Printed: 1/11/2002 3:25:36 PM ..... ....... ..... ~'pHí UJPS) ,liD ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/14/2001 10/15/2001 10/16/2001 (' (' Page 4 of 8 PHilliPS ALASKA INC. Operations Summary Report CD2-15 CD2-15 ROT - DRILLING Doyon Doyon 19 Sub From - To Hours Code Code Phase 22:00 - 00:00 00:00 - 03:00 03:00 - 03:30 03:30 - 08:00 08:00 - 08:30 08:30 - 12:00 12:00 - 13:30 13:30 - 14:15 14:15 - 15:30 15:30 - 17:30 17:30 - 18:30 18:30 - 00:00 00:00 - 01 :00 01 :00 - 03:30 03:30 - 09:30 09:30 - 10:30 10:30 - 13:00 13:00 - 13:30 13:30 - 14:00 14:00 - 15:00 15:00 - 16:30 16:30 - 19:00 2.00 CASE 3.00 CASE 0.50 CASE 4.50 CASE 0.50 CASE 3.50 CASE 1.50 CEMEN" CI RC RUNC INTRM1 RUNC INTRM1 CIRC INTRM1 RUNC INTRM1 CIRC INTRM1 RUNC INTRM1 0.75 CEMENl PUMP INTRM1 INTRM1 1.25 CEMENl DISP INTRM1 2.00 CEMEN" PULD INTRM1 1.00 DRILL 5.50 DRILL 1.00 DRILL 2.50 DRILL 6.00 DRILL OTHR PROD OTHR PROD OTHR PROD PULD PROD PULD PROD 1.00 RIGMNT RSRV PROD 2.50 DRILL TRIP PROD 0.50 CEMEN" GOUT PROD 0.50 DRILL 1.00 DRILL CIRC PROD OTHR PROD 1.50 RIGMNT RURD PROD 2.50 CEMEN" DSHO PROD Spud Date: 10/5/2001 End: 10/30/2001 Group: Start: 10/4/2001 Rig Release: 10/30/2001 Rig Number: 19 Description of Operations .. ing - M/U & Bakerlok shoe track joints - che ck floats - run 7" csg - 7 jts. to 276.96' Continue running 7" 26# L-80 MBTC casing to 2649' (65 jts.) Circulate btms up @ 9 5/8" shoe Continue running 7" 26# L-80 MBTC to 7038' (173 jts) Circulate btms up @ 7038' Contiune running 7" 26# L-80 MBTC to 9793' - 241 jts. total - landed casing wI mandel h anger in wellhead wI shoe @ 9830' FC @ 9743' - rig down fill up tool - install cement head Circulate and condition mud for cement job -PV 7 YP 18 PJSM - Cement 7" - Pump 5 bbls pre-flush - test lines to 3000 psi pump 15 bbls pre-flus h - pumped 50 bbls Arco spacer @ 12.5 ppg drop btm plug - pump 30 bbls 15.8 ppg cmt - drop top plug Pumped 20 bbls water f/ Dowell - switch to r ig pumps & displace cement wI 353 bbls 9.8 ppg mud - 7 bbls/min @ 400 to 700 psi bum ped plug wI 1000 psi - floats held - CIP @ 1 510 hrs - Rig down cmt head - elevator - landing joint - long bails -pull thin wall wear bushing - i nstall & test pack-off to 5000 psi Change top pipe rams to 3 1/2. X 6" - chang e top drive junk sub to XT-39 Set test plug - Test BOPE - Hydril to 250 ps i & 3500 psi - pipe rams, blind rams, choke manifold valves, kill and choke line valves , TIW, dart valve, top drive valves 250 psi & 5000 psi - perform accumulator recovery te st - Witnessing of test waived by John Crisp AOGCC - LID test plug - set wear bushing - blow down choke and kill lines RI U for TIH M/U BHA # 4 - 6 1/8. bit - motor - MWD - ori ent motor & MWD TIH wI BHA #4 - picking up 4" drill pipe fl p ipe shed (156 jts) Adjust kelly hose and service loop Continue RIH wI 4. drill pipe fl derrick to 9 626' - took wt. Break circ - wash & ream f/ 9626' to 9695' - cmt stringers Circ & condition mud for casing test Rig up & test 7" casing to 3500 psi for 30 m ins. - rig down Slip & cut drill line 60' - service top drive C/O cmt - wiper plugs - FC @ 9743' - cmt - Printed: 1/11/2002 3:25:36 PM '"" ---. -'" ~~PHILLlPS) I[Ð .,.,. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/16/2001 10/17/2001 10/18/2001 10/19/2001 10/20/2001 10/21/2001 10/22/2001 f (' PHILLIPS ALASKA INC. Operations Summary Report CD2-15 CD2-15 ROT - DRILLING Doyon Doyon 19 Page 5 of 8 Spud Date: 10/5/2001 End: 10/30/2001 Group: Start: 10/4/2001 Rig Release: 10/30/2001 Rig Number: 19 Description of Operations Sub From - To Hours Code Code Phase .. . 16:30 - 19:00 19:00 - 20:00 20:00 - 21 :00 21:00 - 21:30 21 :30 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 09:00 09:00 - 15:00 15:00 - 15:30 15:30 - 18:00 18:00 - 18:30 18:30 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 20:00 20:00 - 20:30 20:30 - 21 :00 21 :00 - 00:00 00:00 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 04:00 2.50 CEMENl DSHO PROD 1.00 DRILL DRLG PROD 1.00 DRILL 0.50 DRILL 2.50 DRILL 12.00 DRILL 12.00 DRILL 24.00 DRILL 2.50 DRILL 0.50 DRILL 6.00 DRILL 6.00 DRILL 0.50 DRILL 2.50 DRILL 0.50 DRILL CIRC PROD FIT PROD OTHR PROD DRLG PROD DRLG PROD DRLG PROD DRLG PROD OBSV PROD TRIP PROD TRIP PROD PULD PROD PULD PROD PULD PROD 3.50 DRILL TRIP PROD 0.50 RIGMNT RSRV PROD 1.50 DRILL TRIP PROD 0.50 DRILL TRIP PROD 0.50 DRILL REAM PROD 19.00 DRILL 0.50 DRILL 0.50 DRILL 3.00 DRILL 24.00 DRILL 2.50 DRILL 1.00 DRILL 0.50 DRILL DRLH PROD OTHR PROD TRIP PROD DRLH PROD DRLH PROD DRLH PROD OTHR PROD DRLH PROD shoe @ 9830' - clo rat hole to 9840' Drill 20' new hole fl 9840' to 9860' TVD ADT.9 AST.9 Circ hole clean for F.I.T. Perform F.I.T. to 12.5 ppg EMW wI 1020 psi wI 9.8 ppg mud PJSM - Change well over to 9.2 ppg Flo Pro mud - monitor well - static - clean surface e quip Dril16 1/8" hole fl 9860' to 10351' - TVD 7 222' ADT 8.8 AST 5.1 ART 3.7 Dril16 1/8" hole f/ 10351' to 10936' - TVD 7202' ADT 7.4 AST 3.8 ART 3.6 Drill 6 1/8" hole f/ 10936' to 12,160' 7182' TVD ADT 14.8 AST 3.3 ART 11.5 Drill 6 1/8" hole f/ 12,160' to 12,209' 718 0' TVD ADT 2.1 AST 0 ART 2.1 - motor fa ¡lure Prep to POOH - monitor well - static POOH pump out to 8935' (35 stds) Monitor well - static - blow down top drive - monitor well - static Continue POOH on tri p tank to BHA - std back HWDP & jars LID flex monels - bit - motor ( unable to fin d any problem wI motor) P/U new motor - M/U bit - Down load MWD - Change pulser - up load MWD - Orient motor & MWD P/U flex monels - RIH wI HWDP & jars - test MWD @ 431' RIH to 7970' - filling pipe every 2000' Serveic rig Continue RIH to 9886 Continue RIH F/9886'-12,082' Safety wash & ream FI 12,082' - 12,209' TM D Drlg f 112,209' - 12,273' TMD 7,177'TVD ADT9.8, ART1.4, AST8.4 *Note*: Unable to rotate or slide, Decision made to pull up an d attempt open hole sidetrack, Per Anchorag e office. Flow check, survey, obtain SPRs Pumpout F/12,273' - 11,806' TMD Time drilling FI 11,806' - 7,192' TVD, ADT 1.4 AST 1.4, attempting to sidetrack Time driling fl 11,806' to11 ,834' - 7192' T VD ADT 16.6 AST 16.6 Attempting an open hole sidetrack Attempt to sidetrack time drill f/ 11,834' to 11846' - ADT - 1.9 AST 1.9 MWD failure - attempt to regain data - unsu ccessful Dril16 1/8" hole f/ 11,846' to 11,865' - 719 7236' Printed: 1/11/2002 3:25:36 PM """"" (pHiLLIPs) I[Ð ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/22/2001 10/23/2001 10/24/2001 10/25/2001 10/26/2001 f (, Page 6 of 8 PHilliPS ALASKA INC. Operations Summary Report CD2-15 CD2-15 ROT - DRILLING Doyon Doyon 19 Sub From -To Hours Code Code Phase 03:30 - 04:00 04:00 - 09:00 09:00 - 13:00 13:00 - 15:00 15:00 - 15:30 15:30 - 19:30 19:30 - 20:00 20:00 - 23:30 23:30 - 00:00 00:00 - 04:00 04:00 - 05:00 05:00 - 05:30 05:30 - 07:00 07:00 - 08:00 08:00 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 05:00 05:00 - 06:30 06:30 - 12:00 12:00 - 00:00 00:00 - 12:30 12:30 - 14:00 14:00 - 15:00 15:00 - 16:30 16:30 - 00:00 00:00 - 12:00 12:00 - 12:30 0.50 DRILL 5.00 DRILL 4.00 DRILL 2.00 DRILL DRLH PROD TRIP PROD TRIP PROD PULD PROD 0.50 WELCTL BOPE PROD 4.00 WELCTL BOPE PROD 0.50 WELCTL BOPE PROD 3.50 DRILL PULD PROD 0.50 DRILL TRIP PROD 4.00 DRILL TRIP PROD 1.00 RIGMNT RURD PROD 0.50 RIGMNT RSRV PROD 1.50 DRILL TRIP PROD 1.00 DRILL 16.00 DRILL 2.00 DRILL 1.00 DRILL 2.00 DRILL 1.50 DRILL 5.50 DRILL 12.00 DRILL 12.50 DRILL SURV PROD DRLG PROD DRLG PROD CIRC PROD DRLG PROD CIRC PROD DRLG PROD DRLG PROD DRLG PROD 1.00 DRILL 1.50 FRMTST CI RC PROD PROD 1.50 DRILL 7.50 DRILL 12.00 DRILL 0.50 DRILL TRIP DRLH PROD DRLH PROD DRLH PROD DRLH PROD Spud Date: 10/5/2001 End: 10/30/2001 Group: Start: 10/4/2001 Rig Release: 10/30/2001 Rig Number: 19 Description of Operations 1'TVD ADT.2 ART.2 Monitor well - static - TOOH wI pump f/ 11, 846' to 9,122' - Monitor well @ 7" shoe - sta tic Continue TOOH on trip tank fl 9,122' to 340' (BHA) Stand back HWDP, jars, flex collars - LID M WD, motor, & bit PJSM - flow check - drain stack - pull wear bushing - set test plug Install test plug - R/U & Test BOPE, Hydril @ 250 10 I 3500 hi, pipe rams,blind rams, ch oke & kill line valves, choke manifold valve s, floorsafety valve, dart valve, Hydraulic & Manual Top Drive valves T/250 10 - 5,000 P SI Hi. Perform accumulator recovery test. W itnessing of test waived by Jeff Jones AOGC C. RID & Pull test plug, Install wear bushing. P/U BHA, MWD, Orient, Upload MWD, RIH wI DC & HWDP' Test MWD@ 466'TMD RIH wI 4" DP Continue RIH to 7" shoe. Cut & Slip Drlg Line @ 9,820'TMD. Service Top Drive. Rih, wI Bit #4rr, Orient & work into Sidetrac k @ 11,808', Tag Btm @ 11,865' TMD. MAD Pass fl 11,830 - 11,865' TMD. Drld ahead fl 11,865' - 12,782' TMD 17,187' TVD, ADT 11.5, ART 9.6 AST 1.9 hrs Drill fl 12,782' to 12,890' Circulate btms up sample for geologist. Drill fl 12,890' to 12,956' TMD. Circulate btms sample for geologist. Drill fl 12,956' to 13,100' TMDI 7,187' TVD, ADT 6.3 hrs, ART 3.2 hrs, AST 3.1 hrs. Drill f/ 13,100' to 13,310' TMD 17,180' TVD. ADT 6.1 hrs, ART1.6 hrs, AST 4.5 hrs. Drld fl 13,310' - 13,776' TMD I 7,187' TVD. ADT=9.0 hrs, ART=5.4 hrs, AST=3.6 hrs. Circulate up sample f/ Geology, sweep hole while waiting on Geology. Flow check, Pump out fl 13,776' to 13,450' TMD I 7,189' TVD. Pull up to 13,410' TMD. Trenching for sidetrack f/ 13,410' - 13,450' Open hole sidetrack,Time drlg, f/ 13,450'-1 3,456' TMD I 7,191' TVD. ADT= 5.5 hrs, AS T= 5.5 hrs, ART= 0 hrs. Open hole sidetrack, Time drlg fl 13,456' - 13,495' TMD 17,191' TVD. ADT= 11.1 hrs, AST= 11.1 hrs, ART= 0 Drlg, rotate fl 13,495' - 13,505' TMD. Whi Ie drlg @ 13,505' TMD an MWD tool failure 0 Printed: 1/11/2002 3:25:36 PM f PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-15 Common Well Name: CD2-15 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 19 Date From -To Hours Code Sub Phase Code 10/26/2001 12:00 - 12:30 0.50 DRILL DRLH PROD 12:30 - 18:30 6.00 DRILL DRLH PROD 18:30 - 20:30 2.00 DRILL CIRC PROD 20:30 - 00:00 3.50 DRILL TRIP PROD 10/27/2001 00:00 - 04:00 4.00 DRILL TRIP PROD 04:00 - 08:45 4.75 DRILL TRIP PROD 08:45 - 09:30 0.75 DRILL TRIP PROD 09:30 - 12:45 3.25 DRILL PULD PROD 12:45 - 13:15 0.50 DRILL TRIP PROD 13:15 - 18:45 5.50 DRILL TRIP PROD 18:45 - 19:30 0.75 DRILL TRIP PROD 19:30 - 20:15 0.75 DRILL TRIP PROD 20:15 - 20:45 0.50 DRILL REAM PROD 20:45 - 00:00 3.25 DRILL REAM PROD 1 0/28/2001 00:00 - 02:15 2.25 DRILL DRLH PROD 02:15 - 18:00 15.75 DRILL DRLH PROD 18:00 - 20:00 2.00 DRILL CIRC PROD 20:00 - 23:00 3.00 DRILL CIRC PROD 23:00 - 00:00 1.00 DRILL TRIP PROD 1 0/29/2001 00:00 - 01 :00 1.00 DRILL CIRC PROD 01 :00 - 02:30 1.50 DRILL TRIP PROD 02:30 - 03:15 0.75 DRILL CIRC PROD 03:15 - 04:45 1.50 DRILL TRIP PROD 04:45 - 08:00 3.25 DRILL TRIP PROD Page 7 of 8 Spud Date: 10/5/2001 End: 10/30/2001 Group: Start: 10/4/2001 Rig Release: 10/30/2001 Rig Number: 19 Description of Operations ccured (@12:30 hrs) Drld ahead blind f/ 13,505' - 13,929' TMD. ADT= 5.2 hrs, ART= 5.2 hrs, AST= 0 Circulate piggyback 300 FV vis sweeps, pre pare to displace to brine. Decision was mad e to trip f/ new MWD and finish drlg planned interval, Per Geologist. Flow check well bore. Pumping out of the ho Ie 11 13,929' TMD Pump out from 12117' to 9539', hole in good condition, 5-10K over. Flow check well, sta tic. POH to BHA, flow check well static. Set back hwdp, plug in and download LWD ( 30 min). Lay down BHA #6, PU BHA #7, program LWD (30) min. RIH to 465', shallow test tools. RIH to 11750', filled pipe every 2000'. Orientate into first sidetrack, survey for con formation. RIH to 13400'. Orientate into 2nd 13450' to 13500', Mad Pass log from each stand. Drill from 13929' to 14082', ROP dropped fr om 100 fph to 5 fph. Drill from 14082' to 14161', 87 Degree Inc. ROP 5-6 fph.Cuttings indicated siltstone ab ove Alpine sands. At 0900 hrs. LWD indicat ed crossing an unmapped fault. Abandoned a ttempt to drill back into Alpine sands when shale was observed in cuttings. Total ART= 13.7 AST=1.3 Pump piggy back 300 fv sweeps and circ ho Ie clean, monitor well static. Pump 40 bbl push pill and displaced hole wi th 9.2 ppg KCL Brine untill clean, 780 bbls 170% of hole volume. Monitor well, initial 10 sses 48 bph. POH to 13259', 42 bph losses. Total brine 10 sses 59 bbls. Losses continued at 42 bph, pumped 40 bbls of 3 ppb Flo-Vis pill, 5.0 bpm @ 1370 psi, displaced into open hole. POH from 13259' to 11320', 15-25Kdrag, flu id losses @ 22 bph. . Pumped 40 bbls of 3 ppg Flo-Vis pill, 5.0 bp m @ 1320 psi, displaced into open hole. POH from 11320' to 9444', monitor well, 8 b ph losses. POH, LD excess drill pipe from 7026' to 476 sidetrack, MAD Pass from survey. 13500' to 13927', survey Printed: 1/11/2002 3:25:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( PHilliPS ALASKA INC. Operations Summary Report CD2-15 CD2-15 ROT - DRILLING Doyon Doyon 19 Date From -To Hours Code Sub Phase Code 10/29/2001 04:45 - 08:00 3.25 DRILL TRIP PROD 08:00 - 08:30 0.50 RIGMNT RGRP PROD 08:30 -11:45 3.25 DRILL TRIP PROD 11:45 -12:00 0.25 DRILL PULD PROD 12:00 - 13:30 1.50 DRILL PULD PROD 13:30 - 13:45 0.25 CMPL TN OTHR CMPL TN 13:45 - 15:15 1.50 WELCT BOPE CMPL TN 10/30/2001 15:15 - 15:45 15:45 - 16:00 16:00 - 22:15 22:15 - 00:00 00:00 - 04:15 04:15 - 04:30 04:30 - 07:00 07:00 - 08:15 08:15 - 09:30 09:30 - 10:30 0.50 CMPL TN RURD CMPL TN 0.25 CMPL TN SFTY CMPL TN 6.25 CMPL TN PULD CMPL TN 1.75 CMPL TN SEaT CMPL TN 4.25 CMPLTN NUND CMPLTN 0.25 CMPL TN SFTY CMPL TN 2.50 CMPL TN FRZP CMPL TN 1.25 CMPL TN NUND CMPL TN 1.25 CMPL TN DEOT CMPL TN 1.00 CMPL TN NUND CMPL TN Page 8 of 8 Spud Date: 10/5/2001 End: 10/30/2001 Group: Start: 10/4/2001 Rig Release: 10/30/2001 Rig Number: 19 Description of Operations 4', 4 bph losses. Replace failed hydraulic hose on Iron Rough neck. Continue to lay down 4" drill pipe from 4764 , to 372'. Circ 40 bbls of treated brine through BHA. Lay down flex collars, down load LWD (25 m in), lay down BHA. PU wash sub and flush BOP Stack. Pull wear bushing, install 4-1/2" test joint a nd plug. Test top pipe rams to 250/5000 psi, LD test joint and plug. RU to run 4-1/2" tubing. PJ SM. PU & MU Completion equipment and 4-1/2" t ubing, MU hanger and land tubing, WLEG @ 9308' . RILDS, LD LJa, install TWC, MU LJb and RU to test hanger M/M seals. Test tubing hanger M/M seals to 5000 psi. L D LJb, ND BOPE. Install and test adaptor fl ange and tree to 5000 psi. RU lubricator an d pull TWC. RU circ manifold and hard lines , pressure test to 4000 psi. PJ SM. Pumped 130 bbls of 9.6 ppg treated brine @ 3.0 bpm followed by 182 bbls of diesel at 2 .3 bpm. RD hardline on tree, RU lubricator and drop setting ball and rod. RD lubricator and RU h ardline to tree. Set packer @ 9197', test tubing to 3600 psi for 30 min, final pressure 3351 psi. Test 7" x 4.5" annulus to 3533 psi for 30 min, final pressure 3442 psi. RD Circ manifold and lines, RU lubricator a nd install BPV, RD lubricator and secure wel Ihead. Released Rig from CD2-15 @ 1030 ho urs. - Printed: 1/11/2002 3:25:36 PM = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00104 Sidetrack No. Page ~ of 7 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/15 PB#1 115 PB#2/15 Survey Section Name CD2-15 PB#1 MWD BHI Rep. HARSTAD 1 BALLOU I NTJEQ. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1715.67 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. E/W Slot Coord. E/W -1544.32 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100tt~ 3OmO 10mO Vert. Sec. Azim. 292.61 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Inct. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) 1 S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (Fl) (Fl) (FT) (Fl) (Per 100 Fl) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT ~ - OS-OCT -01 MWD 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 OS-OCT -01 MWD 349.00 0.50 285.00 235.00 349.00 1.02 0.27 -0.99 0.21 0.21 OS-OCT -01 MWD 484.25 1.82 278.90 135.25 484.22 3.69 0.75 -3.68 0.98 0.98 OS-OCT -01 MWD 575.19 3.88 271 .41 90.94 575.04 7.96 1.05 -8.19 2.30 2.27 OS-OCT -01 MWD 664.56 6.57 277.76 89.37 664.03 15.72 1.81 -16.28 3.07 3.01 7.11 0S-OCT-01 MWD 754.93 7.78 279.21 90.37 753.69 26.67 3.49 -27.44 1.35 1.34 1.60 OS-OCT -01 MWD 845.30 9.36 285.96 90.37 843.05 39.92 6.49 -40.54 2.07 1.75 7.47 OS-OCT -01 MWD 934.57 10.41 287.94 89.27 931.00 55.17 10.97 -55.19 1.24 1.18 2.22 05-0CT -01 MWD 1029.08 12.96 288.99 94.51 1023.54 74.26 17.05 -73.34 2.71 2.70 1.11 OS-OCT -01 MWD 1124.04 16.52 292 . 08 94.96 1115.36 98.40 25.59 -95.93 3.84 3.75 3.25 OS-OCT -01 MWD 1216.66 17.08 292.69 92.62 1204.03 125.17 35.79 -120.68 0.63 0.60 0.66 OS-OCT -01 MWD 1313.42 18.30 293.77 96.76 1296.21 154.56 47.40 -147.69 1.31 1.26 1.12 ..-.. -- OS-OCT -01 MWD 1406.06 21.41 294 . 99 92.64 1383.33 186.01 6Ó..4O -176.34 3.39 3.36 1.32 0S-OCT-01 MWD 1502.71 22.40 290.35 96.65 1473.01 222.04 74.26 -209.59 2.06 1.02 -4.80 0S-OCT-01 MWD 1596.95' 25.08 289.88 94.24 1559.27 259.94 87.30 -245.22 2.85 2.84 -0.50 OS-OCT -01 MWD 1693.91 28.26 290.07 96.96 1645.90 303.41 102.17 -286.12 3.28 3.28 0.20 OS-OCT -01 MWD 1789.31 31.48 292.47 95.40 1728.62 350.89 119.45 -330.36 3.60 3.38 2.52 OS-OCT -01 MWD 1883.31 35.98 294.52 94.00 1806.78 403.06 140.30 -378.19 4.94 4.79 2.18 06-0CT-01 MWD 1981.74 39.65 291.30 98.43 1884.53 463.38 163.71 -433.78 4.23 .3.73 -3.27 -#' 06-0CT-O1 MWD 2077.02 41.90 288.61 95.28 1956.69 525.52 184.91 -492.27 3.00 2.36 -2.82 06-0CT -01 MWD 2172.62 44.61 289.63 95.60 2026.31. 590.90 206.38 -554.15 2.93 2.83 1.07 06-0CT -01 MWD 2268.06 44.83 290.77 95.44 2094.13 658.00 229.57 -617.17 0.87 0.23 1.19 06-0CT-01 MWD 2362.88 44.15 291.66 94.82 2161.77 724.42 253.61 -679.12 0.97 -0.72 0.94 ..-. .-. -- ...- .- ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00104 Sidetrack No. Page 2 of 7 ---- - Company PHILLIPS ALð..SKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/15 PB#1 / 15 PB#2 / 15 Survey Section Name CD2-15 PB#1 MWD BHI Rep. HARSTAD / BALLOU I N'TEQ. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1715.67 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. E/W Slot Coord. E/W -1544.32 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim. 292.61 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / See) E(+) / We-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (per 100 FT) Drop (-) Left (-) 0S-OCT-01 MWD 2458.02 43.35 292.55 95.14 2230.49 790.21 278.37 -740.07 1.06 -0.84 0.94 ~ - OS-OCT-01 MWD 2552.17 44.73 290.62 94.15 2298.17 855 . 64 302 . 43 -800.93 2.04 1.47 -2.05 06-0CT-01 MWD 2613.57 45.35 289.80 61.40 2341.56 899.05 317.44 -841.70 1.38 1.01 -1.34 OB-OCT -01 MWD 2726.73 44.38 290.84 113.16 2421.77 978.81 345.15 -916.56 1.07 -0.86 0.92 08-0CT-01 MWD 2820.34 44.36 289.69 93.61 2488.68 1044.21 367.82 -977.96 0.86 -0.02 -1.23 0B-OCT-01 MWD 2918.71 44.54 288.86 98.37 2558.91 1112.98 390.56 -1 042.99 0.62 0.18 -0.84 08-0CT -01 MWD 3015.11 44.95 289.35 96.40 2627.37 1180.72 412.77 -1107.11 0.56 0.43 0.51 0B-OCT-01 MWD 3106.39 45.05 287.88 91.28 2691 .92 1245.10 433.37 -1168.28 1.14 0.11 -1.61 08-0CT-O1 MWD 3207.32 45.28 289.00 100.93 2763.08 1316.48 456.01 -1236.17 0.82 0.23 1.11 OS-OCT -01 MWD 3302.79 45.55 289.05 95.47 2830.10 1384.34 478.18 - -1300.45 0.29 0.28 0.05 09-0CT-01 MWD 3398.14 45.85 288.22 95.35 2896.69 1452.42 499.98 -1365.12 0.70 0.31 -0.87 09-0CT -01 MWD 3491 .84 42.29 287.92 93.70 2964.01 1517.38 520.20 -1427.06 3.81 -3.80 -0.32 09-0CT-01 MWD 3589.25 42.43 288.65 97.41 3035.99 1582.82 540.79 -1489.38 0.53 0.14 0.75 ..-.. - -.- 09-0CT-01 .MWD 3684.69 42.39 287.88 95.44 3106.45 1647.00 560.97 -1550.50 0.55 -0.04 -0.81 09-0CT;.Q1 MWD 3779.94 42.35 284.01 95.25 3176.84 1710.73 578.59 -1612.20 2.74 -0.04 -4.06 09-0CT-01 MWD 3875.33 42.23 285.70 95.39 3247.40 1774.33 595.05 -1674.24 1.20 -0.13 1.77 09-0CT -01 MWD 3969.59 42.70 287.90 94.26 3316.94 1837.63 613.44 -1735.15 1.65 0.50 2.33 09-0CT-01 MWD 4066.53 44.37 291.01 96.94 3387.22 1904.29 635.70 -1798.08 2.80 1.72 3.21 09-0CT-01 MWD 4160.23 44.29 291 .43 93.70 3454.25 1969.74 659.40 -1859.12 0.32 -0.09 0.45 09-0CT-01 MWD 4254.81 44.22 292.28 94.58 3521 .99 2035.74 683.97 -1920.38 0.63 -0.07 0.90 09-0CT-01 MWD 4350.81 44.09 292.36 96.00 3590.87 2102.61 709;37 -1982.24 0.15 -0.14 0.08 09-0CT-O1 MWD 4444.99 43.90 291.53 94.18 3658.62 2168.02 733.82 -2042.92 0.64 -0.20 -0.88 09-0CT-01 MWD 4542.14 43.50 290.82 97.15 3728.86 2235.12 758.06 -2105.50 0.65 -0.41 -0.73 09-0CT -01 MWD 4637.31 45.49 291 .09 95.17 3796.74 2301.79 781.92 -2167.79 2.10 2.09 0.28 - 1- ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00104 Sidetrack No. Page ~ of 7 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/15 PB#1 /15 PB#2/15 Survey Section Name CD2-15 PB#1 MWD BHIRep. HARSTAD/BALLOU 'NTEQ. WELL DATA Target TVD (Fi) Target Coord. N/S Slot Coord. N/S -1715.67 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. ENI Slot Coord. ENI -1544.32 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Builcl\Walk\DL per: 1 00ft~ 30mD 10mD Vert. Sec. Azim. 292.61 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Inct. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Fl) (DD) (DD) (Fl) (Fl) (Fl) (Fl) (per 100 Fi) Drop (-) Left (-) 09-0CT -01 MWD 4731 .85 45.27 291 .86 94.54 3863.15 2369.07 806.55 -2230.41 0.62 -0.23 0.81 --.., - 09-0CT -01 MWD 4825.00 45.36 291.74 93.15 3928.65 2435.29 831 .15 -2291.90 0.13 0.10 -0.13 09-0CT -01 MWD 4919.32 45.24 290.23 94.32 3995.00 2502.30 855.15 -2354.49 1.15 -0.13 -1.60 09-0CT-01 MWD 5018.28 45.18 290.14 98.96 4064.72 2572.47 879.39 -2420.41 0.09 -0.06 -0.09 09-0CT-O1 MWD 5108.84 45.40 290.31 90.56 4128.43 2636.77 901 .64 -2480.80 0.28 0.24 0.19 09-0CT -01 MWD 5209.88 44.90 289.09 101.04 4199.69 2708.31 925.79 -2548.23 0.99 -0.49 -1.21 09-0CT -01 MWD 5304.59 45.19 288.52 94.71 4266.60 2775.18 947.39 -2611.68 0.52 0.31 -0.60 09-0CT -01 MWD 5400.39 45.30 288.69 95.80 4334.06 2843.05 969.10 -2676.15 0.17 0.11 0.18 09-0CT -01 MWD 5497.08 45.18 289.08 96.69 4402.14 2911 .56 991 .32 -2741.11 0.31 -0.12 0.40 1 O-OCT -01 MWD 5595.38 45.11 287.66 98.30 4471.47 2981 .05 1013.28 -2807.24 1.03 -0.07 -1.44 1 o-OCT -01 MWD 5690.40 44.88 286.11 95.02 4538.67 3047.89 1032.79 -2871.53 1.18 -0.24 -1.63 1 O-OCT -01 MWD 5786.03 45.78 287.08 95.63 4605.90 3115.52 1052.22 -2936.70 1.19 0.94 1.01 1 O-OCT -01 MWD 5881.51 45.59 285.65 95.48 4672.60 3183.43 1071 .47 -3002.24 1.09 -0.20 -1.50 --.. ~ 1 O-OCT -Õ1 MWD 5976.92 45.68 286.35 95.41 4739.32 3251.19 1090.27 -3067.81 0.53 0.09 0.73 1 O-OCT-01 MWD 6072.36 45.42 291 .52 95.44 4806.18 3319.13 1112.36 -3132.21 3.88 -0.27 5.42 1 O-OCT -01 MWD 6168.08 45.41 292.17 95.72 4873.37 3387.30 1137.72 -3195.49 0.48 -0.01 0.68 1 o-OCT -01 MWD 6263.76 45.29 290.55 95.68 4940.61 3455.35 1162.51 -3258.88 1.21 -0.13 -1.69 1 O-OCT-01 MWD 6357.39 45.21 289.78 93.63 5006 . 53 3521.78 1185.44 -3321 .29 0.59 -0.09 -0.82 1 o-OCT -01 MWD 6454.75 45.00 290.03 97.36 5075.25 3590.67 1208.92 -3386.14 0.28 -0.22 0.26 1 O-OCT -01 MWD 6547.93 44.65 289.61 93.18 5141.34 3656.28 1231.19 -3447.94 0.49 -0.38 -0.45 1 O-OCT -01 MWD 6637.64 44.52 290.00 89.71 5205.23 3719.18 1252.53 -3507.19 0.34 -0.14 0.43 10-0CT-01 MWD 6735.04 44.13 288.67 97.40 5274.91 3787.12 1275.06 -3571.40 1.03 -0.40 -1.37 10-0CT-01 MWD 6832.86 43.56 289.30 97.82 5345.46 3854.74 1297.10 -3635.48 0.73 -0.58 0.64 1 O-OCT-01 MWD 6929.29 43.45 288.10 96.43 5415.40 3920.97 1318.38 -3698.35 0.86 -0.11 -1.24 , - - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00104 Sidetrack No. Page ~ of 7 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field AL,PINE FIELD Well Name & No. PAD CD#2/15 PB#1 /15 PB#2/15 Survey Section Name CD2-15 PB#1 MWD BHIRep. HARSTAD/BALLOU I NTEQ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1715.67 Grid Correction 0.000 Depths Measured From: RKB~ MSLO ssO Target Description Target Coord. E/W Slot Coord. E/W -1544.32 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 3OmO 10mO Vert. See, Azim. 292.61 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (per 100 FT) Drop (-) Left (-) 10-0CT-01 MWD 7023.89 44.46 289.12 94.60 5483.50 3986.47 .1339.34 -3760.58 1.30 1.07 1.08 ~ - 10-0CT -01 MWD 7120.41 44.36 288.26 96.52 5552.45 4053.85 1360.99 -3824.56 0.63 -0.10 -0.89 1 O-OCT -01 MWD 7214.19 44.20 287.31 93.78 5619.59 4119.09 1380.99 -3886.90 0.73 -0.17 -1.01 1 O-OCT -01 MWD 7313.39 43.82 287.47 99.20 5690.94 4187.73 1401 .59 -3952.67 0.40 -0.38 0.16 1 O-OCT -01 MWD 7408.96 44.64 287.89 95.57 5759.42 4254.15 1421.83 -4016.19 0.91 0.86 0.44 11-0CT -01 MWD 7502.73 44.82 288.30 93.77 5826.04 4319.94 1442.33 -4078.91 0.36 0.19 0.44 11-0CT -01 MWD 7600.69 44.65 288.03 97.96 5895.63 4388.67 1463.82 -4144.43 0.26 -0.17 -0.28 11-0CT -01 MWD 7695.57 44.07 288.25 94.88 5963.46 4454.81 1484.48 -4207.46 0.63 -0.61 0.23 11-0CT -01 MWD 7791 .05 44.63 288.95 95.48 6031.74 4521.39 1505.77 -4270.72 0.78 0.59 0.73 11-0CT -01 MWD 7886.65 44.35 288.60 95.60 6099.94 4588.23 1527.33 -4334.15 0.39 -0.29 -0.37 11-0CT -01 MWD 7982.33 44.15 288.29 95.68 6168.47 4654.82 - 1548.45- -4397.49 0.31 -0.21 -0.32 11-0CT -01 MWD 8078.09 44.17 287.80 -95.76 6237.17 4721.32 1569.12 -4460 . 92 0.36 0.02 -0.51 11-0CT -01 MWD 8173.23 45.04 290.06 95.14 6304.91 4787.98 1590.80 -4524.10 1.90 0.91 2.38 --- -'- 11-0CT-O1 MWD 8268.09 45.38 289.90 94.86 6371.74 4855.24 1613.80 -4587.37 0.38 0.36 -0.17 11-0CT-01 MWD 8362.25 44.97 290.30 94.16 6438.12 4921 .96 1638.75 -4650.09 0.53 -0.44 0.42 11-0CT-01 MWD 8459.24 44.58 289.18 96.99 6506.97 4990.18 1659.83 -4714.38 0.91 -0.40 -1.15 11-0CT -01 MWD 8554.52 44.68 288.36 95.28 6574.78 5056.96 1681.36 -4777.76 0.61 0.10 -0.86 11-0CT -01 MWD 8648.52 45.15 288.79 94.00 6641.34 5123.17 1702.51 -4840.67 0.60 0.50 0.46 11-0CT -01 MWD 8745.62 45.17 288.28 97.10 6709.81 5191 .85 1724.39 -4905.95 0.37 0.02 -0.53 11-0CT -01 MWD 8840.13 45.08 288.27 94.51 6776.49 5258.63 1745.39 -4969.54 0.10 -0.10 -0.01 12-0CT-01 MWD 8935.79 45.75 289.59 95.66 6843 . 64 5326.62 1767.50 -5033.99 1.21 0.70 1.38 12-0CT -01 MWD 8960.53 47.50 291.99 24.74 S86O . 64 5344.59 1773.89 -5050.79 9.99 7.07 9.70 12-0CT-01 MWD 9002.06 49.17 292.50 41.53 6888.24 5375.61 1785.63 -5079.51 4.12 4.02 1.23 12-0CT -01 MWD 9031.74 49.56 294.29 29.68 6907.57 5398.13 1794.58 -5100.18 4.76 1.31 6.03 ~ - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00104 Sidetrack No. Page ~ of 7 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/15 PB#1 /15 PB#2/15 Survey Section Name CD2-15 PB#1 MWD BHIRep. HARSTAD/BALLOU , NTEQ. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1715.67 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. EIW Slot Coord. E/W -1544.32 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 3OmD 10mD Vert. Sec. Azim. 292.61 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (F1) (FT) (Ff) (Fl) (per 100 F1) Drop (-) Left (-) 12-0CT -01 MWD 9061.55 51.67 296.63 29.81 6926.49 5421 .14 1804.48 -5120.97 9.32 7.08 7.85 ~ - 12-0CT -01 MWD 9093.81 52.79 297.51 32.26 6946.25 5446.56 1816.09 -5143.68 4.09 3.47 2.73 12-0CT -01 MWD 9125.67 52.91 300.49 31.86 6965.49 5471.79 1828.40 -5165.88 7.46 0.38 9.35 12-0CT-O1 MWD 9157.54 53.25 303.68 31.87 6984.64 5496.92 1841.93 -5187.47 8.07 1.07 10.01 12-0CT -01 MWD 9188.98 53.82 305.98 31.44 7003.33 5521 .62 1856.37 -5208.22 6.16 1.81 7.32 12-0CT -01 MWD 9222.79 55.25 308.21 33.81 7022.94 5548.28 1872.98 -5230.18 6.84 4.23 6.60 12-0CT -01 MWD 9253.36 56.27 309.63 30.57 7040.14 5572.53 1888.86 -5249.84 5.09 3.34 4.65 12-0CT -01 MWD 9286.28 57.39 310.89 32.92 7058.16 5598.79 1906.67 -5270.86 4.67 3.40 3.83 12-0CT -01 MWD 9318.51 58.70 312.48 32.23 7075.21 5624.63 1924.86 -5291 .28 5.83 4.06 4.93 12-0CT -01 MWD 9349.46 60.38 313.47 30.95 7090.90 5649.64 1943.04 -5310.80 6.09 5.43 3.20 12-0CT -01 MWD 9380.83 62.82 315.23 31.37 7105.82 5675.27 1962.33 -5330.52 9.21 7.78 5.61 12-0CT -01 MWD 9414.01 65.17 315.37 33.18 7120.37 5702.78 1983.53 -5351.50 7.09 7.08 0.42 12-0CT -01 MWD 9445.86 65.85 316.74 31.85 7133.57 5729.37 2004.40 -5371 .61 4.46 2.13 4.30 --- '- 12-0CT -01 MWD 9478.00 67.07 317.41 32.14 7146.41 5756.19 2025.97 -5391.68 .4.25 3.80 2.08 12-0CT -01 MWD 9509.40 68.89 320.21 31.40 7158.18 5782.30 2047.88 -5410.84 10.10 5.80 8.92 12-0CT-O1 MWD 9540.03 70.57 321.58 30.63 7168.80 5807.60 2070.18 -5428.96 6.91 5.48 4.47 12-0CT -01 MWD 9571.22 72.15 321 .57 31.19 7178.76 5833.46 2093.33 -5447.33 5.07 5.07 -0.03 13-0CT -01 MWD 9601 .32 73.72 322.61 30.10 7187.60 5858.50 2116.03 -5465.01 6.17 5.22 3.46 13-0CT -01 MWD 9636.40 75.17 324.53 35.08 7197.01 5887.48 2143.22 -5485.07 6.70 4.13 5.47 13-0CT -01 MWD 9668.22 76.49 325.79 31.82 7204.79 5913.49 2168.54 -5502.70 5.65 4.15 3.96 13-0CT-O1 MWD 9700.48 78.56 325.78 32.26 7211.76 5939.85 2194.59 -5520.41 6.42 6.42 -0.03 13-0CT -01 MWD 9737.05 79.16 326.27 38.57 7218.83 5989.80 2224.34 -5540.46 2.10 1.64 1.34 13-0CT -01 MWD 9774.45 80.65 328.17 37.40 7225.38 6000.10 2255.30 -5560.39 6.39 3.98 5.08 16-0CT -01 MWD 9864.09 86.55 329.08 89.64 7235.37 6072.12 2331.32 -5606.75 6.66 6.58 1.02 - - - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00104 Sidetrack No. Page 6 of 7 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/15 PB#1 /15 PB#2/15 Survey Section Name CD2-15 PB#1 MWD BHIRep. HARSTAD/BALLOU I NTEQ WELL DATA TargetTVD (FT) Target Coord. N/S Slot Coord. N/S -1715.67 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSO Target Description Target Coord. E/W Slot Coord. E/W -1544.32 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (CD) Build\Walk\DL per: 100ft~ 3OmD 1OmD Vert. Sec. Azim. 292.61 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical Build (+) Right (+) Comment Depth Angle Direction Length TVD Section N(+) I S(-) E(+) I W(-) DL Type (F1) (CD) (DD) (F1) (F1) (F1) (F1) (per 100 FT) Drop (-) Left (-) 17-0CT-O1 MWD 9894.96 89.02 330.71 30.87 7236.57 6096.66 2358.00 -5622.22 9.58 8.00 5.28 r.-", - 17-0CT -01 MWD 9957.97 92.58 334.95 63.01 7235.69 6144.75 2414.03 -5650.98 8.79 5.65 6.73 17 -OCT -01 MWD 9989.90 92.65 335.32 31.93 7234.23 6168.26 2442.97 -5664.39 1.18 0.22 1.16 17-0CT -01 MWD 10018.54 92.46 334 . 88 28.64 7232.95 6189.35 2468.92 -5676.43 1.67 -0.66 -1.54 17 -OCT -01 MWD 10115.88 92.15 333.11 97.34 7229.04 6262.33 2556.33 -5719.08 1.84 -0.32 -1.82 17-0CT -01 MWD 10212.74 91.72 333.69 96.86 7225.77 6335.62 2642.89 -5762.42 0.75 -0.44 0.60 17 -OCT -01 MWD 10308.92 91.35 333.31 96.18 7223.19 6408.30 2728.94 -5805.32 0.55 -0.38 -0.40 17-0CT-O1 MWD 10404.61 93.75 335.44 95.69 7218.93 6479.59 2815.12 -5846.66 3.35 2.51 2.23 17-0CT-O1 MWD 10500.30 93.69 333.96 95.69 7212.72 6550.45 2901.44 -5887.47 1.54 -0.06 -1.55 17-0CT-O1 MWD 10595.99 90.68 332.69 95.69 7209.08 6622.92 2986 . 88 -5930.39 3.41 -3.15 -1.33 17-0CT-O1 MWD 10690.47 89.75 331.58 94.48 7208.72 6695.80 3070.40 -5974.55 1.53 -0.98 -1.17 17-0CT-O1 MWD 10785.74 91.66 331 .66 95.27 7207.55 6769.82 3154.21 -6019.83 2.01 2.00 0.08 17-0CT-O1 MWD 10881.42 92.52 330.73 95.68 7204.06 6844.56 3237.99 -6065.90 1.32 0.90 -0.97 ...-.~. - 18-0CT -ó1 MWD 10969.20 92.28 329.36 87.78 7200.38 6914.19 3313.98 -6109.69 1.58 -0.27 -1.56 18-0CT -01 MWD 11069.39 92.15 331.01 100.19 7196.51 6993.54 3400.84 -6159.46 1.65 -0.13 1.65 18-0CT -01 MWD 11163.57 90.31 330.81 94.18 7194.49 7067.43 3483.11 -6205.24 1.97 -1.95 -0.21 18-0CT -01 MWD 11257.04 90.18 329.68 93.47 7194.09 7141.45 3564.26 -6251 .63 1.22 -0.14 -1.21 18-0CT -01 MWD 11354.39 90.12 329.77 .97.35 7193.84 7219.07 3648.33 -6300.70 0.11 -0.06 0.09 18-0CT -01 MWD 11451.86 90.18 331.53 97.47 7193.58 7295.84 3733.29 -6348.48 1.81 0.06 1.81 18-0CT -01 MWD 11548.82 90.25 330.76 96.96 7193.22 7371 .68 3818.21 -6395.27 0.80 0.07 -0.79 18-0CT -01 MWD 11644.00 89.51 331.51 95.18 7193.42 7446.14 3901 .56 -6441 .21 1.11 -0.78 0.79 18-0CT -01 MWD 11741.03 90.37 331.57 97.03 7193.52 7521.62 3986.86 -6487.45 0.89 0.89 0.06 18-0CT -01 MWD 11836.67 91.91 332.72 95.64 7191 .61 7595.37 4071 .40 -6532.13 2.01 1.61 1.20 18-0CT-01 MWD 11931.71 91.85 332.42 95.04 7188.50 7668.17 4155.71 -6575.89 0.32 -0.06 -0.32 - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00104 Sidetrack No. Page ~ of 7 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/15 PB#1 115 PB#2/15 Survey Section Name CD2-15 PB#1 MWD BHI Rep. HARSTAD 1 BALLOU , NT'EQ WELL DATA Target TVD (Fl) Target Coord. NIS Slot Coord. N/S -1715.67 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO ssO Target Description Target Coord. E/W Slot Coord. E/W -1544.32 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 30mD 10mD Vert. Sec. Azim. 292.61 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (per 100 Fl) Drop (-) Left (-) 1 ~OCT-01 MWD 12027.14 91.60 333.67 95.43 7185.62 7740.77 4240.73 -6619.12 1.34 -0.26 1.31 ~ - 1 ~OCT -01 MWD 12117.94 91.54 332.64 90.80 7183.14 7809.75 4321.72 -6660.11 1.14 -0.07 -1.13 . 1 ~OCT -01 MWD 12216.76 92.40 333.76 98.82 7179.74 7884.74 4409.87 -6704.64 1.43 0.87 1.13 2Q-OCT -01 MWD 12273.00 92.40 333.76 56.24 7177.38 7927.05 4460.27 -6729.48 0.00 - 0.00 0.00 Projected Data - NO SURVEY -c- .. -- - "'- - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00104 Sidetrack No.1 Page ~ of 1 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/15 PB#1 115 PB#2/15 Survey Section Name CD2-15 PB#2 MWD BHI Rep. HARSTAD 1 BALLOU , NJ"EQ WELL DATA Target lVD (FT) Target Coord. N/S Slot Coord. N/S -1715.67 Grid Correction 0.000 Depths Measured From: RKB gJ MSLO SSO Target Description Target Coord. E/W Slot Coord. E/W -1544.32 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (00) Build\Walk\DL per: 100ft~ 3OmO 10mO Vert. Sec. Azim. 331.88 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical Build (+) Right (+) Comment Depth Angle Direction Length IVD Section N(+) 1 S(-) E(+) IW(-) DL Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (per 100 FT) Drop (-) Left (-) MWD 11806.00 91 .42 332.35 7192.50 6639.89 4044.20 -6517.99 TIE IN POINT ~ - 23-0CT -01 MWD 11865.38 88.15 330.81 59.38 7192.72 6698.26 4096.41 -6546.25 6.09 -5.51 -2.59 23-0CT -01 MWD 11962.93 90.43 329.38 97.55 7193.93 6795.75 4180.96 -6594:87 2.76 2.34 -1.47 23-0CT -01 MWD 12058.30 90.98 330.69 95.37 7192.76 6891.06 4263.58 -6642.50 1.49 0.58 1.37 23-0CT -01 MWD 12153.85 91.66 329.82 95.55 7190.56 6986.54 4346.51 -6689.90 1.16 0.71 -0.91 23-0CT -01 MWD 12249.83 90.00 332.72 95.98 7189.17 7082.49 4430.66 -6736.02 3.48 -1.73 3.02 23-0CT -01 MWD 12345.47 89.82 332.74 95.64 7189.32 7178.12 4515.67 -6779.84 0.19 -0.19 0.02 23-0CT -01 MWD 12440.91 90.18 333.18 95.44 7189.32 7273.55 4600.67 -6823.23 0.60 0.38 0.46 23-0CT -01 MWD 12535.36 90.31 332.85 94.45 7188.91 7367.98 4684.84 -6866 . 09 0.38 0.14 -0.35 23-0CT -01 MWD 12631 .41 90.43 331.92 96.05 7188.29 7464.02 4769.94 -6910.61 0.98 0.12 -0.97 23-0CT -01 MWD 12721.17 90.74 332.87 89.76 7187.38 7553.77 4849.48 -6952.20 1.11 0.35 1.06 24-0CT -01 MWD 12821 .58 91.11 332.12 100.41 7185.76 7654.16 4938.53 -6998.56 0.83 0.37 -0.75 24-0CT -01 MWD 12917.21 91.78 332.96 95.63 7183.34 7749.75 5023.36 -7042.64 1.12 0.70 0.88 ~,- 24-0CT -Õ1 MWD 13013.12 87.66 332.17 95.91 7183.81 7845.63 5108.46 -7086.82 4.37 -4.30 -0.82 24-0CT -01 MWD 13108.75 90.18 330.88 95.63 7185.61 7941.24 5192.50 -7132.41 2.96 2.64 -1.35 24-0CT -01 MWD 13204.71 91.29 331.97 95.96 7184.38 8037.18 5276.76 -7178.30 1.62 1.16 1.14 24-0CT -01 MWD 13298.77 89.14 333 . 53 94.06 7184.03 8131.22 5360.37 -7221.36 2.82 -2.29 1.66 25-0CT -01 MWD 13395.25 86.74 332.64 96.48 7187.50 8227.61 5446.34 -7265.00 2.65 -2.49 -0.92 25-0CT -01 MWD 13490.03 89.94 332.41 94.78 7190.24 8322.33 5530.38 -7308.71 3.38 3.38 -0.24 25-0CT-01 MWD 13584.61 90.31 332.26 94.58 7190.04 8416.91 5614.15 -7352.62 0.42 0.39 -0.16 25-0CT-01 MWD 13681.51 90.92 332.50 96.90 7189.00 8513.80 5700.00 -7397.54 0.68 0.63 0.25 25-0CT -01 MWD 13715.86 91.05 333.30 34.35 7188.41 8548.14 5730.58 -7413.19 2.36 0.38 2.33 25-0CT-01 MWD 13776.00 90.50 333.30 60.14 7187.59 8608.25 5784.30 -7440.21 0.91 -0.91 0.00 Projected Data - NO SURVEY - - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00104 Sidetrack No.2 Page ~ of 1 -- Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/15 PB#1 115 PB#2/15 SUlvey Section Name CD2-15 MWD BHI Rep. HARSTAD 1 BALLOU , NTI!Q WELL DATA Target TVD (F1) Target Coord. N/S Slot Coord. N/S -1715.67 Grid Correction 0.000 Depths Measured From: RKB gj MSLD ssD Target Description Target Coord. E/W Slot Coord. E/W -1544.32 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 1 00ft~ 3OmD 10mD Vert. Sec. Azim. 331.88 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) 1 S(-) E(+) ¡W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DD) (FT) (Fl") (F1) (F1) (Per 100 Fl") Drop (-) Left (-) MWD 13450.00 88.59 332.51 7189.74 8283.31 5494.90 -7290.19 TIE IN POINT --.. ~- 27-0CT -01 MWD 13490.23 86.55 329.88 40.23 7191 .45 8322.50 5530.12 -7309.55 8.26 -5.07 -6.53 27-0CT -01 MWD 13586.02 86.37 328.86 95.79 7197.36 8418.01 5612.38 -7358.26 1.08 -0.19 -1.06 27-0CT-01 MWD 13682.16 86.68 329.88 96.14 7203.19 8513.88 5694.95 -7407.16 1.11' 0.32 1.06 27-0CT -01 MWD 13777.39 86.80 329.34 95.23 7208.60 8608.88 5776.97 -7455.25 0.58 0.13 -0.57 27-0CT -01 MWD 13871.47 87.41 330.74 94.08 7213.36 8702.79 5858.37 -7502.17 1.62 0.65 1.49 27-0CT-O1 MWD 13967.60 87.41 329.10 96.13 7217.70 8798.76 5941.46 -7550.30 1.70 0.00 -1.71 28-0CT -01 MWD 14061.22 86.98 331.03 93.62 7222.28 8892.22 6022.49 -7596.96 2.11 -0.46 2.06 28-0CT -01 MWD 14100.85 86.98 331.47 39.63 7224.37 8931.79 6057.19 -7616.00 1.11 0.00 1.11 28-0CT -01 MWD 14161.00 86.98 331.47 60.15 7227.54 8991 .85 6109.96 -7644.69 0.00 0.00 0.00 Projected Data - NO SURVEY .-.. ',- - { AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well CD2-15PB2 ~ OJ---/5CJ Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,741.03' MD Window / Kickoff Survey 11,806.00' MD Projected Survey: 13,776.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ( 12-Nov-O1 RE(;E"/ED NOV 1 :5 2001 Alaska Oil & Gas Cons, Commî$Sion I~n(;~~orage 0- UJ ~ ~ - I (J ~ D EFI N ITIVE '--- Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-15 CD2-15PB2 Job No. AKMM11163, Surveyed: 25 October, 2001 ~~-- SURVEY REPORT 9 November, 2001 Your Ref: 501032038671 Surface Coordinates: 5974641.66 N, 371696.24 E (70020' 20.2250H N, 151002' 28.0829" W) Surface Coordinates relative to Project H Reference: 974641.66 N, 128303.76 W (Grid) Surface Coordinates relative to Structure: 198.36 N, 24.65 W (True) Kelly Bushing: 52. 42ft above Mean Sea Level ~.~ 55 P E!"""-' Y - 55 U .., DRILLING SERVices A HaHlburton Company Survey Ref: svy9688 Sperry-Sun Drilling Services Survey Report for CD2-15PB2 Your Ref: 501032038671 Job No. AKMM11163, SulVeyed: 25 October, 2001 . North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings NO~ Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ð/1 OOft) . 11741.03 90.370 331.570 7141.09 7193.51 3986.87 N 6487.46 W 5978738.96 N 365277.95 E 6573.94 Tie on Point 11806.00 91.420 332.350 7140.07 7192.49 4044.21 N 6518.00 W 5978796.81 N 365248.40 E 2.013 6638.90 Window Point 11865.38 88.150 330.810 7140.29 7192.71 4096.42 N 6546.25 W 5978849.50 N 365221.04 E 6.087 6698.27 11962.93 90.430 329.380 7141.50 7193.92 4180.97 N 6594.88 W 5978934.86 N 365173.87 E 2.759 6795.76 12058.30 90.980 330.690 7140.33 7192.75 4263.58 N 6642.51 W 5979018.28 N 365127.66 E 1.490 6891.07 ~ 12153.85 91.660 329.820 7138.13 7190.55 4346.52 N 6689.90 W 5979102.02 N 365081.69 E 1.155 6986.55 12249.83 90.000 332.720 7136.74 7189.16 4430.66 N 6736.03 W 5979186.94 N 365037.01 E 3.481 7082.50 12345.47 89.820 332.740 7136.89 7189.31 4515.67 N 6779.85 W 5979272.68 N 364994.65 E 0.189 7178.13 12440.91 90.180 333.180 7136.89 7189.31 4600.68 N 6823.24 W 5979358.42 N 364952.73 E 0.596 7273.55 12535.36 90.310 332.850 7136.48 7188.90 4684.85 N 6866.09 W 5979443.31 N 364911.32 E 0.376 7367.98 12631.41 90.430 331.920 7135.86 7188.28 4769.95 N 6910.61 W 5979529.16 N 364868.26 E 0.976 7464.03 12721.17 90.740 332.870 7134.95 7187.37 4849.49 N 6952.20 W 5979609.40 N 364828.04 E 1.113 7553.78 12821.58 91.110 332.120 7133.33 7185.75 4938.54 N 6998.57 W 5979699.23 N 364783.20 E 0.833 7654.17 12917.21 91.780 332.960 7130.91 7183.33 5023.37 N 7042.65 W 5979784.80 N 364740.58 E 1.123 7749.76 13013.12 87.660 332.170 7131.38 7183.80 5108.47 N 7086.83 W 5979870.65 N 364697.86 E 4.374 7845.64 13108.75 90.180 330.880 7133.19 7185.61 5192.51 N 7132.41 W 5979955.45 N 364653.72 E 2.960 7941.24 13204.71 91.290 331.970 7131.95 7184.37 5276.77 N 7178.31 W 5980040.49 N 364609.28 E 1.621 8037.19 13298.77 89.140 333.530 7131.60 7184.02 5360.38 N 7221.37 W 5980124.82 N 364567.65 E 2.824 8131.23 13395.25 86.740 332.640 7135.07 7187.49 5446.35 N 7265.01 W 5980211.52 N 364525.49 E 2.653 8227.62 13490.03 89.940 332.410 7137.81 7190.23 5530.39 N 7308.71 W 5980296.30 N 364483.23 E 3.385 8322.34 13584.61 90.310 332.260 7137.61 7190.03 5614.16 N 7352.63 W 5980380.81 N 364440.75 E 0.422 8416.92 "-'- 13681.51 90.920 332.500 7136.57 7188.99 5700.01 N 7397.55 W 5980467.42 N 364397.31 E 0.676 8513.81 13715.86 91.050 333.300 7135.98 7188.40 5730.58 N 7413.19 W 5980498.25 N 364382.19 E 2.359 8548.14 13776.00 91.050 333.300 7134.88 7187.30 5784.30 N 7440.21 W 5980552.43 N 364356.09 E 0.000 8608.26 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.208° (09-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 331.880° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13776.00ft., The Bottom Hole Displacement is 9424.17ft, in the Direction of 307.863° (True). -- - .. ... ""----. 9 November, 2001 - 14:46 Page 2 of 3 DrillQlIest 2.00.09.003 - Kuparuk River Unit Comments Measured Depth (ft) -.- 11741.03 11806.00 13776.00 '- Sperry-Sun Drilling Services Survey Report for CD2-15PB2 Your Ref: 501032038671 Job No. AKMM11163, SulVeyed: 25 October, 2001 . 3986.87 N 4044.21 N 5784.30 N Survey tool program for CD2-15PB2 North Slope, Alaska Alpine CD-2 Station Coordinates' TVD Northings Eastings (ft) (ft) (ft) 7193.51 7192.49 7187.30 From Measured Vertical Depth Depth (ft) (ft) 0.00 349.00 .~ 9 November, 2001 - 14:46 0.00 349.00 To Measured Vertical Depth Depth (ft) (ft) 349.00 13776.00 349.00 7187.30 Comment 6487.46 W 6518.00 W 7440.21 W Tie on Point Window Point Projected Survey Survey Tool Description Tolerable Gyro (CD2-15PB1) MWD Magnetic (CD2-15PB1) -- -- --.-- Page 3 of 3 DrillQlIest 2.00.09.003 ( ~.. AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well CD2-15PB1 d.OJ-/5, Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 0.00' MD Window / Kickoff Survey , MD Projected Survey: 12,273.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED NOV 1 3 2001 Alaska Oil & Gas Cons. CommiSSion Anctwrage 12-Nov-01 f¡ , . , ........ <J C\J D EFI N ITIVE - Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-15 CD2-15PB1 Job No. AKMM11163, Surveyed: 20 October, 2001 SURVEY REPORT 9 November, 2001 Your Ref: 501032038670 Surface Coordinates: 5974641.66 N, 371696.24 E (70020' 20.2250" N, 151002' 28.0829" W) Surface Coordinates relative to Project H Reference: 974641.66 N, 128303.76 W (Grid) Surface Coordinates relative to Structure: 198.36 N, 24.65 W (True) Kelly Bushing: 52.42ft above Mean Sea Level ,,~ 5peraraY-!5LJr1 DRILLING SERVices A Halliburton Company Survey Ref: svy9668 Sperry-Sun Drilling Services . Survey Report for CD2-15PB1 Your Ref: 501032038670 Job No. AKMM11163, Surveyed: 20 OctoberJ 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment eft) eft) eft) eft) (ft) (ft) (ft) (O /1 OOft) 0.00 0.000 0.000 -52.42 0.00 O.OON 0.00 E 5974641.66 N 371696.24 E 0.00 Tolerable Gyro 114.00 0.000 0.000 61.58 114.00 0.00 N O.OOE 5974641.66 N 371696.24 E 0.000 0.00 349.00 0.500 285.000 296.58 349.00 0.27 N 0.99W 5974641.94 N 371695.25 E 0.213 0.70 MWD Magnetic '- 484.25 1.820 278.900 431.80 484.22 0.75 N 3.68W 5974642.47 N 371692.57 E 0.979 2.40 575.19 3.880 271.410 522.62 575.04 1.05 N 8.19W 5974642.85 N 371688.07 E 2.297 4.78 '~ 664.56 6.570 277.760 611.61 664.03 1.81 N 16.28 W 5974643.75 N 371680.00 E 3.074 9.27 754.93 7.780 279.210 701.27 753.69 3.49 N 27.44 W 5974645.62 N 371668.87 E 1.354 16.01 845.30 9.360 285.960 790.63 843.05 6.49 N 40.54 W 5974648.84 N 371655.82 E 2.070 24.83 934.57 10.410 287.940 878.58 931.00 10.97 N 55.19 W 5974653.57 N 371641.24 E 1.236 35.69 1029.08 12.960 288.990 971.12 1023.54 17.05 N 73.34 W 5974659.96 N 371623.20 E 2.707 49.61 1124.04 16.520 292.080 1062.94 1115.36 25.59 N 95.93 W 5974668.89 N 371600.76 E 3.838 67.79 1216.66 17.080 292.690 1151.61 1204.03 35.79 N 120.68 W 5974679.51 N 371576.19 E 0.634 88.45 1313.42 18.300 293.770 1243.79 1296.21 47.40 N 147.69 W 5974691.58 N 371549.38 E 1.306 111.41 1406.06 21.410 294.990 1330.91 1383.33 60.40 N 176.34 W 5974705.07 N 371520.96 E 3.387 136.39 1502.71 22.400 290.350 1420.59 1473.01 74.26 N 209.60 W 5974719.50 N 371487.95 E 2.063 164.28 1596.95 25.080 289.880 1506.85 1559.27 87.30 N 245.22 W 5974733.14 N 371452.55 E 2.851 192.57 1693.91 28.260 290.070 1593.48 1645.90 102.17 N 286.12 W 5974748.71 N 371411.91 E 3.281 224.96 1789.31 31.480 292.470 1676.20 1728.62 119.45 N 330.36 W 5974766.74 N 371367.97 E 3.600 261.05 1883.31 35.980 294.520 1754.36 1806.78 140.30 N 378.19 W 5974788.41 N 371320.51 E 4.937 301.98 1981.74 39.650 291.300 1832.11 1884.53 163.71 N 433.78 W 5974812.77 N 371265.33 E 4.233 348.84 2077.02 41.900 288.610 1904.27 1956.69 184.91 N 492.26 W 5974834.97 N 371207.21 E 2.996 395.10 '- 2172.62 44.610 289.630 1973.89 2026.31 206.38 N 554.15 W 5974857.50 N 371145.70 E 2.927 443.20 2268.06 44.830 290.770 2041.71 2094.13 229.57 N 617.17 W 5974881.76 N 371083.09 E 0.872 493.36 2362.88 44.150 291.660 2109.35 2161.77 253.61 N 679.12 W 5974906.86 N 371021.56 E 0.973 543.76 2458.02 43.350 292.550 2178.07 2230.49 278.37 N 740.07 W 5974932.65 N 370961.04 E 1.061 594.32 2552.17 44.730 290.620 2245.75 2298.17 302.43 N 800.93 W 5974957.75 N 370900.60 E 2.044 644.22 2613.57 45.350 289.800 2289.14 2341.56 317.44 N 841.70 W 5974973.45 N 370860.10 E 1.383 676.68 2726.73 44.380 290.840 2369.35 2421.77 345.15 N 916.56 W 5975002.44 N 370785.72 E 1.075 736.40 2820.34 44.360 289.690 2436.26 2488.68 367.82 N 977.96 W 5975026.16 N 370724.71 E 0.859 785.34 2918.71 44.540 288.860 2506.49 2558.91 390.56 N 1042.99 W 5975050.01 N 370660.09 E 0.619 836.04 .0-- 9 November, 2001 - 14:50 Page 2 of 7 DrillOliest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for CD2-15PB1 Your Ref: 501032038670 Job No. AKMM11163, Surveyed: 20 October, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 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) (°/1 0 Oft) . 3015.11 44.950 289.350 2574.95 2627.37 412.77 N 1107.11 W 5975073.32 N 370596.35 E 0.556 885.85 3106.39 45.050 287.880 2639.50 2691.92 433.38 N 1168.28 W 5975094.96 N 370535.55 E 1.144 932.85 3207.32 45.280 289.000 2710.66 2763.08 456.02 N 1236.17W 5975118.76 N 370468.05 E 0.819 984.82 ~-~ 3302.79 45.550 289.050 2777.68 2830.10 478.18 N 1300.45 W 5975142.02 N 370404.16 E 0.285 1034.67 3398.14 45.850 288.220 2844.28 2896.70 499.98 N 1365.12 W 5975164.93 N 370339.88 E 0.698 1084.37 ~ 3491.84 42.290 287.920 2911.59 2964.01 520.20 N 1427.06 W 5975186.20 N 370278.29 E 3.806 1131.40 3589.25 42.430 288.650 2983.57 3035.99 540.79 N 1489.38 W 5975207.86 N 370216.33 E 0.525 1178.93 3684.69 42.390 287.880 3054.03 3106.45 560.97 N 1550.50 W 5975229.08 N 370155.56 E 0.546 1225.53 3779.94 42.350 284.010 3124.42 3176.84 578.60 N 1612.20 W 5975247.76 N 370094.18 E 2.738 1270.16 3875.33 42.230 285.700 3194.98 3247.40 595.05 N 1674.24 W 5975265.27 N 370032.43 E 1.199 1313.91 3969.59 42.700 287.900 3264.52 3316.94 613.44 N 1735.15 W 5975284.71 N 369971.84 E 1.653 1358.85 4066.53 44.370 291.010 3334.81 3387.23 635.70 N 1798.08 W 5975308.04 N 369909.30 E 2.802 1408.14 4160.23 44.290 291.430 3401.83 3454.25 659.40 N 1859.12W 5975332.78 N 369848.68 E 0.325 1457.81 4254.81 44.220 292.280 3469.57 3521.99 683.97 N 1920.38 W 5975358.39 N 369787.85 E 0.632 1508.35 4350.81 44.090 292.360 3538.45 3590.87 709.37 N 1982.24 W 5975384.84 N 369726.43 E 0.147 1559.91 4444.99 43.900 291.530 3606.20 3658.62 733.82 N 2042.92 W 5975410.33 N 369666.18 E 0.645 1610.07 4542.14 43.510 290.820 3676.43 3728.85 758.07 N 2105.51 W 5975435.64 N 369604.01 E 0.645 1660.95 4637.31 45.490 291.090 3744.31 3796.73 781.92 N 2167.80 W 5975460.56 N 369542.14 E 2.090 1711.35 4731.85 45.270 291.860 3810.72 3863.14 806.56 N 2230.42 W 5975486.26 N 369479.95 E 0.625 1762.59 4825.00 45.360 291.740 3876.22 3928.64 831.15 N 2291.91 W 5975511.91 N 369418.89 E 0.133 1813.27 4919.32 45.240 290.230 3942.57 3994.99 855.16 N 2354.50 W 5975536.98 N 369356.72 E 1.145 1863.94 5018.28 45.180 290.140 4012.28 4064.70 879.39 N 2420.42 W 5975562.34 N 369291.22 E 0.089 1916.38 --.~' 5108.84 45.400 290.310 4076.00 4128.42 901.64 N 2480.81 W 5975585.62 N 369231.22 E 0.277 1964.47 5209.88 44.900 289.090 4147.26 4199.68 925.79 N 2548.24 W 5975610.92 N 369164.21 E 0.989 2017.55 5304.59 45.190 288.520 4214.17 4266.59 947.40 N 2611.69 W 5975633.61 N 369101.14 E 0.525 2066.51 5400.39 45.300 288.690 4281.62 4334.04 969.10 N 2676.16 W 5975656.41 N 369037.05 E 0.170 2116.04 5497.08 45.180 289.080 4349.71 4402.13 991.32 N 2741.12 W 5975679.74 N 368972.48 E 0.312 2166.26 5595.38 45.110 287.660 4419.04 4471.46 1013.28 N 2807.25 W 5975702.83 N 368906.74 E 1.026 2216.79 5690.40 44.880 286.110 4486.24 4538.66 1032.80 N 2871.54 W 5975723.44 N 368842.80 E 1.178 2264.30 5786.03 45.780 287.080 4553.47 4605.89 1052.22 N 2936.71 W 5975743.98 N 368777.97 E 1.186 2312.15 9 November, 2001 - 14:50 Page 3 of 7 Dril/QlIest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for CD2-15PB1 Your Ref: 501032038670 Job No. AKMM11163, SulVeyed: 20 October, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) . 5881.51 45.590 285.650 4620.17 4672.59 1071.47 N 3002.25 W 5975764.35 N 368712.76 E 1.090 2360.02 5976.92 45.680 286.350 4686.89 4739.31 1090.27 N 3067.82 W 5975784.27 N 368647.53 E 0.533 2407.51 6072.36 45.420 291.520 4753.74 4806.16 1112.36 N 3132.22 W 5975807.45 N 368583.51 E 3.876 2457.34 -... 6168.08 45.410 292.170 4820.94 4873.36 1137.73 N 3195.50 W 5975833.90 N 368520.68 E 0.484 2509.54 6263.76 45.290 290.550 4888.18 4940.60 1162.52 N 3258.89 W 5975859.77 N 368457.72 E 1.211 2561.28 -~ 6357.39 45.210 289.780 4954.10 5006.52 1185.44 N 3321.31 W 5975883.76 N 368395.71 E 0.590 2610.91 6454.75 45.000 290.030 5022.82 5075.24 1208.92 N 3386.15 W 5975908.35 N 368331.27 E 0.282 2662.19 6547.93 44.650 289.610 5088.91 5141.33 1231.20 N 3447.95 W 5975931.67 N 368269.86 E 0.492 2710.96 6637.64 44.520 290.000 5152.80 5205.22 1252.53 N 3507.20 W 5975954.02 N 368210.99 E 0.338 2757.70 6735.04 44.130 288.670 5222.48 5274.90 1275.07 N 3571.41 W 5975977.65 N 368147.17 E 1.035 2807.84 6832.86 43.560 289.300 5293.03 5345.45 1297.11 N 3635.49 W 5976000.79 N 368083.48 E 0.734 2857.48 6929.29 43.450 288.100 5362.97 5415.39 1318.39 N 3698.36 W 5976023.14 N 368020.98 E 0.864 2905.88 7023.89 44.460 289.120 5431.07 5483.49 1339.35 N 3760.59 W 5976045.16 N 367959.12 E 1.304 2953.70 7120.41 44.360 288.260 5500.02 5552.44 1360.99 N 3824.57 W 5976067.90 N 367895.52 E 0.632 3002.94 7214.19 44.200 287.310 5567.16 5619.58 1380.99 N 3886.91 W 5976088.96 N 367833.53 E 0.728 3049.96 7313.39 43.820 287.4 70 5638.51 5690.93 1401.59 N 3952.68 W 5976110.68 N 367768.12 E 0.399 3099.13 7408.96 44.640 287.890 5706.99 5759.41 1421.84 N 4016.20 W 5976132.01 N 367704.96 E 0.911 3146.92 7502.73 44.820 288.300 5773.61 5826.03 1442.34 N 4078.93 W 5976153.58 N 367642.59 E 0.363 3194.56 7600.69 44.650 288.030 5843.19 5895.61 1463.83 N 4144.44 W 5976176.19 N 367577.46 E 0.260 3244.40 7695.57 44.070 288.250 5911.03 5963.45 1484.48 N 4207.48 W 5976197.92 N 367514.78 E 0.632 3292.33 7791.05 44.630 288.950 5979.31 6031.73 1505.77 N 4270.73 W 5976220.29 N 367451.90 E 0.779 3340.92 ~ 7886.65 44.350 288.600 6047.50 6099.92 1527.34 N 4334.16 W 5976242.94 N 367388.85 E 0.389 3389.83 7982.33 44.150 288.290 6116.04 6168.46 1548.46 N 4397.50 W 5976265.14 N 367325.88 E 0.308 3438.31 8078.09 44.170 287.800 6184.74 6237.16 1569.13 N 4460.93 W 5976286.89 N 367262.82 E 0.357 3486.43 8173.23 45.040 290.060 6252.48 6304.90 1590.81 N 4524.11 W 5976309.65 N 367200.01 E 1.902 3535.33 8268.09 45.380 289.900 6319.31 6371.73 1613.81 N 4587.38 W 5976333.73 N 367137.15 E 0.378 3585.44 8362.25 44.970 290.300 6385.69 6438.11 1636.76 N 4650.10 W 5976357.75 N 367074.83 E 0.530 3635.24 8459.24 44.580 289.180 6454.54 6506.96 1659.83 N 4714.39 W 5976381.92 N 367010.94 E 0.907 3685.90 8554.52 44.680 288.360 6522.34 6574.76 1681.37 N 4777.77 W 5976404.54 N 366947.94 E 0.614 3734.76 8648.52 45.150 288.790 6588.91 6641.33 1702.51 N 4840.68 W 5976426.75 N 366885.40 E 0.595 3783.06 .- . 0--- ----- 9 November, 2001 - 14:50 Page 4 of 7 Dril/QlIest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for CD2-15PB1 Your Ref: 501032038670 Job No. AKMM11163, Surveyed: 20 October, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) . 8745.62 45.170 288.280 6657.38 6709.80 1724.40 N 4905.96 W 5976449.75 N 366820.51 E 0.373 3833.13 8840.13 45.080 288.270 6724.06 6776.48 1745.40 N 4969.55 W 5976471.84 N 366757.28 E 0.096 3881.63 8935.79 45.750 289.590 6791.21 6843.63 1767.51 N 5034.00 W 5976495.05 N 366693.23 E 1.207 3931.50 ' - 291.990 6808.21 6860.63 1773.89 N 5050.80 W 5976501.72 N 366676.53 E 9.987 3945.05 8960.53 47.500 9002.06 49.170 292.500 6835.81 6888.23 1785.64 N 5079.52 W 5976513.96 N 366648.02 E 4.124 3968.94 c,- 9031.74 49.560 294.290 6855.14 6907.56 1794.58 N 5100.19W 5976523.25 N 366627.51 E 4.762 3986.57 9061.55 51.670 296.630 6874.06 6926.48 1804.49 N 5120.98 W 5976533.51 N 366606.89 E 9.322 4005.11 9093.81 52.790 297.510 6893.82 6946.24 1816.10 N 5143.69 W 5976545.51 N 366584.38 E 4.087 4026.05 9125.67 52.910 300.490 6913.06 6965.48 1828.41 N 5165.89 W 5976558.19 N 366562.39 E 7.464 4047.37 9157.54 53.250 303.680 6932.21 6984.63 1841.94 N 5187.47 W 5976572.09 N 366541.04 E 8.073 4069.48 9188.98 53.820 305.980 6950.89 7003.31 1856.38 N 5208.23 W 5976586.89 N 366520.54 E 6.156 4092.00 9222.79 55.250 308.210 6970.51 7022.93 1872.99 N 5230.19 W 5976603.87 N 366498.87 E 6.837 4117.00 9253.36 56.270 309.630 6987.71 7040.13 1888.87 N 5249.84 W 5976620.08 N 366479.48 E 5.087 4140.27 9286.28 57.390 310.890 7005.72 7058.14 1906.68 N 5270.87 W 5976638.25 N 366458.77 E 4.673 4165.88 9318.51 58.700 312.480 7022.78 7075.20 1924.86 N 5291.29 W 5976656.78 N 366438.66 E 5.834 4191.55 9349.46 60.380 313.470 7038.47 7090.89 1943.05 N 5310.81 W 5976675.30 N 366419.46 E 6.088 4216.79 9380.83 62.820 315.230 7053.39 7105.81 1962.34 N 5330.53 W 5976694.93 N 366400.07 E 9.211 4243.10 9414.01 65.170 315.370 7067.94 7120.36 1983.54 N 5351.51 W 5976716.48 N 366379.46 E 7.093 4271.68 9445.86 65.850 316.740 7081.14 7133.56 2004.41 N 5371.62 W 5976737.69 N 366359.70 E 4.459 4299.56 9478.00 67.070 317.410 7093.98 7146.40 2025.98 N 5391.69 W 5976759.60 N 366340.01 E 4.250 4328.05 9509.40 68.890 320.210 7105.75 7158.17 2047.89 N 5410.85 W 5976781.83 N 366321.22 E 10.096 4356.40 -.-.- 9540.03 70.570 321.580 7116.36 7168.78 2070.18 N 5428.97 W 5976804.44 N 366303.49 E 6.905 4384.60 9571.22 72.150 321.570 7126.33 7178.75 2093.34 N 5447.34 W 5976827.90 N 366285.52 E 5.066 4413.68 9601.32 73.720 322.610 7135.17 7187.59 2116.04 N 5465.02 W 5976850.90 N 366268.23 E 6.174 4442.04 9636.40 75.170 324.530 7144.57 7196.99 2143.23 N 5485.08 W 5976878.43 N 366248.64 E 6.700 4475.47 9668.22 76.490 325.790 7152.36 7204.78 2168.55 N 5502.70 W 5976904.05 N 366231.45 E 5.652 4506.11 9700.48 78.560 325.780 7159.33 7211.75 2194.59 N 5520.42 W 5976930.39 N 366214.19 E 6.417 4537.43 9737.05 79.160 326.270 7166.40 7218.82 2224.35 N 5540.47 W 5976960.49 N 366194.65 E 2.102 4573.12 9774.45 80.650 328.170 7172.95 7225.37 2255.31 N 5560.40 W 5976991.78 N 366175.25 E 6.394 4609.82 9864.09 86.550 329.080 7182.94 7235.36 2331.33 N 5606.75 W 5977068.59 N 366130.20 E 6.659 4698.72 u ~-------- 9 November, 2001. 14:50 Page 5 of 7 DrillQlIest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for CD2-15PB 1 Your Ref: 501032038670 Job No. AKMM11163, SufVeyed: 20 October, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 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) ("/100ft) . 9894.96 89.020 330.710 7184.13 7236.55 2358.01 N 5622.22 W 5977095.53 N 366115.19 E 9.584 4729.54 9957.97 92.580 334.950 7183.25 7235.67 2414.04 N 5650.98 W 5977152.04 N 366087.39 E 8.785 4792.51 " 9989.90 92.650 335.320 7181.80 7234.22 2442.98 N 5664.40 W 5977181.21 N 366074.48 E 1.178 4824.36 "- 10018.54 92.460 334.880 7180.52 7232.94 2468.93 N 5676.44 W 5977207.36 N 366062.88 E 1.672 4852.93 10115.88 92.150 333.110 7176.61 7229.03 2556.34 N 5719.08 W 5977295.49 N 366021.74 E 1.845 4950.12 .~ 10212.74 91.720 333.690 7173.34 7225.76 2642.90 N 5762.43 W 5977382.78 N 365979.88 E 0.745 5046.89 10308.92 91.350 333.310 7170.76 7223.18 2728.95 N 5805.33 W 5977469.54 N 365938.46 E 0.551 5142.99 10404.61 93.750 335.440 7166.50 7218.92 2815.13 N 5846.67 W 5977556.42 N 365898.60 E 3.352 5238.49 10500.30 93.690 333.960 7160.29 7212.71 2901.45 N 5887.47 W 5977643.43 N 365859.27 E 1.545 5333.86 10595.99 90.680 332.690 7156.64 7209.06 2986.88 N 5930.40 W 5977729.58 N 365817.82 E 3.414 5429.43 10690.47 89.750 331.580 7156.29 7208.71 3070.41 N 5974.55 W 5977813.85 N 365775.10 E 1.533 5523.91 10785.74 91.660 331.660 7155.12 7207.54 3154.22 N 6019.83 W 5977898.42 N 365731.26 E 2.007 5619.17 10881.42 92.520 330.730 7151.63 7204.05 3238.00 N 6065.90 W 5977982.98 N 365686.63 E 1.323 5714.77 10969.20 92.280 329.360 7147.95 7200.37 3313.99 N 6109.69 W 5978059.70 N 365644.15 E 1.583 5802.43 11069.39 92.150 331.010 7144.08 7196.50 3400.85 N 6159.47 W 5978147.40 N 365595.87 E 1.651 5902.50 11163.57 90.310 330.810 7142.06 7194.48 3483.12 N 6205.24 W 5978230.45 N 365551.50 E 1.965 5996.64 11257.04 90.180 329.680 7141.66 7194.08 3564.27 N 6251.63 W 5978312.38 N 365506.51 E 1.217 6090.07 11354.39 90.120 329.770 7141.40 7193.82 3648.34 N 6300.71 W 5978397.28 N 365458.88 E 0.111 6187.35 11451.86 90.180 331.530 7141.15 7193.57 3733.30 N 6348.48 W 5978483.04 N 365412.57 E 1.807 6284.79 11548.82 90.250 330.760 7140.78 7193.20 3818.22 N 6395.27 W 5978568.75 N 365367.24 E 0.797 6381.74 11644.00 89.510 331.510 7140.98 7193.40 3901.57 N 6441.22 W 5978652.88 N 365322.72 E 1.107 6476.91 -- 11741.03 90.370 331.570 7141.09 7193.51 3986.87 N 6487.46 W 5978738.96 N 365277.95 E 0.888 6573.94 11836.67 91.910 332.720 7139.18 7191.60 4071.41 N 6532.14 W 5978824.25 N 365234.73 E 2.009 6669.56 11931.71 91.850 332.420 7136.06 7188.48 4155.72 N 6575.89 W 5978909.29 N 365192.42 E 0.322 6764.54 12027.14 91.600 333.670 7133.19 7185.61 4240.74 N 6619.13 W 5978995.04 N 365150.64 E 1.335 6859.90 12117.94 91.540 332.640 7130.70 7183.12 4321.73 N 6660.12 W 5979076.72 N 365111.05 E 1.136 6950.64 12216.76 92.400 333.760 7127.31 7179.73 4409.88 N 6704.65 W 5979165.62 N 365068.03 E 1.428 7049.38 12273.00 92.400 333.760 7124.95 7177.37 4460.28 N 6729.49 W 5979216.43 N 365044.06 E 0.000 7105.54 Projected Survey .---- -.---- 9 November, 2001 - 14:50 Page 6 of 7 DrillQlIest 2.00.09.003 , .' . . ~ Sperry-Sun Drilling Services Survey Report for CD2-15PB1 Your Ref: 501032038670 Job No. AKMM11163, SuIVeyed: 20 October, 2001 . Kuparuk River Unit North Slope, Alaska Alpine CD.2 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.226° (19-0ct-01) The Dogleg Severity is in Degrees per 100 feet (US). --. Vertical Section is from Well and calculated along an Azimuth of 331.880° (True). ',<---, Based upon Minimum Curvature type calculations, at a Measured Depth of 12273.00ft., The Bottom Hole Displacement is 8073.42ft., in the Direction of 303.536° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12273.00 7177.37 4460.28 N 6729.49 W Projected Survey Survey tool program for CD2-15PB1 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description ~- 0.00 349.00 0.00 349.00 349.00 12273.00 349.00 7177.37 Tolerable Gyro MWD Magnetic 9 November, 2001 - 14:50 Page 7 of 7 DrilfQlIest 2.00.09.003 ( t 12-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well CD2-15 Q?OJ-ISCj Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 13,395.25' MD Window / Kickoff Survey 13,450.00' MD Projected Survey: 14,161.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED NOV 1 3 2001 ~aska Oil &. Gas Conso Commission Ancnorage tB ;' - « Q ra -"~~- ., D EFI N ITIVE Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-15 CD2-15 Job No. AKMM11163, Surveyed: 28 October, 2001 SURVEY REPORT 9 November, 2001 Your Ref: 501032038600 Surface Coordinates: 5974641.66 N, 371696.24 E (70" 20' 20.2250" N, 151" 02' 28.0829" W) Surface Coordinates relative to Project H Reference: 974641.66 N, 128303.76 W (Grid) Surface Coordinates relative to Structure: 198.36 N, 24.65 W (True) Kelly Bushing: 52.42ft above Mean Sea Level 'c,- 55 P E!"""""" Y -55 U., DRILLING SEAVlces A Halliburton Company Survey Ref: svy9690 Sperry-Sun Drilling Services Survey Report for CD2-15 Your Ref: 501032038600 Job No. AKMM11163 Surveyed: 28 October, 2001 . North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inet Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (It) (ft) (It) (It) (It) (It) (It) (0/100ft) . 13395.25 86.740 332.640 7135.07 7187.49 5446.35 N 7265.01 W 5980211.52 N 364525.49 E 8227.62 Tie on Point 13450.00 88.590 332.510 7137.30 7189.72 5494.90 N 7290.21 W 5980260.50 N 364501.13 E 3.387 8282.32 Window Point 13490.23 86.550 329.880 7139.01 7191.43 5530.12 N 7309.57 W 5980296.04 N 364482.37 E 8.269 8322.50 13586.02 86.370 328.860 7144.92 7197.34 5612.38 N 7358.28 W 5980379.13 N 364435.07 E 1.079 8418.01 13682.16 86.680 329.880 7150.75 7203.17 5694.96 N 7407.17 W 5980462.53 N 364387.60 E 1.107 8513.88 ~~ 13777.39 86.800 329.340 7156.16 7208.58 5776.97 N 7455.27 W 5980545.35 N 364340.91 E 0.580 8608.89 13871.47 87.410 330.740 7160.92 7213.34 5858.37 N 7502.19 W 5980627.55 N 364295.39 E 1.621 8702.79 13967.60 87.410 329.100 7165.26 7217.68 5941.47 N 7550.32 W 5980711.45 N 364248.69 E 1.704 8798.77 14061.22 86.980 331.030 7169.84 7222.26 6022.50 N 7596.98 W 5980793.27 N 364203.42 E 2.110 8892.22 14100.85 86.980 331.470 7171.93 7224.35 6057.19 N 7616.01 W 5980828.29 N 364184.99 E 1.109 8931.80 14161.00 86.980 331.470 7175.10 7227.52 6109.97 N 7644.70 W 5980881.54 N 364157.20 E 0.000 8991.86 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.208° (09-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 331.880° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14161.00ft., The Bottom Hole Displacement is 9786.38ft., in the Direction of 308.633° (True). --- -- - -- --------- 9 November, 2001 - 17: 13 Page 2 of 3 DrlllQuest 2.00.09.003 " Kuparuk River Unit Comments Measured Depth (ft) -"-' 13395.25 13450.00 14161.00 ~ Sperry-Sun Drilling Services Survey Report for CD2-15 Your Ref: 501032038600 Job No. AKMM11163 Surveyed: 28 October, 2001 . 5446.35 N 5494.90 N 6109.97 N Survey tool program for CD2-15 North Slope, Alaska Alpine CD-2 Station Coordinates- TVD Northlngs Eastlngs (ft) (It) (It) 7187.49 7189.72 7227.52 From Measured Vertical Depth Depth (ft) (ft) 0.00 349.00 -"'- 9 November, 2001 - 17:13 0.00 349.00 To Measured Vertical Depth Depth (It) (It) 349.00 14161.00 349.00 7227.52 _..-----_.._~._-- Comment 7265.01 W 7290.21 W 7644.70 W Tie on Point Window Point Projected Survey Survey Tool Description Tolerable Gyro (CD2-15PB1) MWD Magnetic (CD2-15PB1) -.--.-- Page 3 of 3 DrillQuest 2. 00. 09. 003 {' ( ~ " Ñ\ \~ !)' \ YJ'\ \\\ ~ III ~ V' 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 Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface 1716' FNL, 1545' FEL, Sec. 2, T11 N, R4E, UM At top of productive interval 613' FSL, 1863' FEL, Sec. 34, T12N, R4E, UM At effective depth At total depth 260' FNL, 1063' FWL, Sec. 34, T12N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 77' Surface 2419' Production 9793' Perforation depth: measured true vertical 11 056 7131 11 056 7131 Size 16" 9-5/8" 7" None None Operational shutdown - Plugging - Pull tubing 5. Type of Well: Development _X Exploratory - Stratigraphic - Service ----- Per APD ----- Per APD feet feet feet feet Plugs (measured) Junk (measured) Cemented 300 Sx AS1 399 Sx AS III L & 240 Sx 15.8 class G 132 Sx 15.8 class G Tubing (size, grade, and measured depth 4.5" 12.6#, L-80 @ 9308' MD Packers & SSSV (type & measured depth) 7" Baker S3 Permanent Packer @ 9197' MD Description summary of proposal -- Detailed operations program -- BOP sketch -- Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic 14. Estimated date for commencing operation 15. Status of well classification as: November 20, 2001 16. If proposal was verbally approved 13. Attachments Oil__X Name of approver Date approved Service -- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Notify Commission so representative may witness Plug integrity -- BOP Test -- Location clearance- Mechanical Integrity Test - Subsequent form required 10-_~~¿- ()~ ~ ""'~\u" Conditions of approval: Form 10-403 Rev 06/15/88 . Title: Alpine Drilling Team Leader . . . OR! GINAL Re-enter suspended well - Time extension - Stimulate - Variance Perforate 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Other j Annular Disposal Colville River Unit 8. Well number CD2-15 9. Permit number / approval number 201-159 10. API number 50-103-20386-00 11. Field / Pool Colville River Field / Alpine Oil Pool Measured Depth 114' 2656' True vertical Depth 114' 2372' 9830' 7233' RECE IVED NO\l 0 2 2001 Alaska Oil & Gas Cons. Commission Anchorage x Gas -- Suspended -- Questions? Call Vern Johnson 265-6081 Date tl( tlt'( Commissioner Date SUBMIT IN TRIPLICATE (" (' Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-15 b. The depth to the base of freshwater aquifers There are no USDW aquifers in the Colville and permafrost, if present. River Unit. Base of Permafrost = 1552' TVD (RKB) c. A stratigraphic description of the interval The Schrader Bluff formation provides an exposed to the open annulus and other upper barrier and marine shales and information sufficient to support a claystones of the Lower Cretaceous Torok commission finding that the waste will be Formation provide a lower barrier. Calculated confined and will not come to the surface or water salinities of the Cretaceous and older contaminate freshwater. 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-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. e. Identify the types and maximum volume of Types of fluids can be mud, diesel, cement, waste to be disposed of and the estimated and water. Maximum volume to be pumped is density of the waste slurry. 35,000 bbls. f. An estimate of maximum anticipated Maximum anticipated pressure at casing shoe pressure at the outer casing shoe during during disposal operations is 1907 psi. See annular disposal operation and calculations attached calculation page. showing how this value was determined. g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. See attached cementing reports, LOT/FIT reports, and casing reports. h. Details that show the inner and outer casing See attached casing summary sheet and strings have sufficient strength in collapse calculation page. and burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission to confirm containment of drilling wastes. NA I( -(' CD2-15 Pressure Calculations for Annular Disposal .... .... a> a> "0 "0 ro a> ro a> ..c. ..c. ëñ CJ) c. c. 0 0 0 0) 0 0 c: C\I 0 CJ) C\I ca + + () ~ ~ = co CJ) CJ) - c. C. LO I ..- ..- 0) 0 0 CJ) CJ) ro ca <.9 <.9 Ç=9-5/8" 36 Ib/ft, J-55 BTC casing @ 2656 ft MD (2372 ft TV D) Pburst = 3520 psi, @ 85%: Pburst85% = 2992 psi ........ ............ 'Töë' Estimated Top of Cement @ 8685 ft MD (6877 ft TVD) (7" csg x 8-1/2" Open hole annulus) 0) c: :c :::::I l- N 0) ;:: c: I ëñ ~ ca () Ç=4-1/2" 12.6 Ib/ft L-80 tubing to 9308 ft MD F-- Ç=7" 26 Ib/ft, L-80, BTC casing @ 9380 ft MD (7233 ft TVD) Pcollapse = 5410 psi, @ 85%: Pcollapse85% = 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 - PFormation Pmax = 12.0 (0.052) (2372)+1500 - 0.4525 (2372) Pmax = 1907psi Maximum fluid density to burst 9-5/8" casinq: Pburst85% = PHydrostatic + P Applied - PFormation 2992 = MW max (0.052) (2372) + 1500- 0.4525 (2372) MW max = 20.8 ppg Maximum Fluid Density to Collapse 7" Casinq: Pcollapse85% = PHydrostatic + PAp plied - PGasGradient - PHeader 4598 = MW max (0.052) (6877) + 1500 - (0.1) (6877) - 2000 MWmax = 16.2 ppg ( l " _PHILLIPS Alaska, Inc. Casing Detail 9 518" Surface Casing Well: Date: CD2-15 1 0/6/01 A Subsidiary of PHilLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.60 FMC Gen V Hanger 2.24 36.60 Jts 3 to 61 59 Jts 9-5/8" 36# J-55 BTC Csg 2528.08 38.84 Davis Lynch Float Collar 1.53 2566.92 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 85.48 2568.45 Davis Lynch Float Shoe 1.80 2653.93 9- 5/8" shoe @ 2655.73 TD 12 1/4" Surface Hole 2666.00 RUN TOTAL 35 BOWSPRING CENTRALIZERS - 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. Last 11 joints stay out # 62 thru # 72. Use Best-Q-Life 2000 pipe dope Remarks: Up Wt -160 k Dn Wt -140 k Block Wt - 70 Supervisor: David Burley :( ~' ; (, PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-15 Common Well Name: CD2-15 Event Name: ROT - DRILLING Prima Hole Size: TMD Set: Date Set: Csg Type: Csg Size: 2,656 (ft) 10/7/2001 Surface Casing Cmtd. Csg: Cement Co: Dowell Schlumberger Report #: Start: 1 10/4/2001 Cement Job Type: S ueeze Casin Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Page 1 of 3 Spud Date: 10/5/2001 Report Date: 10/8/2001 End: Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Cementer: Jerry Culpepper Pipe Movement: Reciprocating Rot Time Start: : Rec Time Start:15:00 Type: Pre-Flush Volume Excess %: 150.00 Meas. From: Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 420 (gpm) Mud Circ Press: 520 (psi) Time End: : Time End: 17:55 Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 10 (Ibs) RPM: SPM: 5 stage No: 1 011 Max Torque: (ft-Ibf) Drag Down: 10 (Ibs) Start Mix Gmt: 16:33 Disp Avg Rate: 10.00 (bbl/min) Returns: Start Slurry Displ: 16:34 Disp Max Rate: 10.00 (bbl/min) Total Mud Lost: (bbl) Start Displ: 17:35 Bump Plug: Y Gmt Vol to Surf: 133.00 (bbl) End Pumping: 18:00 Press Prior: 540 (psi) End Pump Date: 1 0/7/2001 Press Bumped: 1,000 (psi) Ann Flow After: N Top Plug: Y Press Held: 2 (min) Mixing Method: Bottom Plug: Y Float Held: N Density Meas By: Mud Data Type: Spud Mud Density: 9.7 (ppg) Visc: 44 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PVIYP: 25 (cp)/10 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 7 (lb/100fF) Bottom Hole Static Temperature: (OF) Density: 9.7 (ppg) Volume: 199.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Stage No:1Slurry No: 1 of4 To: (ft) Description: Biozan with nutplug marke Gmt Vol: (bbl) Density: (ppg) Slurry Vol: (sk) Water Vol: 40.0 (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: (OF) Purpose: SPACER Mix Water: (bbl) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 10/9/2001 3:50:06 PM (' Legal Well Name: CD2-15 Common Well Name: CD2-15 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: ^" ,'II' \, PHILLIPS ALASKA INC. Cementing Report Page 2 of 3 Report #: Start: 1 10/4/2001 Spud Date: 10/5/2001 Report Date: 10/8/2001 End: Stage No: 1 Slurry No: 2 of 4 To: (ft) Description: ARCO spacer Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Slurry Data Fluid Type: PRIMARY Slurry Interval: 2,156.00 (ft)To: (ft) Water Source: Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1..,Slurry..No: 36f4 Description: AS Lite Cmt Vol: 313.0 (bbl) Slurry Vol:399 (sk) Class: Density: 10.70 (ppg) Yield: 4.40 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry~No: 4of4 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,656.00 (ft)To: 2,156.00 (ft) Cmt Vol: 49.5 (bbl) Water Source: Slurry Vol240 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Class: G Density: 15.80 (ppg) Yield: 1.17 (fP/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Pressu re (psi) (psi) Purpose: TAIL Mix Water: (bbl) Foam Job: N Pressu re (psi) (psi) Printed: 10/9/2001 3:50:06 PM (' PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-15 Common Well Name: CD2-15 Event Name: ROT - DRILLING Casing Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Report #: Start: Shoe Test Pressure: 16.20 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: l Î\ 1 10/4/2001 Liner Lap: Pas Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Page 3 of 3 Spud Date: 10/5/2001 Report Date: 10/8/2001 End: Liner Top Test Tool: N Tool: N Interpretation Summary Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Printed: 10/9/2001 3:50:06 PM (' (' r- -, ~ PHIWPS ) Phillips Alaska, Inc. 1m¡ Daily Drilling Report Well Sidetrack AFE 24 Hrs TMD TVD DFS REPT NO. DATE Prog CD2-15 CD2-15 999756 0' 2,666' 2,379' 3 4 10/7/01 Supervisor David Burley Proposed TMD 10,699' Pressure Test(s) Rig Name Doyon 19 Da ily Cost $293,055 Type I Date I TM D I TVD I MW I Press Tot. press I EMW Field Name Alpine Cumulative Cost $772,929 110'10'10 ppglO psilO.OO psilO.OO PPQ Current Status Finishing BOPE Last Safety 10/7/01 Last BOP Test esting. Meetinq Event Code ODR Incident 1st 24 hrs No Next BOP Test 10/11/01 MU BHA#3, test 24 HR Forecas casing, Clean out tmt. FIT, Drill 8.5" hole. Last Survey TMD: INC: Azim: Last Casing Next Casing Operations Summary From [To Hours Phase Activity SubcodE Time lrroubh Operation Class 00:00 01:30 1.5 SURFAC DRILL CIRC P Pumped low/high vis sweeps and circ hole clean, monitor well, static. POH, wiped through tight spots @ 2380', 2266', 1913', 1755' and 1513' 40-50k over. Monitor well 01:30 07:00 5.5 SURFAC DRILL TRIP P at hwdp, static. Stand back hwdp and 8" DC's, lay down remainder of BHA. Clear tools from and lean riq floor. 07:00 09:00 2 SURFAC CASE RURD P RU to run 9-5/8" casing, change out bails, MU ill-up tool and rig up running tools. 09:00 09:15 0.25 SURFAC CASE SFTY P Held pre job safety meeting with crew. ran 61 joints of 9-5/8",36#, L-80 casing. MU 09:15 14:00 4.75 SURFAC CASE RUNC P hanger and landing joint, land casing @ 2666', FC @ 2567'. 14:00 14:45 0.75 SURFAC CEMENT PULD P Lay down fill-up tool and MU cement head. Staged pumps up to 10 bpm and conditioned 14:45 16: 15 1.5 SURFAC CEMENT CIRC P mud for cementing. Reciprocated pipe 160k PUW, 140k SOW, final pressure 520 psi, full returns throughout. Pumped 40 bbls of Biozan spacer with nut plug marker, swith to cement line and pressure test lines to 2500 psi. Pumped 50 bbls of 12.5 ppg 16: 15 18:00 1.75 SURFAC CEMENT PUMP P spacer, mix and pump 313 bbls of 10.7 ppg lead and 49.5 bbls of 15.8 ppg tail slurry. Displaced cement with 20 bbls of FW from cementers and 179 bbls of mud with rig pumps @ 10 bpm. Bumoed oluqs, floats held CIP @ 1800 hou rs. 18:00 19:00 1 SURFAC CEMENT PULD P RD cement head, landing joint, elevators and lonq bails. 19:00 19:30 0.5 SURFAC CEMENT RURD P Flush diverter system and flowline with fresh water. 19:30 21:00 1.5 SURFAC WELCTL NUND P ND Diverter system. 21:00 00:00 3 SURFAC WELCTL NUND P Install wellhead, test M/M seals to 1000 psi. NU BOP Stack. ~Sum: Isystem, install and test f .Iead. NU BOPE. ( Injection Date Source Volume Destination Total for destination 10/7/01 CD2-15 1,070 CD2-24 30,693 Source Total: 1,080 Mud Data Compan} Mud Density FV PV/YF 10sec / 10 min / ~L/HTHF MBT PH Flowline Drilling Type 30 min Gels Temp Solids M-I Spud Mud 9.6 44 25 / 10 5/7/8 10/0 27.5 8 0 4 Bits Bit/Run Size Manuf. Type Serial Jets or TFA Depth Date I-O-D-L-B-G-O-R No. In In 2/2 12.25 HUGHES- MX-C1 P6OJF 1/0.5625/0.375/0.3125 2520' 10/6/01 0-0-- --- - CHR ~ ..~ Well Name: CASING TEST and FORMATION INTEGRITY TEST Date: CD2-15 10/8/01 Supervisor: D. Micke}/ Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8", 36#, J-55, BTC CgG Casing Setting Depth: Hole Depth: 2,686' TMD 2,393' TVD 2,656' TMD 2,372' TVD Mud Weight: 9.6 ppg 30' Length of Open Hole Section: EMW= Leak-off Press. + Mud Weight 0.052 x TVD 810 psi 0.052 x 2,372' + 9.6 ppg = EMW for open hole section = 16.2 ppg Used cement unit Ria pump used Pump output = 0.0997 bps 2,800 psi 2,700 psi, 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi W 1,700 psi 0:: 1,600 psi :J 1,500 psi ~ 1,400 psi W 1,300 psi 0:: 1,200 psi Q. 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 NO #2 Fluid Pumped = 1.1 bbls Fluid Bled Back = 0.8 bbls I I +.1-... I ¿,...--.~~¡¡>...~..Ifl... .. ..... . -...-,..~ . ~,o;---""-----£-~-'L~ I 1"-'" î- ..._--- !' 'm. .~ I I I """"""" I ! I I' I """-....! i I r I II I I IF I II i I ~ I I I - LEAK-OFF TEST I - , ~CASING TEST - I I -. r I ..m..___"" LOT SHUT IN TIME L' I - -' ~ CASING TEST SHUT IN TIME - , -+-TIME LINE - ", - I. W/!!-. IJ ""'... pp '.' .> ! n ,., r I J" I ---- I r-' 10 20 30 STROKES 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r-- --- ---- - - ---,. -- ------- - - - - - - r - -- - ------- - - _n, : : 0 : 0 psi: .------------+--------------~------------.----i : : 1.0 : 30 pSI : L____--------"""------- ____-L__--------------" ! ¡ 2.0 ¡ 60 psi ! t-- ---- ---- ---... - -------- - -- - - - t - -- - - -- ---- - - - - -.. ! ! 3.0 ! 90 psi ! r------------"T'"--------------r--- - ------------, : : 4.0 : 150 psi: .------------+---------------~--- - --------.---i : : 5.0 : 230 pSI I L--------------"""------------ -L----------------" ! ! 6.0 ! 330 psi! t-------------'" ---------------þ-- --- -------- ---.. ! ¡ 7.0 ! 420 psi! r-- ---- --- - - -- -"T'" - - ------ -- - - - - r - -- - - ------- ----, : : 8.0 : 520 psi: .-- ---- - - ----- - + - - ------ --- - --~ - -- - - - ----- - -. - -- i : : 9.0 : 610 pSI: ¡-------------r---1 0 :Õ----¡---77C)psf--1 r- --- - -- -- - --r- -- -11-:Õ - --- T -- ã 1 Õ-p-- sT 1 . I , I r-------------"T'"--------------r----------------' I I I I I I I I .-------------+-------------~----------------i I I I I I I I I L__--_----------"""---------______L----------------" I I . I I I . I I I . I t--------------...---------------Þ----------------" I I . I I I I I I I I I r--------------"T'"------------ --r------ ------- ---, I I I I I I I I .-------------+ ------------ --~-- --- ------- ----i I I I I I I I I L-------------""" ------- _____-L----- ----------.. I I I I . I I I I I I I t----------------------------Þ-- --- ------- ----.. I I I I I I I , I I I I r-------------"T'"-----------r- -----______n_, I I I I I I I I .-____n___--_+---------------~------__---_n-i I I I I I I I I L______-------"""-------_____--L ---------------.. . I I I I I I I I I I I .----------------i I I I I I I . I I I I I , , 60 ~ SHUT IN TIME: SHUT IN PRESSURE . - - ----- - --:- -- -+ -- - ----- -- - - - r -- - - -- ------ -: - ---. : 0.0 mm : I 810 pSI I L------_n___"""__-----__--___L---------- ----.. ! 1.0 min ! ! 750 psi! .-____-n---_---"'_____n_____~----------------" ! 2.0 min ! ! 720 psi! r--------------"T'"-------------r----- ----------, : 3.0 min : : 710 psi: .---------:----+ ----------- --~----- --------.---i : 4.0 mtn : : 700 pSI: L-------------"""---------- -_-L-- --------------.. I 5 0 'I I 700 . I : . mm : : pSI: .------ --- - --- -...- - - - ----- - - - -- - Þ - -- - - - ------ --- -.. ! 6.0 min ! ! 690 psi! r---__-n------"T'"---------------r--------______n, I 7.0 min I : 690 psi: .----------:----+--------- -----~--- ---------.- --i : 8.0 mm : : 680 pSI: L__--__- -------"""-------__--___L_n--___--------" ! 9.0 min ¡ ! 680 psi! .-------------...--------- - ---- Þ---------------" L1.Q.;Q_~l~-.L-__----- - ---- L.-~~.Q_p.~L- J ~PHILLIPS Alaska, Inc. ~ A Slbsidiary or PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE ,---------- ---,- __--n___- --- -,------------- ----. : : 0 stks : 20 psi: ~- -------- ----+ --------------+--- ----------- --f : : 2 stks : 50 psi: L_-_----------""---- --------- -...... --- ------------, ¡ ! 4 stks ! 140 psi: t-------------------- ----------- __n------___- --: ! ! 6 stks ! 340 psi! r- --------------,...---- - -------- -,...---- ---------- --. : : 8 stks : 620 psi: ~- ------- ___n+_--- ----------+--- - ------------f ! : 10 stks I 880 psi: L- _____n- --- -....--------------....---- ------------, ! ! 12 stks ¡ 1,030 psi! t-------------- ---- -------- -- -.....- ----- ----------. ~--------- --- - --L-- ~ _'!_!!~_!!- -+- _!!~-~.Q-p'~j--~ I I 16 stks I 1,350 psi I .------------ - --+--- -------- --+------------:--f L______-- --- - __L- ~-~_!!~_!! __L_!!~_~.Q-p.~~_.1 ! ! 20 stks ! 1,730 psi! t- --------------- ---- -------- --.....---- __--___n___' ¡ ! 22 stks i 1,950 psi! r-------- ----- -"T'"-- - - n_____- - -,...-- -------- ----. : : 24 stks : 2,140 psi: .-- ------------+ -- --- ------- - -+---- ----------. --f : : 26 stks : 2,370 pSI: r- --------- -----r-2-j -siks--'2~ SÕÕ-psT! t--------------.....---- - ------- --.....--- --- ----------. I I I I I I I . I I I . r----____n_---"T'"---------- - ---,...- - --------------. I I I . I I I I .--- ------- ---- - +---------- ----+--- --- ----------f I I I I I I I , L__- ------ - --- -......---------- - ---""_____n__------' I I I I I I I . I I I . t---------- _n- _n-___---- - ----- - ----- --------. I I I I I I I I I ----' , I --, : SHUT IN TIME I SHUT IN PRESSURE ~-------- --:----+----- ------- - --¡-- --- ---------:--1 I 0.0 mm : : 2,500 pSI: L --------- ---- -- ....------------ - -....--- ---- ------ --, ! 1.0 min ! ! 2,490 psi! t--------- --------- __n_____- ----- ____n____-- --. I 2.0 min : : 2,480 Psi: I I I I rn___-_-- --- - --"T'"-- ---------- - -,...---------------. : 3,0 min : : 2,480 psi: .-------- --:- ---+ ----- ------- --+---- --- -------:--f : 4.0 mm : I 2,470 pSI: r---5~Õ-m1ñ --I ----- ------ -- -'2 ~47Õ-psT! t----------- ----- ----- ------ ---.....-- --- ----------. ~---?:Q-~ l~--L----------- ---L-~!~?Q-p'~j--¡ : 7.0 min : : 2,470 psi: ~--- ------- -: ----+---------- ----+-- ------------:.-- f L__~Q_~~~__l______---- ____L~!~ ?Q-p.~~-.1 ! 9.0 min ! ! 2,470 psi! t--- ------- ---------- ------ - - --.....-- ---- ---------. ! 10.0 min ! ! 2,470 psi ¡ r --- ------ - --- - "T'"-- __n___--- - -"T'"-- -- -_u--------. I 15.0 min : : 2,460 psi: ~----------- ~- - - + -- -- - ------- - -+--- - ---------:.--f I 20.0 mm : : 2,460 pSI: L--------- _n__- ....-- ---------- - -....-- -- ------------, ! 25.0 min ! ¡ 2,450 psi! t--------- -- -- --..... -- - -- -- ----- -- .....--- - -- ------- - --. L - ~-~.:Q- ~i ~__l___- - ----- ---- L~!~~.Q-P.~ Ll ~~, NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ~I' ( Casing Detail 7" Intermediate Casinq Well: Date: CD2-15 10/13/01 Phillips Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 35.20 FMC 11" X 7" Hanger 1.32 35.20 Jts 3 to 241 239 Jts 7" 26# L-80 BTCM Csg 9706.59 36.52 7" Davis Lynch Float Collar 1.52 9743.11 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 83.00 9744.63 7" Davis Lynch Float Shoe 1.72 9827.63 9829.35 8-1/2" TD 9840.00 1 straight blade centralizer per jt # 2 & #4 - # 19, then every other jt. F / # 179 to # 239 51 total centralizers Use Best-o-Life 2000 pipe dope Remarks: Up Wt = 225 On Wt = 145 Block Wt= 70K Supervisor: Don Mickey (' (" PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-15 Common Well Name: CD2-15 Event Name: ROT - DRILLING Report #: Start: 2 10/4/2001 Cement Job Type: Primary Prima S ueeze Casin Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Hole Size: TMD Set: Date Set: Csg Type: Csg Size: 8.500 (in) 9,830 (ft) 10/15/2001 Production Casing 7.000 (in.) Hole Size: SO TMD: (ft) SO Date: SO Type: Cmtd. Csg: Intermediate Casing/Li Cmtd. Csg: Cement Co: Dowell Schlumberger Page 1 of 2 Spud Date: 10/5/2001 Report Date: 10/16/2001 End: Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe Movement: No movement Rot Time Start: : Rec Time Start: : Time End: : Time End: : RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Max Torque: (ft-Ibf) Drag Down: (Ibs) Type: Cement Casing Start Mix Gmt: 14:10 Disp Avg Rate: 7.00 (bbl/min) Returns: full Volume Excess %: 40.00 Start Slurry Displ: 14:20 Disp Max Rate: 7.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: Start Displ: 14:20 Bump Plug: Y Gmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 15:10 Press Prior: 700 (psi) To Cementing: 1.50 End Pump Date: 10/15/2001 Press Bumped: 1,000 (psi) Ann Flow After: N Mud Circ Rate: 6 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: Mud Circ Press: 450 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Mud Data Type: Non-Disp. LS Density: 9.8 (ppg) Visc: 39 (s/qt) Bottom Hole Circulating Temperature: 1 02 (OF) Displacement Fluid Type: Mud PV/yP: 7 (cp)/18 (lb/100ft2) Gels 10 sec: 4 (lb/100ft2) Gels 10 min: 8 (lb/100fF) Bottom Hole Static Temperature: (OF) Density: 9.8 (ppg) Volume: 353.00 (bbl) Stage Nò: 1 Slurry No: 1 of 3 Slurry Data Fluid Type: ., FLUSH Slurry Interval: (ft) Water Source: Description: CW100 Gmt Vol: (bbl) Slurry Vol: (sk) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Purpose: SPACER Mix Water: (bbl) Foam Job: N To: (ft) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temperature: (OF) Temperature: (OF) Temperature: (OF) (OF) Temp (OF) (OF) Pressure (psi) (psi) Printed: 10/17/2001 9:44:17 AM ( (' PHILLIPS ALASKA INC. Cementing Report Page 2 of 2 Legal Well Name: CD2-15 Common Well Name: CD2-15 Event Name: ROT - DRILLING Report #: Start: 2 10/4/2001 Spud Date: 10/5/2001 Report Date: 10/16/2001 End: Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: ARCO SPACER Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Stage No: 1 Slurry No: 30f3 Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 9,830.00 (ft)To: 9,115.00 (ft) Cmt Vol: 30.0 (bbl) Water Source: lake water Slurry Vol:132 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: 15.5 (bbl) Other Vol: 0 Purpose: TAIL Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressu re (psi) (psi) (OF) Casing Test .' Shpe Test Liner Top Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y 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 LoglSurvey 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: 8985 (ft) How Determined: Calculated TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Printed: 10/17/2001 9:44:17 AM (' (' ~.. .~ ~ PIIIWPS) Phillips Alaska, Inc. m Daily Drilling Report Well Sidetrack AFE 24 Hrs TMD TVD DFS REPT NO. DATE Proa CD2-15 CD2-15 998008 0' 9,840' 7,234' 11 12 10/15/01 Supervisor Don Mickey Proposed TMD 10,699' Pressure Test(s) Rig Name Doyon 19 Daily Cost $298,161 Type I Date I TMD I TVD I MW I Press Tot. press 1 EMW Field Name Alpine Cumulative Cost $2,020,034 FIT 110'10'10 ppglO psiO.OO psiO.OO ppg Current Status RIH w/ 6 1/8" Last Safety 10/15/01 Last BOP Test 10/15/01 BHA Meeting Event Code ODR Incident 1st 24 hrs 'No Next BOP Test 10/22/01 RIH w/ 6 1/8" 24 HR Forecas ß HA - test csg - drill 6 1/8 " hole Last Survey TMD: INC: Azim: Last Casing Next Casing Operations Summary From iTo Hours Phase Activity SubcodE Time ~roubl~ Operation Class 00:00 03:00 3 INTRM 1 CASE RUNC P Continue running 7" 26# L-80 MBTC casing to 2649' (65 its.) 03:00 03:30 0.5 INTRMl CASE CIRC P Circulate btms up @ 9 5/8" shoe 03:30 08:00 4.5 INTRMl CASE RUNC P Continue running 7" 26# L-80 MBTC to 7038' (173 its) 08:00 08:30 0.5 INTRMl CASE CIRC P Circulate btms up @ 7038' Contiune running 7" 26# L-80 MBTC to 9793' - 08:30 12:00 3.5 INTRMl CASE RUNC P 241 jts. total - landed casing wi mandel hanger in wellhead wi shoe @ 9830' FC @ 9743' - rig down fill UP tool - install cement head 12:00 13:30 1.5 INTRMl CEMENT CIRC P Circulate and condition mud for cement job -PV 7 YP 18 PJSM - Cement 7" - Pump 5 bbls pre-flush - test lines to 3000 psi pump 15 bbls pre-flush - 13:30 14:15 0.75 INTRMl CEMENT PUMP P pumped 50 bbls Arco spacer @ 12.5 ppg drop btm plug - pump 30 bbls 15.8 ppg cmt. - drop OP pluq Pumped 20 bbls water fl Dowell - switch to rig 14:15 15:30 1.25 INTRMl CEMENT DISP P pumps & displace cement wi 353 bbls 9.8 ppg mud - 7 bbls/min @ 400 to 700 psi bumped plug wI 1000 psi - floats held - CIP @ 1510 hrs - Rig down cmt head - elevator - landing joint - 15:30 17:30 2 INTRM1 CEMENT PULD P long bails -pull thin wall wear bushing - install & est pack-off to 5000 psi 17:30 18:30 1 PROD DRILL OTHR P Change top pipe rams to 3 1/2" x 6" - change top drive iunk sub to XT-39 Set test plug - Test BOPE - Hydril to 250 psi & 3500 psI - pipe rams, blind rams, choke manifold valves, kill and choke line valves, TIW, dart 18:30 00:00 5.5 PROD DRILL OTHR P valve, top drive valves 250 psi & 5000 psi - perform accumulator recovery test - Witnessing of test waived by John Crisp AOGCC - L/D test plug - set wear bushing - blow down choke and kill lines "IA u.. I~um: (' (' In i ection Date Source Volume Destination Total for destination 10/16/01 CD2-15 280 CD2-39 6,397 Source Total: 11,771 Mud Data Compan, Mud Density FV PV /YF 10sec / 10 min / WL/HTHI MBT PH Flowline Drilling Type 30 min Gels Temp Solids M-I Non-Disp. 9.8 38 6/18 5/7/9 6.6/ 11.4 15 8.4 130 2.7 LS Bits Bit/Run Size Manuf. Type Serial Jets or TFA Deptl1 Date In I-O-D-L-B-G-O-R No. In 4/4 6.125 HUGHES- STR386DG2 0324700 10.46875/0.46875/0.46875 9840' 10/16/01 0-0-- --- - CHR ~, "'~ Well Name: CASING TEST and FORMATION INTEGRITY TEST Date: 10/16/01 Supervisor: D. Mickey CD2.15 Reason(s) for test: D Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J.55 BTC X 7" 26# L.80 BTMC Casing Setting Depth: Mud Weight: Hole Depth: TOC 8,985' TMD 6,877' TVD 2,656' TMD 2,372' TVD 9.8 ppg 6,329' Length of Open Hole Section: - 398 psi 0.052 x 2,372' + 9.8 ppg EMW- Leak-off Press. + Mud Weight 0.052 x TVD EMW for open hole section = 13.0 ppg Pump output = bbls pumped Fluid Pumped = 5.5 bbls Fluid Bled Back = 0.0 bbls w 0::: ~ . f/) 300 pSI f/) W 0::: D.. 600 psi 500 psi 400 psi LEAK-OFF TEST ~CASINGTEST ~~'LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME -+-TIME LINE 4 6 8 10 BARRELS 12 16 18 200 psi 100 psi 0 psi ~ 0 2 14 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA 20 MINUTES FOR LOT BBLS PRESSURE r-------------r--------------r----------------" ; : 0 I 0 psi: }--------------+--------------~-------------.---i ; : 0.5 : 187 PSI; L--------------...L.-------___----_L- ---------------.. i ! 1.0 ! 258 psi i .---------------+--------------~---------------.. ! ! 1.5 ! 323 psi! r-------------..,...--------------r----- ------ -----., I ; 2.0 : 374 psi: }--------------+---------------~------------.---i I ; 2.5 ; 398 pSI: L-------------...L.--------____--L----------------" i ! 3.0 i 389 psi! .--------------+------------ ---~ ----------------.. i i 3.5 i 379 psi ¡ r--------------..,...---------------r---------------" ; ; 4.0 ; 379 psi: }--------------+--------------~---- ------- -.---i ; ; 4.5 ; 379 PSI; L---------------...L.--------_____--L----------------" ! ! 5.0 ! 374 psi i .--------------+--- -------------~-- --- ----------.. ! ! 5.5 ! 374 psi i r-------------..,...--------------r-- -------------, I I I I I I I I }-------------+----------- --~- --------- -----i I I I I I I I I L------------...L.----------- - ---L----- ----------.. I I I I I I I I I I I I .--------------+----------------~---------------.. I I I I I I I I I I , I r-------------"""-------------- r----------- ----, I I I I I I I I }------------+---------------~---- ----------- i I I I I I I I I L--------------...L.---------_____-L----------------" I I I I I I I I I I I I .--------------+----------------~----------------.. I I I I I I I I I I I I r--------------..,...--------------r--------------' I I I I I I I I }-------------- +---------------~- --------- -----i I I I I I I I I L_____----------...L.--------______L_--____--------" I I I I I I I I I I I I .----------------i I I I I I I I I I I I ! ' , ; SHUT IN TIME; SHUT IN PRESSURE }----------.----+---------------r-------------.---¡ ; 0.0 mm I I 374 pSI: L-------------...L.- ------_____-L--------------" i 1.0 min ! ! 293 psi! .--------------+----------------~----------------.. ! 2.0 min ! ! 268 psi i r-----------.----T--------------r----------.---' I 3.0 mm I I 258 pSI I }------ ----.----+----------- ----~--- --- -------.---i ; 4.0 mm ; : 253 pSI: L-------------...L.-------_-----L------ ----------.. ! 5.0 min ! ! 248 psi! .----------------+---------------~----------------.. i 6.0 min i ! 248 psi ¡ r---------------"""---------- ----r ---- ------------, ; 7.0 min ; I 243 psi: }--------.----+------------~ -------------.---i I 8.0 mm I I 237 pSI I L_--------------...L. ---------_-----L - ---------------.. ! 9.0 min ! ¡ 237 psi i .---------------+----------------~----------------.. L-~-Q.:.c!_~ 1 Œ- L-------- ----.L-- _?~~_!! ~j- -.J øPHILLIPS Alaska, Inc. ~ A Slbsidiary of PHilLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE r-------- ---- --.,--- ------------.,-- - -- --- ---------, I : 0 stks: 0 psi: ~ ---------------+--- ----------+-- ----- ----- - ---i I I I I I I I I L ---------- ----.L.- - - -----------.L.------------- ---, I I I I : I : : ~----------- ----+------------- -+------------- ---. : I I I I I I I r------------ ---.,..- --- --------- - .,..----------------, I I I I I I I I }------------- --+-- --- ---------+--- --- ------ - ---i I I I I I I I I L----------- ---.L. -------------.L.--- ------------ -, I I I I I I I I I I I I ~-------- ---- --+-- - -----------+---- -------- ----. I I I I I I I I I I I I r --------------.,..-- - -----------.,--- ----- ------ _u, I I I I I I I I ~------------ +-- - -----------+------------- ---i I I I I I I I I L----------- ---- .L.-- ------------.L.-- -------____--0 I I I I I I I I I I I I ~-- - ------------ + ---- ----------+ ----------------. I I I I I I I I I I I I r ----------- ----.,..-- ------------.,- -- --------- ----, I I I I I I I I t---------- - ---- t----- ---------t ----- -------- ---1 I I I I L--- -------- ----.L. - --- - --------- .L._---------------o I I I I I I I I I I I I ~--------- ---- --+-- --------- -- - +--- ---- ------- --. f I I I I I I I I I I I r--------- ---- --.,..------------ --.,-----------------, I I I I I I I I } ------------ --+------------ --+- - ----- ------ ---i I I I I L______---- ----1.-- - --------- --1.-- --------_____-1 I I I I I I I I I I I I ~--- -----------+--- --------- ---+- ------------ ---. I I I I I I I I . ------' , , ,~,", ~ SHUT IN TIME I SHUT IN PRESSURE ~---------- ~ ---- +---- ----------¡- ----------;-----1 ; 0.0 mm : ; 0 pSI: L--_____-------.L.--------------.L. ----- --------- --, i 1.0 min ! I ! ~-- ----------- --+ ----- -------- ~--- --------- ----. : 2.0 min : : I I I I I r------------ - -.,..------------ --.,..- --- -------- - ---, : 3.0 min : I I } ----------~-- - -+ -- --- ------ - --+--- - ------------i I 4.0 mln : : I L----------- --- - .L.-- - ------- ----.L.- ---- -------- _--0 ! 5.0 min ! ! ! ~----------- ----+--------- -- ---+- - - --- ----------. ! 6.0 min i ! : r----------- ---- .,------ ----- ----.,---- -- --------- --{ : 7.0 min I : : }-----------.-- --+ - --- --------- - +---- -------- -- --i : 8.0 mm : : : L - ------------ - -.L.- - ---------_u.L.--- - ------- ____0 ! 9.0 min ! ! ! ~ - -------- ---- - -+-- - -----------+- - -- -------- - ---. ! 10.0 min i i ! r--- ----------- -.,--- - -------- - --.,-- --- --------- ---, ; 15.0 min ; I : ~-----------7-- -+------------ --+-- --------------i ; 20.0 mm I : ; L--- ------------ .L.-- - -----------.L.- ---------______0 ! 25.0 min ! ! ! ~-- -------- ----+ - - ------------+--- --- -------- --. I 30 0 . I I I L----.:---~ !~--1-- - ------- --- -1--- ------------.1 '~é'. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ( ( Struc!ure : CDH2 Well: 15 locotion : North Slope..~loS.kOI Inc. i , " """"""""","""'"""","'. C,.at.. by bm;cha.r Dcl. plOtt.. , 29 -OcI-20o1 PIO' R,t,...nce ¡, \IWO <,~.~O - 1O,ð,'>. 'I Coo'ó,na'., "'. In ,.., ,.r."nc. ,'a' "5. T"", Va,tlca' Dcpth. a.. ...rcrence RKB (Dayan '9). , - IIffiL& Phillips Alaska, . --_.__.~..._---._...~ ----- ---- ---- ¡'" I Field: Alpine Field i i. .r>rrR.'t <- West (feet) ð400 6000 3200 2400 2000 '000 1200 000 0000 0000 0200 4000 4400 4000 3000 2000 5600 0200 4800 4400 4000 ^ I ~ , ~ \ - ~\ \ 3200 ,- \ \ \ \ \ \ \ \ \ \ \ .. 'C..ln, , "\'~ \ 2000 \ \ :: Q¡¡..... ".........-......-.-....--....-.....,............, "-""""", \ " 400 0~.."........:~:"'~_...........""..,......_.."....,..,.,..._""_..,....,...,..,.."...",........." - """""'ìtt-,...., '/0 C,,'n. ,. \ ...."........""................." - . """"-....~-320 ft. """" // \ """"'l:...!,.~¿~,..7.~~1~.~,~::,::.::,/ \ ./'......:< \ /~/ \ .........- JIþ' "/0 Co . \ .-~;/?/ ;:/ / \ ..-~,¡¡¡P" % ;~"". ,// 1800 \\ ..........,,""::;::;;:'" /// ///"/ :: ø'.///~/:~//' 2BOO /' ,,1"//" / Ea-""/, / ¡ / ~~ 'Cooln, i \ \ \ \ \ \ ~ 2BOO 2400 ....... ãi Q) '<- '-" -'= t 0 z 400 BOO '200 3200 3600 ::: 4000 Ii' &5' a a ". II J: u ,S 4400 4800 " õ u V> 0200 6400 4000 8000 5600 5200 4800 3600 3200 2600 2000 2000 '600 1200 800 4400 <- West (feet) 400 400 Scole 1 ;nch ~ 400 ft 400 '600 4000 0000 2000 2400 2000 3200 3000 600 1200 5000 0200 4800 4400 4000 3000 3200 2800 ~ \ \ \ \ , \ '\, \ \ \ \\ \ \ '\ \ \\ \ , \, , , , \ \ \ , , \ , \ \ , \ \ \ 2000 fÞ 2400 2000 1000 1200 800 ^ I Z 0 :¡ :r 400 '</0 C..ln, ....... ..., co co -:; " 400 ~, ,"""': '0/< C..ln, ,""'" \ "',..", \~ "/~"""~' , '" \ ',' , "", \\, """"""", , ", \ " \ "', \ "" \ ' \ """"", \ " " ~ \ \ \ \ '\ \. , \a ~'c,,'n, \ \ , , \ ~ 600 1200 '000 2400 2800 3200 3600 4000 UJ 0 c ¡¡- 4400 5' 0 :J' 4800 .. a a ;: 400 5200 4000 600 '200 I GOO 2000 2800 3200 3&00 2400 Scole 1 inch ~ 400 ft 1800 1700 '.00 Q), "00 Qò'" HOO 1300 1200 1100 Q/". '000 900 (600 700 600 000 ^ I 400 --. Q; ~ JOO '-' ..c:---; 1: 200 0 Z 100 '00 200 JOO 400 -« 000 '00 700 600 ::: 900 8 1000 '" U ,. 110O . õ ~ 1200 ( ( ¡Phillips Inc. Alaska, c...,.. by ,,"<_..1 O,lt pl."'. : 29-Oc'-2001 p~, "",,"no> 'I ""D <134SO .. H161'>, Coo"'n.'.. .,. in 'oo' ,,"'""" "., "0, , I'NO V"",.I D.,'n' .,. "'or.... "K. (Doyon 19),j .... ' , 8feL.c l__.___.....,. nmt'1-_---, ¡ , - n_, . -. ,_.. on._.-_n.- ....._,- ------, Structure: CD#2 Field: Alpine Field Well: 15 Location: North Slope, <- West (teet) Scale 1 inch = 100 ft 2J00 "°0 600 1300 "00 700 '00 >00 400 JOO 200 '00 \00 200 JOO 400 500 7200 "00 2000 "00 '60O 1700 'BOO HOO 1100 1000 900 ~ ~ "°0 ~'\, , , \ '\ , \ \, ~ 1700 '600 "00 ~ "':' , , t\ "I' Coo",' 1400 \JOO S 1700 "00 1000 000 600 700 .00 000 400 ^ I Z 0 ::¡. :T " \ \ 1'!'f "IB ""~ \, \; ,"~, " \ 'I, \ .. \ '\ " ", " , Jt:, ,,' 'I' C"'" '\ "" 't:::,~ ,'I. C,;,~, ,¥, 24 ........,....... .................................. .....,....".."........ ~;~;;; :',(;-" 'I. COOI~ " '\ >S9 1320 ft . \' "~ë....~>::;:.~~":.~"."",:,::".,,,~:,'",:,:":,'.',',,:,:':',::,,::'.",',.',:,:,",,:'*'!':,,',',:':",',":."','"'"",Þ».:",.,,,,,A,',',:,",,"I_,.,',',,' '",' "':'118""','"",'"".",,,/,,",.,,',.c,',,',"c"',/,,',n,.",:,.",/,..",,</'~~ : -"-"'---""""....:;:;:;,:;;¡;;.:.::::..::to:':;",~---_...._".,.".,..,ceo,.. '" ':.."'" ~ () () .::;. ", ""\ 100 ,...þ '.'.",;;,;,' ",þ:"'la',...",: ¡"", '.Ia Coo., 200 JOO ~, /./,,/:;~~jE;';»::*"~ ", ,: '~ .c. --\: ; """,,"";»;,>;/ \\",'~, "/a C,""~ 600 " '\ ',i \! 900 '" " a " !'. '@ /' "" /»' &ø , , 1000 5' g. ~ 1100 0 0 &; @ '200 ;:0 2JOO 900 000 .00 700 600 000 400 JOO 200 100 100 200 JOO 400 2200 2100 2000 "00 '600 1700 '600 1000 1400 1300 1200 1100 '000 <- West (feet) Scole 1 inch m 100 ft WELLS W/SURFACE CASING SHOE (+/- 2400' TVD) WITHIN 1/4 MILE CD2-15 ~ Wells Permit # Permit Date Cement Report Casing Tally No. of LOT Source well Ann. Vol. Start Date End Date CD2-24, CD2-33, CD2- CD2-42 301-140 6/1/01 x x 2 33A, CD2-15 33992 6/1/01 10/10101 CD2-33 (+A&B), CD2-39, CD2-24 301-186 7/13/01 x x 2 CD2-14, CD2-15 33999 7/16/01 10/9/01 CD2-14 301-288 1 0/9/01 x x 2 NA .-, -~ (' (" Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 1,2001 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drillina Waste on well CD2-15 Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that CD2-15 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 injection on CD2-15 approximately November 20, 2001. Please find attached form 10-403 and other pertinent information as follows: 1. Form 10-403 2. Annular Disposal Transmittal Form 3. Pressure Calculations for Annular Disposal 4. Surface Casing Description 5. Surface Casing Cementing Report & Daily Drilling Report during cement job 6. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 7. Intermediate Casing Description 8. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 9. Formation LOT on 9-5/8" x 7" casing annulus 10. Plan View of Adjacent Wells 11. Details regarding wells within ~ mile radius of surface casing shoe. If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip Alvord at 265-6120. ~inc ~' . / I /1/11"'1 - _.. Vern Johnson Drilling Engineer cc: CD2-24 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake A TO-868 Anadarko A TO-1530 RECEIVED NOli 0 2 , 2001 Alaska Oil & G as Cons Cì . Anchorag~ omrmssíon ORIGINAL it ( NOTE TO FILE CO2 -15. . .201-159. . .301-308 Request for Annular Disposal Approval Phillips (PPCo) has requested approval for annular disposal on the subject well. They have submitted the required information. This document analyzes the information and makes a recommendation regarding their request. CD2-15 is one of the early development wells on Alpine's CO2 pad. In the documents submitted by PPCo, information from 3 wells that are within % mile are provided. The 3 wells were drilled within the last 6 months. All of the wells have been permitted for AD, with 2 of the wells (CD2-42 and CD2-24) having received nearly 34000 bbls each. No disposal is noted for CD2-14. The supplied information indicates the the closest well to CD2-15 is CD2-24 with about 330' of separation at the shoe. The casing and cementing reports for all the wells are provided. It is indicated that in each case the casings were successfully run and cemented. In the case of CD2-15, it is noted that 133 bbls of cement were circulated. Based on spreadsheet calculations, gauge plus 57% XS cement was left in the well. The casing was successfully pressure tested prior to drillout. After drilling new hole below the rathole, the formation did not leak off at about 15.8 ppg EMW. During the 10 minute observation period, the pressure dropped about 100 psi. The well was drilled into the Alpine reservoir and the 7" casing string was set and cemented. On the injectivity test, the initial departure from linear occurs at about 375 psi. The pressure reaches a maximum of about 400 psi. As injection continues, the pressure stabilizes at 375 psi in good agreement with the original departure pressure. After pumping was stopped, a 80 psi drop was recorded after 1 minute with a stabilized pressure of between 240 and 230 psi being reached by the end of 7 minutes and holding for the remainder of the observation period. The pressure plots for CD2-15 are similar to those presented for the other wells. Based on the presented information, I recommend that Phillips request for annular disposal in CD2-15 (201-159) be approved. k-~ ~~ Tom Maunder, PE N 0-....) Co f ~oa ( Sr. Petroleum Engineer I /' (, ('" 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 Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 9951 0-0360 4. Location of well at surface 1706' FNL,.1547' FEL, Sec. 2, T11N, R4E, UM At top of productive intèrval 789' FNL, 1260' FEL, Sec. 2, T11 N, R4E, UM At effective depth At total depth 1856' FSL, 2577' FWL, Sec. 35, T12N, R4E, UM . 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 77' Surface 2417' Production 7634' Perforation depth: measured true vertical 1:ubing (size. grade. and measured depth 11056 7131 11056 -7131 Size 16" 9-5/8" 7" None None Operational shutdown - Plugging - pun tubing - 5. Type of Well: Developmerit_X Exploratory - Stratigraphic - Service - --Per APD -- Per APD feet feet feet feet Plugs (measured) Junk (measured) Cemented; ; 261 SxAS~ : 376 Sx AS)II L & 240 Sx 15.8 cla~'G 138 Sx 15.8 class G Packers & SSSV (type & measured depth) 4.5" 12.6#, L-80 @ 7412' MD R~nter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (OF or KB feet) RKB 52 feet 7. Unit or Property name Other j Annular Disposal Colville River Unit 8. Well number CD2-14 9. Pennit number I approval number 201-177 10. API number 50-1 03~20390-O0' 11. Reid I Pool Colville River Field I Alpine Oil Pool Measured Depth 114' 2454' True vertical Depth 114" .2343' 7671' 72031 RECEIVED OCT 0.9 2001 Alaska Oil & Gas Cons. CommisSIon Anchorage 7" Baker 83 Permanent Packer @ 7297' MD, Cameo 8al-o @ 2101' MD Description summary of propos~1 - Detailed operations program - . BOP sketch - Refer to àttached morning drilling report for LOT test. surface cement details and casing detail sheets, schematic _X 14. Estimated date for commencing operation . 15. Status of well classification as: . October 22, 2001 . 16. If proposal was verbally approved 13. Attachments Oil_X Name of approver Date approved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE O'NL Y Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test.:..-. Location clearance - . , -\ ~ (' Mechanical I g Test- entfonn required 10- '{lI..~,,~ Title: Alpine Drilling Team Leader Form 1 Q.403 Rev 06115/88 . nt JPJ '[ATF ---------.--- .Gas- Suspended - Questions? Call Vem Johnson 265-6081 Date 1010'( 0 , Commissioner' Approval no. 0 "C\..~ b r- . Date SUBMIT IN TRIPLICATE (: (r _PHilLIPS Alaska, Inc. Casing Detail 9 518" Surface Casing Well: Date: CD2~14 9/21/01 A Subsidiary of PHilLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LOS 36.80 FMC Gen V Hanger 2.95 36.80 Jts 3 to 57 55 Jts 9-5/8" 36# J-55 BTC Csg 2333.62 39.75 Davis Lynch Float Collar 1.53 2373.37 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 77.50 2374.90 Davis Lynch Float Shoe 1.71 2452.40 9- 5/8" shoe @ 2454.11 TO 12 1/4" Surface Hole 2464.00 RUN TOTAL 32 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #3) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52,54 Last 8 joints stay out # 58 thru # 65. Use Best-O-Life 2000 pipe dope Remarks: Up Wt -160 k On Wt -140 k Block Wt - 70 Supervisor: Don Mickey ( ( PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Report #: Start: 1 9/18/2001 Cement Job Type: Primary Prima Hole Size: 12.250 (in) Hole Size: TMD Set: 2,454 (ft) SQ TMD: (ft) Date Set: 9/22/2001 SQ Date: Csg Type: Surface Casing SQ Type: Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: . S ueeze Casin Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Page 1 of 2 Spud Date: 9/20/2001 Report Date: 9/23/2001 End: Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe Movement: Reciprocating Rot Time Start: : Rec Time Start:08:30 Time End: : Time End: 11 :00 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 165,000 (Ibs) Drag Down: 125,000 (Ibs) Type: Cement Casing Volume Excess %: 300.00 Meas. From: Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 500 (psi) Start Mix Gmt: 11 :20 Start Slurry Displ: 12:30 Start Displ: 12:30 End Pumping: 13:00 End Pump Date: 9/22/2001 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: 7.00 (bbl/min) 7.00 (bbllmin) Y 760 (psi) 1,100 (psi) 5 (min) Y Returns: full returns Total Mud Lost: (bbl) Gmt Vol to Surf: 125.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: Type: Spud Mud Density: 9.6 (ppg) Visc: 50 (s/qt) Bottom Hole Circulating Temperature:68 (OF) Displacement Fluid Type: Mud PV/YP: 20 (cp)/17 (lb/100ft2) Gels 10 sec: 7 (lb/100fF) Gels 10 min: 27 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 165.90 (bbl) Slurry Data Fluid Type: PRIMARY Slurry Interval: 1,812.00 (ft)To: (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 2 Description: AS Lite Gmt Vol: 297.0 (bbl) Slurry Vol:376 (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: Density: 10.70 (ppg) Yield: 4.44 (fP/sk) Water Vol: (bbl) Other Vol: 0 Purpose: FILLER GEM Mix Water: (bbl) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 9/25/2001 3:37:10 PM ( ( PHILLIPS ALASKA INC. Cementing Report Page 2 of 2 Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Report #: Start: 1 9/18/2001 Spud Date: 9/20/2001 Report Date: 9/23/2001 End: Stage No: 1 Slurry No: 2 of 2 Slurry Data Fluid Type: TAl L Description: Slurry Interval: 2,454.00 (ft}To: 1,954.00 (ft) Cmt Vol: 49.0 (bbl) Water Source: Slurry Vol:240 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (fP/sk) Water Vol: (bbl) Other Vol: 0 Purpose: SHOE INTEG Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 16.10 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pas Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation . .Interþretation 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: N Number of Remedial Squeezes: Printed: 9/25/2001 3:37:10 PM f (' ,.-- ~ I < PIIIWPS ~ Phillips Alaska, Inc. m Daily Drilling Report Well Sidetrack AFE 24 H rs TMD TVD DFS REPT NO. DATE Prog CD2-14 CD2-14 998D09 O' 2,465' 2,353' 2.13 3 9/22/01 Supervisor Don Mickey Proposed TMD 10,699' Pressure Test(s) Rig Name Doyon 19 Daily Cost $172,029 Type I Date I TM D I TVD I MW I Press Tot. press I EMW Field Name Alpine Cumulative Cost $629,137 110'10'10 ppglO psilO.OO psilO.OO ppg Current Status Circ - Prep to test Last Safety Last BOP Test casing Meeting Event Code ODR Incident 1st 24 hrs¡' Next BOP Test Finish BOP test - 24 HR Forecas ~/U BHA - Test Csg - Drill 8 1/2" hole Last Survey TMD: INC: Azim: Last Casing Next Casing 9/24/01 6,255 0.66 126.27 9.625 (in) (êi¿ 2454 7 (in) @ 7698 Operations Summary From To Hours Phase ~ctivity SubcodE Time TroublE Operation Class 00:00 02:00 2 SURFAC DRILL PULD P Finish laying down BHA 02:00 03:00 1 SURFAC CASE RURD P Rig up to run 9 5/8" casing 03:00 08:00 5 SURFAC CASE RUNC P PJSM - Ran 57 jts. 9 5/8" 36# J-55 BTC w/ shoe @ 2454' - float collar @ 2373' 08:00 08:30 0.5 SURFAC CASE RURD P RIg down tongs - fill up tool - M/U cmt head - blow down top drive 08:30 10:30 2 SURFAC CEMENT CIRC P Circulate & condition mud for cement job PJSM - Cement 9 5/8" csg : pumped 40 bbls viscosified water w/ nut plug - drop btm plug - 50 bbls Arco spacer @ 10.5 ppg - mix & pump 10:30 12:30 2 SURFAC CEMENT PUMP P 297 bbls (376 sxs) 10.7 ppg AS 3 LIte - Observed nut plug marker @ shakers - switch to ail slurry 49 bbls (240 sxs) 15.8 ppg Class G - drop top pluq wI 20 bbls fresh water Displace cement wi 9.6 ppg mud @ 7 bblsl min - 550 to 760 psi - slow pump to 3.5 bbls/ min for 12:30 13:00 0.5 SURFAC CEMENT DISP P last 26 bbls of displacement - bumped plug w/ 165.9 bbls - CIP @ 1300 - floats held - full returns w/ 125 bbls 10.7 ppg cmt returns to surface 13:00 14:00 1 SURFAC CEMENT PULD P Rig down cement head - L/ D landing jt. - 14:00 15:00 1 SURFAC CEMENT OTHR Clean up after cmt job - flush 20" Hydril & flow line 15:00 16:30 1.5 SURFAC DRILL PULD P PJSM - N/U 20" Hydril & diverter system 16:30 18:30 2 INTRM 1 DRILL PULD P Install FMC Unihead & test to 1000 psi for 10 mins 18:30 21:00 2.5 INTRM 1 DRILL OTHR P N/U 13 5/8 5K BOPE - change top drive saver sub 21:00 00:00 3 INTRMl DRILL OTHR P PJSM - Rig up test equipment - test BOPE 24 Hr. L/D BHA - Run & Cmt 9 5/8" casing - Test BOPE Sum: (' f!' ( Injection Date Source Volume Destination Total for destination 9/22/01 CD2-14 1,827 CD2-24 29,613 Source Total: 2.962 Mud Data Compan1 Mud Density FV PV/YF 10sec / 10 min / WL/HTHF MBT PH Flowline Drilling Type 30 min Gels Temp Solids M-I Spud Mud 9.6 44 8/16 4/11/15 10.870 22.5 8 0 2.4 Bits Bit/Run Size Manuf. Type Serial Jets or TFA Depth Date I-O-D-L-B-G-O-R No. In In 2/2 8.5 HYCA DS70FHPV 24312 1/0.34375/0.34375/0.34375 2465' 9/23/01 0-0-- u- - ~, ..~ Well Name: CD2-14 CASING TEST and FORMATION INTEGRITY TEST Date: 9/23/01 Supervisor: D. Mickey Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Setting Depth: Casing Size and Description: 9 5/8", 36#, J-55, BTC CSG Hole Depth: 2,485' TMD 2,373' TVD Mud Weight: 2,454' TMD 2,331' TVD 9.6 ppg 31' Length of Open Hole Section: = 790 psi 0.052 x 2,331' + 9.6 ppg EMW= Leak-off Press. + Mud Weight 0.052 x TVD EMW for open hole section = 16.1 ppg Used cement unit Ria pump used NO #2 Pump output = 0.0997 bps Fluid Pumped = 0.9 bbls Fluid Bled Back = 0.8 bbls 2,Boo psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,BOO psi W 1,700 psi r::t:: 1,600 psi ::J 1,500 psi en 0, en 1,40 pSI W 1,300 psi r::t:: 1,200 psi a. 1,100 psi 1,000 psi 900 psi BOO psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 ¡ , . I oJ~-;', I I ;!C--r ,- -,,-~,~=-:':~""":£=-r-"'~ I -- I TIME LINE _I.of>JI;;: MINun;: TIC(~ I - " -t- ~LEAK-OFF TES-r- i ~CASINGTEST ' - n LOT SHUT IN TIME ~- CASING TEST SHUT IN TIME ~TIME LINE I I , .. , "'~.~,........,...,.....,,!~ ¡ 1 1 10 20 30 STROKES 40 so NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA i I i 1 j I j I J I MINUTES FOR LOT STROKES PRESSURE r----------u---r-----------r--------------" : I 0 I 50 psi I }-----------+------------~-------------.- --i : I 1.0 I 150 pSI: L-------------~------______L___-----------" I i 2.0 ! 220 psi i t--------- ----....--------_u_--~-- --------- -----.. ! ! 3.0 ! 280 psi I r-- ---- - -- - -- -.--- - -- ----- - -r- - - - - - -- --- - - - - -., : : 4.0 : 360 psi I }-------------+------------~------------.--i : : 5.0 : 450 pSI I ¡-- ----- - -- --1--- -6~Õ-- - - - -! - - - 5Ö-Õr> sc-1 t------------""-------------~------------- -.. ! ! 7.0 ¡ 640 psi i r - - ---- --- ---- -.- - ----- --- - - - - r - - -- ----- - - - - , : : 8.0 : 730 psi: } - -- -- --- --- - + -------- - - - -- ~ _u- - ---- - - -. - - - i : : 9.0 : 790 pSI: L-----------~--------______L____----------" . , I . . , I . I I I . t------------""------------~-- --- -----------.. I I I , I I I I I , I , r--------- - -----.----------- --- r----- ----- --- --, I I I , I I I , }----------+--------------~ ----- ------ --- --i I I I , I I I , L- ------------~--------- ------ L ----- ---------.. I . I , I I I , I I . I t------------""-------------~--------------" I I . I . I . I . I , I r - ---- - -- - - - -.- ------- - - -- r - -- - ---- -- -., . I . I . , I I }------------+-- --------- ---~------------- --i I I I I I I I I L---------- ----~---------- ___L__-_----- --- --.. I I I I I I I I I I I , t- - ----- - - - -- -.... -- - ------ -- - ~ - -- - - -- --- - - - -.. I I I I I I I I I I I I r- ------------.--------------r ----------------, I I I I I I I I }-----------+-------------~--------------i I I . I I I . I L______-------~----------- __L______-------" . I I I . . I I . I I I t----------------+- , I I I I I . I I I I I ' , : SHUT IN TIME: SHUT IN PRESSURE }---------:----+-------------r-----------:---" I 0.0 mm : I 790 pSI I L- - ---- - --- - - ~ - - -------- - - L -- - -- --- - - - -.. ! 1.0 min I I 760 psi I t-----------""--------- - ---~---------- ----.. ! 2.0 min ! I 750 psi I r------------'- -----------r----------- ----, : 3.0 min : : 750 psi: } - ------ no_. -- + - - ------- - - - - - + - - -- ----- -. - - - i : 4.0 mm : : 740 pSI I L-------------~-------_____-L- - ------------.. I 5 0 . I I 730 . I ; . mm I I pSI: t-------------""------------~- --------- --- --.. ! 6.0 min ¡ I 720 psi I r-----------.---T-------------r-----------.--' I 7.0 mm I I 720 pSI I }------:----+--------------+------------ -.--- i : 8.0 mm : : 710 pSI: L--------- -----~------- ---- _-L---- --------- --.. ¡ 9.0 min I ! 710 psi I t-------------""--------------~--------------" L]-Q-=-q_~l!:._.L___-------- - -L _!.~-~J1.~}- -.J 60 ~PHILLIPS Alaska, Inc. ~ A SLbsidiary of PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE r-------------"'------ ---------.,--- -------------, : I 0 stks: 0 psi: ~--------------+--- -------- -- - +----- -------- --t : : 2 stks : 130 psi: ¡---------- ---- r--ifstks--- r-- 32õ"jišf-1 ~--------- - - ---....- -----------....-- -- -------- --_of I I 6 stks ! 540 psi I r---------- - ---.----- ----------.-- - ----------- ---, I I 8 stks I 840 psi I 1'-- --------- - --+-------------+- ------------ _not I I 10 stks I 990 psi I ¡------------ --or -T2sikš--r1~1"š(fpsrî ~-------- ------ ...----- ------....---------- --. ~---------------L-~--!_!!~-~- -+-_!!~-QQ_P.~} --1 : : 16 stks I 1,460 psi I ~---------------+--- --------- +--- - - - ____on_. --t L______- ---___L_~_~_!!!<_~-- L_! !~- ~Q_P.~~_..1 ! ! 20 stks ! 1,840 psi! ~--- ------- - ----... ------------- ....--- --- --------. ! ! 22 stks ¡ 2,080 psi I r-- - -----------..,.--------------.---- ------------, : I 24 stks : 2,440 psi I ~-- ---------- --+ _____n_-_-- +--- - -- --------.-- t : I 25 stks : 2,520 pSI I L-- --------- --.....--- - ---------..... -- -- --- ------ --- 0 I I I I . I I I I I I I . -------------...---- - --------... - ----- ---- - -_of I I I I I I I I I I I I r ------------- ..,.-- - ------- -- -..,. -- ----- ----oo--, I I I I I I , I ~-------- - ---+--- ------- -- +-- - ----------t I I I I . I I I L_- -------- -----.....-------------.....-- - ---- ----- _n_O I I I I I I I I I I I I ~-- - -------- - -...----------- --....- ------ ------ --. . I I I I I I I I I I I I SHUT IN TIME I SHUT IN PRESSURE ~_u_------:-- -+----- --------..- -- ----- ------:--1 I 0.0 mm I : 2,520 pSI: L - -----------.....-- - ------- -- -..... --------______0 ¡ 1.0 mín I ¡ 2,500 psi! ~---------- ---- ...-- ------ - - - ....--- - - ------- ----f ! 2.0 mín I ! 2,500 psi! r- ----------- ..,.--- ------ - ----.-- -- - -- ------ ---, : 3.0 min I I 2.500 psi: ~----------: ----+-------- ----+- - -- ----------.--t : 4.0 mm : I 2,490 pSI I L-- --------- ----.....-- -------- -- --.....--- - -------- --- 0 ¡ 5.0 mín ! ¡ 2,490 psi! ~-- ------- ----...--------- ----....-- -- -- ----------. I 6.0 min ! I 2,490 psi: r-------------- --.-- --- ------ -----.-- ---- ----------{ : 7.0 min : I 2,490 psi: ~----------:---+------------ +-- --- ------ --:--t L- - ~.:Q-~~ E!_L- - ------- ____L~! ~~Q_P.~~_.1 ¡ 9.0 min ! ¡ 2,480 psi I ~--- -------- ----.... ---- ------ ----...- - ------------. I 10.0 min ! I 2,480 psi I r-- ----------.- -------------.-- - -------------, I 15.0 min : I 2,480 psi I }- ------ --~- --+----- ------ ---+ -------------.--t : 20.0 mln I : 2,470 pSI: L-- - --------- --- .....-- - ------ - - - .....--- - -- ------ -- __0 ! 25.0 min I ! 2,470 psi! ~---------- - --- ...-- - ------- -- --...- --- -- ------ ---. L}-Q.:9.-~ i ~--.L-- -------- --- L~!~ ?Q_P.~}.J ~" ~. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY { ( Casing Detail 7" Intermediate Casinq Well: Date: CD2~14 9/26101 Phillips Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 35.20 FMC 11" X 7" Hanger 1.79 35.20 Jts 3 to 186 184 Jts 7" 26# L-80 BTCM Csg 7547.27 36.99 7" Davis Lynch Float Collar 1.43 7584.26 Jts 1 to 2 2 Jts 7" 26# L~80 BTCM Csg 83.24 7585.69 7" Davis Lynch Float Shoe 1.75 7668.93 7670.68 8-1/2" TD 7681.00 1 straight blade centralizer per]t # 2 & #4 - # 19, # 126, 127 128 then every other it. F/ #130 to # 182 47 total centralizers Use Best-a-Life 2000 pipe dope Remarks: Up Wt =300 On Wt = 175 Block Wt= 70K Supervisor: Don Mickey ('" .~' ~~, PHILLIPS ALASKA INC. Cementing Report Page 1 of 2 Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Report #: Start: 2 9/18/2001 Spud Date: 9/20/2001 Report Date: 9/29/2001 End: Cement Job Type: Primary Prima Hole Size: 8.500 (in) Hole Size: TMD Set: 7,671 (ft) sa TMD: (ft) Date Set: 9/29/2001 sa Date: Csg Type: Intermediate Casing/Li sa Type: Csg Size: 7.000 (in.) Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cement Co: Dowell Schlumberger S ueeze Casin Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe Movement: Reciprocating Rot Time Start: : Rec Time Start:OO:OO Time End: : Time End: 01 :30 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Max Torque: (ft-Ibf) Drag Down: (Ibs) Stage No: 1 of 1 Type: Cement Casing Start Mix Gmt: 00:45 Disp Avg Rate: 7.00 (bbl/min) Returns: full circ Volume Excess %: 40.00 Start Slurry Displ: 00:55 Disp Max Rate: 7.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: Start Displ: 01:00 Bump Plug: Y Gmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 01:45 Press Prior: 800 (psi) To Cementing: 1.50 End Pump Date: 9/29/2001 Press Bumped: 1 100 (psi) Ann Flow After: N Mud Circ Rate: 294 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: Mud Circ Press: 790 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Mud Data Type: Non-Disp. LS Density: 9.7 (ppg) Visc: 41 (s/qt) Bottom Hole Circulating Temperature: CF) Displacement Fluid Type:Mud PVIYP: 8 (cp)/22 (lb/100ft2) Gels 10 sec: 8 (lb/100ft2) Gels 10 min: 10 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.0 (ppg) Volume: 290.00 (bbl) Stage No:1SlurryNo:1 of3 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: ARCO wash Gmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (ftJ/sk) Other Vol: 0 Purpose: SPACER Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Printed: 10/1/2001 9:33:05 AM ( { PHILLIPS ALASKA INC. Cementing Report Page 2 of 2 Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Report #: Start: 2 9/18/2001 Spud Date: 9/20/2001 Report Date: 9/29/2001 End: Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: ARCO Spacer Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) 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: PRIMARY Description: Slurry Interval: 7,671.00 (ft)To: 6,884.00 (ft) Cmt Vol: 31.0 (bbl) Water Source: Slurry Vol:138 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: 16.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) . Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 12.50 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pas 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: N Number of Remedial Squeezes: Printed: 10/1/2001 9:33:05 AM { (' r-. I ~ PIIIWPS Phillips Alaska, Inc. 1m) Daily Drilling Report Well Sidetrack AFE 24 H rs TMD TVD DFS REPT NO. DATE Prog CD2-14 CD2-14 998D09 0' 7,681' 7,203' 9.13 10 9/29/01 Supervisor David Burley Proposed TMD 10,699' Pressure Test(s) Rig Name Doyon 19 Daily Cost $170,800 Type I Date I TMD I TVD I MW I Press Tot. Dress I EMW Field Name Alpine Cumulative Cost $1,648,739 FIT 19/29/0117701'17203'19.6 ppglll00 psi4,692.15 psi12.54 ppg Current Status Driling ahead from Last Safety 9/23/01 Last BOP Test 9/29/01 7857'. Meeting Event Code ODR Incident 1st 24 hrs ~No Next BOP Test 10/6/01 24 HR Forecas Drill 6 1/8" horizontal hole Last Survey TMD: INC: Azim: Last Casing Next Casing 9/30/01 8,619 90.86 332.48 7 (in) @ 7671 4.5 (in) @ 7400 ~ Operations Summary From To Hours Phase Activity SubcodE Time TroublE Operation Class 00:00 00:30 0.5 INTRMl CEMENT CIRC P Circ and cond mud, final rate 7 bpm, 790 psi. PJSM. fest cement lines to 3500 psi. Pumped 20 bbls of wash and 40 bbls of 12.5 ppg spacer, cemented 00:30 02:00 1.5 INTRMl CEMENT PUMP P casing with 31 bbls of 15.8 ppg cement. Displaced with 9.6 ppg mud using rig pumps, bumped pluqs floats held. CIP @ 0145 hours. 02:00 03:00 1 INTRM 1 CEMENT PULD P RD cement head and landing joint, clear equipment from floor. 03:00 04:00 1 INTRMl CASE PTCH P Pull thin wear bushig, install and test Packoff to 5000 psi. 04:00 05:00 1 INTRM 1 CASE NUND P Change top pipe rams to 3-1/2" x 6", change drive sub on top drive to 4" XT-39. Install test plug and test BOPE. Tested annular Preventor to 250/3500 psi. Test pipe rams, blind rams, choke, kill, manifold, top Drive and surface 05:00 10:30 5.5 INTRMl WELCTL BOPE P safety valves to 250/5000 psi. Perform Accumulator test, pull test plug and install wear bushing. John Spaulding (AOGCC) witnessed BOPE tests. 10:30 12:30 2 INTRMl DRILL PULD P MU BHA # 5. 12:30 13:00 0.5 INTRMl RIGMNT RSRV P Service Top Drive and Traveling Block. PU 4" drill pipe, shallow test MWD @ 950'. 13:00 18:00 5 INTRMl DRILL TRIP P Continue to PU drill pipe (60 jts.) and RIH to 6470'. 18:00 19:00 1 INTRMl RIGMNT RSRV P Slip and cut drilling line. 19:00 20:00 1 INTRMl DRILL TRIP P RIH, wash down from 7430', tagged cement @ 7520'. 20:00 20:30 0.5 INTRMl CEMENT COUT P Clean out cement from 7520' to 7565', circ 15 min. 20:30 21:30 1 INTRMl CASE DEQT P Blow down Top Drive, RU and test 7" casing to 3500 psi for 30 min. Blow down surface lines. ""._:11 -.... ------.. "'--.. --..:-----.. ---' .--..1..-'- ..- :n:3U L.:S:.:SU L !I\j I K .t:lvlt:l\j I U::>HU t-' 1111', l~tS4', 1""::> c.gJ 1011'. un'l LU' or new . hole to 7 I \J 1'. 23:30 00:00 0.5 INTRM11 CEMENT FIT P Circ and cond mud for FIT. 24 Hr. Condo mud & cmt. 7" Prod. casing. RU and test BOPE. MU BHA # 5 & RIH. Test casing to 3500 psi. Clean out Sum: cement and Drill 20' of new hole to 7701', circ for FIT test. ( ~( Injection Date Source Volume Destination Total for destination 9/22/01 CD2-14 1,827 Çj)2-24 29,613 Source Total: 2962 Mud Data Compan" Mud Density FV PV/YF 10sec / 10 min / WL/HTHF MBT PH Flowline Drilling Type 30 min Gels Temp Solids M-I Non-Disp. 9.6 41 8/17 6/11/13 7.2/ 13.6 17.5 9.2 67 4 LS Bits Bit/Run Size Manuf. Type Serial Jets or TFA Depth Date I-O-D-L-B-G-O-R No. In In 5/5 6.125 HUGHES- STR386DG2K 1903819 /0.46875/0.46875/0.46875 7681' 9/29/01 0-0-- --- - CHR ~. ....1 l ( ".- ~ < PltIWPS) Phillips Alaska, Inc. (W Daily Drilling Report Well Sidetrack AFE 24 Hrs TMD TVD DFS REPT NO. DATE Prog CD2-14 CD2-14 998009 1,083' 8,764' 7,173' 10.13 11 9/30/01 Supervisor David Burley Proposed TMD 10,699' Pressure Test(s) Rig Name Doyon 19 Daily Cost $205,360 Type I Date I TM D I TVD I MW I Press Tot. press 1 EMW Field Name Alpine Cumulative Cost $1,854,099 FIT 19/29/0117701'17203'19.6 ppglllOO psi4,692.15 psi 112.54 ppg Current Status Drilling ahead at Last Safety 9/30/01 Last BOP Test 9/29/01 9147'. Meeting Event Code ODR Incident 1st 24 hrs .No Next BOP Test 10/6/01 24 HR Forecas Drill 6 1/8" 10rizontal hole Last Survey TMD: INC: Azim: Last Casing Next Casing 9/30/01 8,619 90.86 332.48 7 (in) ((ii 7671 4.5 (in) @ 7400 Operations Summary From To Hours Phase ~ctivity SubcodE rrime TroublE Operation Class 00:00 01:30 1.5 INTRM1 CEMENT FIT P CBU, perform FIT to 12.5 ppg EMW. Drill from 7701' to 8764' (7173' TVD) . ART= 12.3 01:30 00:00 22.5 PROD DRILL DRLH P ~ST=2.8 Pumped 25 bbl 180 FV sweep @ 8120' and 20 bbl 300 FV sweep @ 8526', slight increase in cuttinqs with sweeps. 24 Hr. Perform FIT to 12.5 ppg EMW. Drill 6-1/8" hole from 7701' to 8764'. Sum: Surveys MD Incl. Azimuth TVD N/S Cum E/W Cum V. Section Dog Leg Build Deg/l00' 7,758.00 92.13 333.66 7,204.72 1 001.51 211.39 783.43 5.6 5.07 7,855.00 92.3 329.89 7.200.97 1,086.90 165.56 880.34 3.89 0.18 7,949.00 92.92 331.98 7.196.69 1,168.97 119.94 974.23 2.32 0.66 8 046.00 91.57 332.29 7,192.89 1,254.65 74.64 1071.15 1.43 -1.39 8 140.00 92.33 333.95 7,189.69 1,338.45 32.17 1165.07 1.94 0.81 8 236.00 91.06 331.51 7,186.85 1,423.73 -11.79 1261.01 2.86 -1.32 8 331.00 91.34 332.27 7.184.86 1,507.51 -56.54 1355.98 0.85 0.29 8427.00 91.89 332.47 7.182.16 1,592.52 -101.05 1451.94 0.61 0.57 8 523.00 92.33 333.46 7.178.62 1.677.97 -144.65 1547.86 1.13 0.46 8 619.00 90.86 332.48 7,175.95 1,763.45 -188.26 1643.8 1.84 -1.53 Injection Date Source Volume Destination Total for destination 9/22/01 CD2-14 1,827 ,c.Q2..:..2.4: 29,613 Source Total: 2962 ( (' Mud Data Compan} Mud Density FV PV/YF 10sec / 10 min / WL/HTHF MBT PH Flowline Dri lling TvDe 30 min Gels Temp Solids M-I Non-Disp. 9.2 50 10 / 24 11/13/13 3.4 / 8 1.2 9.2 94 1.3 LS Bits Bit/Run Size Manu'. Type Seria I Jets or TFA Depth Date I-O-D-L-B-G-O-R No. In In 5/5 6.125 HUGHES- STR386DG2K 1903819 /0.46875/0.46875/0.46875 7681' 9/29/01 0-0-- _n - CHR ~. ~ Well Name: CASING TEST and FORMATION INTEGRITY TEST Date: Reason(s) for test: CD2-14 9/29/01 Supervisor: D. Burley D Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC X 7" 26# L-80 BTMC Hole Depth: Toe 6,922' TMD 6,797' TVD 2,454' TMD 2,331' TVD Casing Setting Depth: EMW= Mud Weight: 9.6 ppg 4,468' Length of Open Hole Section: Leak-off Press. + Mud Weight 0.052 x TVD 724 psi 0.052 x 2,331' + 9.6 ppg = EMW for open hole section = 15.6 ppg 900 psi 800 psi 700 psi 600 psi w D:: 500 psi :J U) U) W 400 psi D:: c.. 300 psi 200 psi 100 psi Pump output = bbls pumped Fluid Pumped = 10.5 bbls Fluid Bled Back = 0.0 bbls LEAK-OFF TEST """CASING TEST UU^ LOT SHUT IN TIME _:- CASING TEST SHUT IN TIME -+-TIME LINE 10 20 40 50 30 BARRELS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE r ------ ---- - -- - -.- --- ----- -- - - -- r - -- - - ------ - --- -., : : 0 I 0 psi: ~------------- +-------------~- ---------.----i : ; 0.5 : 15psi : L------------I------------ --L---------------..I i i 1.0 ! 20 psi ! .-------------+----------------~----------------.. ! i 1.5 ! 25 psi ! r------------"""-- ------------r--------- ---- -., I : 2.0 : 35 psi : ~---------------+---------------~-----------.----i I : 2.5 : 46 pSI : L-------------I---------__---L--- ----------- -..I ¡ i 3.0 ! 61 psi ! .---------------+---------------~----------------.. ¡ i 3.5 ! 86 psi ! r--------------......--------------r----------- ---- -., I : 4.0 : 116 psi: ~------------+--------------~-------------.---i : : 4.5 : 167 pSI: r--------------¡-----Kõ------ r---237-psr--1 r - ____m - - - - - - T - ---Kš- --- -- r - - - 32Š--p- si m, I I I I r--------------......---------------r---------------' I I 6.0 : 429 psi: ~ - - - ----- -- - - - - +--------- -- - - + - - -- - ----- --.-- - i : I 6.5 : 540 pSI: r------___m_¡-_---:rÕ--m-r---64-fpsr-1 r------------T----7~Š-----T-- 724-p-sr-' I I I I r--------------"""--------- ------r--- --------- - ---, : : 8.0 I 570 psi: ~------------+---------------~-------------.---i ; I 8.5 I 555 pSI: L---------------I---------------L---------------..I i ! 9.0 ! 550 psi! r----_____m_-T----9~5------r- --54-S-p-sr-, I I I I r-------------......---------------r---------------, : : 10.0 : 545 psi: ~-----------+---------------~-------------.---i : : 10.5 : 540 pSI I L______---------I---------______L---------------..I I I I I I I I I I I I I .----------------t I , I I I I I I I I I , , , 60 ¡ SHUT IN TIME ¡ SHUT IN PRESSURE ~-----------.----+---------------r-------------:---¡ : 0.0 mm ; : 540 pSI: L_-------------I--- ------______L-__-_----------..I ! 1.0 min i ! 454 psi! . - ------ -- -- - _u -+- - -------- - --- -- ~ - - ---- ---- - -- - -.. i 2.0 min i ! 444 psi! r-------------......---------------r----------------" I 3.0 min : I 435 psi: ~-----------.----+-------------+-------------.---i : 4.0 mm : I 429 pSI: L-------------I--------____---L----------------..I i 5.0 min i ! 424 psi i .----------------+- ----------- --~- ----- ----------.. ! 6.0 min i ! 419 psi i r--------------......---------------r----------------" : 7.0 min : : 414 psi: ~----------:- ---+---------------~----------- --.- --i : 8.0 mm : : 414 pSI: L__-------------I--------------L---- ------- --- --..I i 9.0 min ! ! 409 psi! .--------------+---------------~----------------.. L _12.:..(L~1~- L------------.l_--~Q~_p.~L_J ~PHILLIPS Alaska, Inc. ~ A Stbsidiary of PHilLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE r---------------"'- ------------- -...--- --- -----------, : : 0 stks: 0 psi I ~-- - ------------+ --------------+----- - ---------- f I I I I I I I I L-- - -------- --- -...- ------------...----- ------- ---, I I I I I I I I I I I I ~-- - ----- -------+---------------+-------------- --t I I I I I I I I I I I I r-- -------------.,..---- - ------ - --...... -------------- --, I I I I I I I I ~------------- --+-- -- - ------- --+--- --------- - --- f I I I , I I I I L ------------- --...---------- ---...---- --------- ---, I I I I I I I I I I I I .--- ------ -------+--- -- - ------- ---+- --- ----------- --t I I I I I I I I I I I I r _n_---- ------T-- --- ------ --T--- ---------- --1 I I I I ~-- ------- ------+--------------+ ----------------f I I I I I I I I L--- ------ ---- --...---- - ---------...-------------- --, I I I I I I I I I I I I .----------------+------------- ---+- --- -------------t I I I I I I I I I I I I rn___-------- --......-- --- ------ --.,..--- - -------- -- --, I I I I I I I I ~ - ---------- ----+ --- ------ -- --+---- ---------- -- f I I I I I I I I L- ----------- --... -- - -----------... ------------ - ---, I I I I I I I I I I I I ~- ---------- -- - --+---- ------- ---- -+--- -- ------ ------t I I I I I I I I I I I I r ----------- -- - -......---------- ----......- ------------ ---, I I I I I I , I ~---------------+- ---- ---------+- - --------------f I I I I I I I I Ln--------- ---- ...---- - ---------...-------------- --, I I I I I I I I I I I I .--- ------ ------ -+----- ------- - ---+---- ------------t I I I I ¡ ¡ : : I SHUT IN TIME: SHUT IN PRESSURE ~--------- --:----+-- --------- - --¡- --- --------:-----, : O.Omln : : 0 pSI : L_- - ------ ------...----------- ---... ------ -------- --, ! 1.0 min ! ! i .--- ---------- - --+--- - ------------+----- ---------- --t : 2.0 min : : : I I I , r-- ----------- --.,..-- - ------- ----...... --- - ---------- --, : 3.0 min : : : ~ - ---------:-- - -+ -- ------- ----+------------ ---- f : 4.0 mm : : : L - ---------- -- - -... - --------- --- --1-- - ---- ----------, ! 5.0 min ! ! ! . ----------- --- --+-------------- --+-- ----- ------- ---t ¡ 6.0 min ! i ! r- ---------- ----.,..---- -------- - -......- - ---- ----------, : 7.0 min : : : ~- ----------: - ---+- -------------+------ ----------f : 8.0 mm : : : L------------ ---...- --- -------- --...--- ----------- --, ! 9.0 min ! ! ¡ .--------- ------ -+----------------+- --- -------------t ! 10.0 mín ! ! ¡ r-- - ------ ------.,..--------- --- -...... --- - ------------, : 15.0 min I : : ~-- ------- --~- --+---------- ----+ --- - ---------- - - t : 20.0 mm : : : L- - ------- ---- --...-- ------------ ...--- --------- -- - -. ! 25.0 min ¡ ¡ ! . ------------- - --+- --- ------- --- - -+--- -- --- ----- -- --. I 30 0 . I I I L- - -_.:_-- f.!1..~~- -1---------- ----1--- - ---------- --! -" ~, NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY WELLS W/SURFACE CASING SHOE (+1- 2400' TVD) WITHIN 1/4 MILE CD2-15 CD2-15 x Y Surface Casino Shoe ASP 4 Coordinates: 370832.00 5974984.02 - Pennit Cement Casing Start End Distance from Shoe X Shoe Y Wells Permit # Date Report Tally No. of LOT Source well Ann. Vol. Date Date Object well * Coord. Coord. CD2-24, CD2-33, CD2-42 301-140 6/1/01 x x 2 CD2-33A, CD2-15 33992 6/1/01 10/10/01 1026.72 371098.46 5973992.48 CD2-33 (+A&B), CD2-39, CD2-14, CD2-24 301-186 7/13/01 x x 2 CD2-15 33999 7/16/01 10/9/01 330.93 370630.11 5974721.81 CD2-14 301-288 1 0/9/01 x x 2 NA 1370.67 372202.47 5974960.87 * Distance in feet, between surface casing shoes, in the X- Y plane ~~, --~-, ( ( ~V!Æ1fŒ (ill~ !Æ~!Æ~[\!Æ ALAS KA 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Vern Johnson Drilling Engineer Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 Re: Colville River Unit CD2-15 Phillips Alaska Inc. Pennit No: 201-159 Sur Loc: 1716' FNL, 1545' FEL Sec. 2, TIIN, R4E, UM Btmhole Loc. 260' FSL, 1063' FWL, Sec. 34, TI2N, R4E, UM Dear Mr. Johnson: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal of dril ling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing con finned by a valid Fonnation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on fonn 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD2 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pennit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 baITels through the annular space of a single well or to use that well for disposal purposes for a period . longer than one year. (' ~.. ", Permit No: 201-159 M~)1 23, 2öð 1 f1?C c¡ Page 2 of2 7/ 2 {)() / The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. /')~.... s~ (grþ Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this L day of August 2001 jjc/Enclosures cc: Departn1ent of Fish & Game, Habitat Section w/o encl. Depaliment of Environmental Conservation w/o encl. ( (' £~1~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1a. Type of Work Drill X Redrill 1b. Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry Deepen Service X Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 52' AIJ£.. feet Colville River Field 3. Address 6. Property DeSignation~,/~ ~ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADl25~~~.9b2 ~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1716' FNL, 1545' FEL, Sec.2, T11 N, R4E, UM Colville River Unit Statewide At target (=7" casing point) 8. Well number Number 613' FSL, 1863' FEL, Sec. 34, T12N, R4E, UM CD2-15 #59-52-180 At total depth 9. Approximate spud date Amount 260' FNL, 1063' FWL, Sec. 34, T12N, R4E, UM 08/30/2001 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and lVD) Property line CD2-24 14837' MD Crosses T11N to feet 89.6' at 550' MD Feet 2560 7204' TVD feet T12N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 90.3° Maximum surface 2547 pslg At total depth (TVD) 3236 at pslg 7152' TVD.SS 18. Casing program SettinQ Depth size Specifications Top Bottom Quantitv of cement Hole Casino Weicht Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2673' 37' 37' 2710' 2400' 428 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 9800' 37' 37' 9837' 7227' 132 Sx Class G N/A 4.5" 12.6# L-80 IBT-M 9451' 32' 32' 9483' 7149' Tubing 19. To be completed for Red rill , Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural RECEIVED Conductor Surface Intermediate Production Liner JUL 3 1 2001 Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch ru~IIIIIgMram X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 MC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .l~ t. (}t. R- Title Drilling Team Leader Date 7/1-'( 01 ,. Commission Use Onlv Permit ~/mber 59 I API number .~ 'i! h I APproval1~eJ I / See cover letter for 2.0 -- / 50- /0 _? - ,;2.., <:::) 'n) b Other reQuirements Conditions of approval Samples required Yes ~. Mucllog required Yes Œ£5 Hydrogen sulfide measures Yes G9J Directional survey required C9 No Required working pressure for BOPE 3M 5M 10M 15M ~ StJO ~\ '"""-\ t"\.~\.)" ~ ~ Ojhe" \.A. (\ ~ ~~ ~ \-c~ ORIGINAL SIGNED B't by order of Date 0'& /0'7/0 I Approved bv ,.... "'-..L - . Commissioner the commission Form 10-401 Rev. 7-24-89 L.I 'iii""" """'W, ""~"~ Submit in tri licate p ORIGINAL ( ( CD2-15 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12 1/4" HI/ 9 5/8" C I t - oe - aslna n erva Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuouslv durinQ interval. Well Collision None N/A Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem peratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries 8-1/2" Hole / 7" Casin Event Abnormal Pressure in Surface Formations >2000' TVO Lost circulation Interval Risk Level low Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low Miti ation Strate BOPE drills, Keep mud weight above 10.4 ppg. Check for flow during connections and if needed, increase mud wei ht. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheolo ,lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. 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 ractices, mud scaven ers 6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low Miti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheolo ,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) monitorin ,wei hted swee s. BOPE drills, Keep mud weight above 9.3 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL ( ( AI ine: CD2-15PH Pilot Hole & CD2-15 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 16. 17. 18. 19. 20. 21. 22. Procedure Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 95/8 surface casing. Install and test BOPE to minimum 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 %" hole to the intermediate casing point in the Alpine Reservoir. Run and cement 7 inch 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 minimum 3500 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. 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 4-1/2" 12.6 #, L-80 tubing with lower gas lift mandrel, DB nipple, and production 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 / 30 min. -. " Set BPV and secure well. Move rig off. CCL ~ <LI'\ \- Q \JO.- \ \ ~ L.a'::J ~ ~\ ~~ ORIGINAL ( ( Well Proximi Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-24 will be the closest well to CD2-15, 86.9' at 550" MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 86.6' at 612.5' MD. Drillina Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular PumpinQ Operations: Incidental fluids developed from drilling operations on well CD2-15 will be injected into a permitted annulus on CO2 pad or the class 2 disposal well on CD1 pad. The CD2-15 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 CD2-15 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 MC 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 below the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi = 1,086 psi Pore Pressure Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse 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 ORIGINAL. ( (" CD2-15 & CD2-15 PH DRilLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 %" Section - 6 1/8" point-12 ~" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 1 0 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4-8 10 - 15 10 minute gels <18 12 - 20 API Filtrate NC - 10 cc 130 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 12 - 14 cc/30 min 160 8.5-9.0 9.0 - 10.0 9.0- 9.5 PH 6% KCL Surface Hole: A standard high viscosity fresh water 1 gel spud mud is recommended for the surface interval. Keep flowline viscosity at ::!: 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel 1 polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining well bore stability. Production Hole Section: The horizontal production interval will be drilled with aM-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with::!: 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL ( ( Colville River Field CD2-15 Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812" ID) at 2000' TVD = 2144' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2710' MD 12400' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet lube pipe dope Cameo KBG-2 GLM (3.909" 10) & 1" Cameo OCK-2 shear valve pinned for casing side shear @ +/- 2000 psi, set 2 joints above Packer Updated 7/24/01 A 1 Injection Valve (2.125"ID) - to be installed later Packer Fluid mix: 9.6 ppq KCI Brine with 2000' TVD diesel cap Tubinq Supended with diesel Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB Nipple 2144' 2000' 4-1/2", 12.6#Ift, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 9280' 7039' 4-1/2" tubing joint (2) R3 S3 Packer (c/w handling pups) 9381' 7099' 4-1/2" tubing joint (2) R3 HES "XN" (3.725" ID) - 63.3 deg 9471' 7143' 4-1/2" 10' pup joint WEG - 64.1 deg 9483' 7149' Baker 83 Packer at +/- 9381' «200' MD above to top Alpine D) TOC @ +/- 9081' MO (+500' MO above top Alpine 0) --<'.' .. '-",<::., , '---;":'<'.:.. .. "';"'.........._.:,....:.....:..:... Top Alpine D at 9581' MD 1 7186' TVD -- ----- ----- ----- ----- ---- - ----- ----- ----- ----- ----- ----- ------, Well TD at ! 14837' MD I ! , 7204" TVD i , , ---- - ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- -----_! 7" 26 ppf L-80 BTC Mod Production Casing @ 9837' MD 17227' TVD @ 90.3 deg . ORIGINAL. ( (' Colville River Field CD2-15 Injection Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' Updated 7/24/01 ". "'. . , '.." ""'" 4-1/2" Cameo OB Nipple (3.812" 10) @ 2000' NO = 2144' MO 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2710' MO /2400' TVO cemented to surface .JA) Bonzai ECP Assembly - Baker ZXP Packer (4.75" 10) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBO) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe 4-1/2" 12.6 ppf L-80 IBT Mod. tubing run with Jet Lube Run'n'Seal pipe dope B 0 en Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBO) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide TOC @ +/- 9081' MO (+500' MO above top Alpine OJ """~<~<'<L . Cameo KBG-2 GLM (3.909" 10) & 1" Cameo OCK-2 shear valve pinned for casing side shear @ +/- 2000 psi, set 2 joints above Packer Baker 83 Packer set at +/- 9381' Well TD at 14837' MD I 7204' TVD _r~_~_~9_~~_r_~____._-_.~...... -- ---. . : @ @ : . , . . . . . . -_-~-_9-_-.-~--.--_. '.' -----_...........: 7" 26 ppf L-80 BTC Mod Production Casing @ 9837' MO / 7227' TVO @ 90.3 deg ORIGINAL i ~ ( CD2-15 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well : Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (Ibs. I (psi) (psi) MD/TVD(ft) qal) 16 114/114 10.9 52 53 9518 2710 I 2400 14.5 1086 1569 7" 9837 I 7227 16.0 3270 2547 N/A 14837 17204 16.0 3260 N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. PROCEDURE FOR CALCULATING ANTI CPA TED SURFACE PRESSURE ASP ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Iblgal 0.052 = Conversion from Ib./gal to psilft 0.1 = Gas gradient in psilft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point 1. ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D = [(14.5 x 0.052) - 0.1] x 2400 = 1569 psi OR ASP = FPP - (0.1 x D) = 3270 - (0.1 x 7227') = 2547 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3270 - (0.1 x 7227') = 2547 psi ORIGINAL ( ( 9 5/8" Suñace Casing run to 2710 MD /2400' TVD. Alpine. CD2-15 Well Cemenfulg Requirements Cement from 2710' MD to 2210' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2210' to suñace with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: System: Tail slurry: System: (2210'-1100') X 0.3132 ft3/ft X 1.5 (50% excess) = 521.5 ft3 below permafrost 1100' X 0.3132 ft3/ft X 4 (300% excess) = 1378.1 ft3 above permafrost Total volume = 521.5 + 1378.1 = 1899.5 ft3 => 428 Sx @ 4.44 fe/sk 428 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% SO01 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 fe/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 ft3/ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fe/sk 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % SO01 accelerator @ 15.8 PPG yielding 1.17 fe/sk 7" Intermediate Casing run to 9837 MD / 7227' TVD Cement from 9837' MO to +/- 9081' MO (minimum 500' MO above top of Alpine 0 formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (9837' - 9081') X 0.1268 fe/ft X 1.4 (40% excess) = 134.2 fe annular volume 80' X 0.2148 fe/ft = 17.2 fe shoe joint volume Total volume = 134.2 + 17.2 = 151.4 fe => 132 Sx @ 1.15 fe/sk 132 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk 1 By Weight Of mix Water, all other additives are BWOCement ORIGINAL c::> ::x:J - - Q - - <= ~ r-- Phillips Alaska, Inc.! {PHilLIPS i.~ --I' ... ~ -... ~JI .... . - .. -- .... .. " .....--- ~ Created by bmichael For: V Johnson Date plotted: 23-JuI-2001 Plat Reference is CD2-15 Versian6. Caardinates are in feet reference slot 1115. True Vertical Depths are reference RKB (Dayan 19). -- ..... -as Structure: CD#2 Field: Alpine Field Well: 15 Location: North Slope, Alaska I """'~1 1----- point~=-~- ~ROFI,:E C~i~ME~oT D~r~A EaS:--V~ect oe9/1J IKOP 500.00 0.00 290.40 500.00 0.00 0.00 0.00 0.00 ¡Build 3/100 1000.00 10.00 290.40 997.47 15.17 -40.79 43.49 2.00 West Sak 1045.32 11.36 290.40 1042.00 18.09 -48.67 51.88 3.00 ¡Base Permafrost 1588.19 27.65 290.40 1552.00 81.05 -217.97 232.37 3.00 lEGe 2168.32 45.05 290.40 2017.46 200.41 -539.01 574.63 3.00 Ic-4O 2394.13 45.05 290.40 2177.00 256.11 -688.80 734.32 0.00 Ic-3O 2698.45 45.05 290.40 2392.00 331.17 -890.67 949.53 0.00 19 5/8 Casing Pt. 2709.77 45.05 290.40 2400.00 333.96 -898.18 957.54 0.00 IC-20 3215.09 45.05 290.40 2757.00 458.60 -1233.38 1314.89 0.00 K-3 4757.91 45.05 290.40 3847.00 839.14 -2256.80 2405.96 0.00 iK-2 5076.38 45.05 290.40 4072.00 917.69 -2468.06 2631.18 0.00 IAlbian-97 7029.69 45.05 290.40 5452.00 1399.47 -3763.78 4012.53 0.00 Albian-96 7850.64 45.05 290.40 6032.00 1601.95 -4308.35 4593.09 0.00 1 HRZ 8975.91 45.05 290.40 6827.00 1879.50 -5054.80 5388.87 0.00 Begin Bld/Trn 9190.05 45.05 290.40 6978.29 1932.32 -5196.85 5540.31 0.00 iK-1 9277.16 50.25 298.34 7037.00 1959.00 -5255.30 5604.53 9.00 Miluveach A 9324.00 53.25 302.12 7066.00 1977.53 -5287.06 5640.97 9.00 ILCU 9436.10 60.84 310.05 7127.00 2033.05 -5362.76 5732.20 9.00 Alpine D 9581.38 71.25 318.73 7186.00 2125.98 -5457.10 5855.02 9.00 ¡Alpine 9637.06 75.35 321.75 7202.00 2166.97 -5491.18 5902.24 9.00 Target-EOC-Csg pt 9836.70 90.26 331.88 7227.00 2332.20 -5598.91 6065.22 9.00 ¡TO - Cso pt 14837.28 90.26 331.88 7204.00 6742.35 -7955.99 9936.88 0.00 ~- r --- ---,- C ::0 - - ~ - - ==== :.t:::.. r--- ¡ Created by bmichoel For: V Johnson ¡ ¡ Date pl~ited: 24-Jul-2001 ¡ i Plot Reference is CD2-15 Version/l6. ¡ i Coordinates are in ree~ reference slot 115. ¡ ¡True Verlicol Dep~hs are reference RKB (Doyon 19).¡ i ~ i i INTY.Q i 10000 9000 9500 TO LOCATION: 260' FNL, 1063' FWL SEC. 34, T12N, R4E 8500 7500 8000 Phillips Alaska, Inc. Structure: CD#2 Field: Alpine Field Well: 15 Location: North Slope, Alaska 7000 < - West (feet) 6500 5500 5000 6000 TO - Csg pt ~ ".V" "cP cs:> ~ 4500 4000 3000 3500 292.61 AZIMUTH 6065' (TO TARGET) ....Plone of Proposal.... '("- CIi,a, 0(," ~~ ,\ö{a,e k' .~e ~ .:~;\.,\¡>\.Ç\ ~\~e I>- x\:. ~t\) eöG'(\ \;.,~\}'" "'.t-,,'\ r\~ .~ ,,\Òl "y-~1- <õea,\ TARGET LOCATION: 613' FSl, 1863' FEL SEC. 34, T12N, R4E TRUE " 0) I § ~ '" <90- .1-°4Z 2500 2000 1500 SURFACE LOCATION: 1716' FNL, 1545' FEL SEC. 2, T11N, R4E 1000 500 .i;Ci'> "> cJ J¡ q,c> I ,';:;. ^i c> () "I 'V- V 0) k..J {] ~ 0 7000 6500 6000 5500 5000 4500 ^ 4000 I z 0 ., 3500 ........ ::J r---. ...., 3000 (1) CD ........ '--" 2500 2000 1500 1000 500 0 ~. .'-', C :x:J - - ~ - ~ ~ r--- Phillips Alaska, I Created by bmichael For: V Johnson ¡ ¡ Date plotted: 2-+-JuI-2001 ¡ ! Plot Reference i. CD2-15 Version'6. ¡ i Coordinates are in feet reference slot /115. i ¡True Vertical Depths are reference RKB (Doyon 19).¡ I ~ I l INTF.Q ¡ Structure: CD#2 Field: Alpine Field Well: 15 location: North Slope, Alaska! 0 700 1400 ,-.... - () () 2100 '+- '--" ..r: - Q.. 2800 () 0 - 3500 0 U .- - I..... () 4200 > () ::J 4900 I..... ~ I V 5600 6300 7000 7700 KOP 2.00 6.00 Build 3/100 15.00 West Sak 21.00 DLS: 3.00 deg per 100 ft 27.00 Base Permafrost 33.00 39.00 45.00 EOC C-40 C-30 9 5/8 Casing Pt. C-20 K-3 K-2 TANGENT ANGLE 45.05 DEG r<-,<.~ <i)-ò\ <j,"- ..,1,.~ ~ ~ <:.,"'0, -~ ~ c,'- / '(.'<õ'b" rz,o Ç) OV .I/.f' e, £: ~. -':-~c~./:$'.~e,~ <0' 'v~~~'<.o,rz, ~. "<1-<...0 b< <0 ,- ") 6/ Inc., 292.61 AZIMUTH 6065' (TO TARGET) ***Plane of Proposal". TRUE ~. .-. TARGET/FINAL ANGLE 90.26 DEG 0 700 5600 84-00 7000 7700 2100 2800 3500 4200 4900 6300 1400 Vertical Section (feet) -> Azimuth 292.61 with reference 0.00 N, 0.00 E from slot #15 9100 TD - Csg pt 15 9800 10500 11200 11900 C :::J::J - -- ~ ~ ~ ~ r--- i Cre<>ted by bmichoel For: V iohnson i i Date plotted: 24-Jul-2001 ¡ i Plot Reference is CD2-15 Versionl6. i ¡ Coordinates are in feet reference slot 1115. i ¡True Vertical Depths are reference RKB (Doyon 19).¡ i INIT~ ¡ ,-.. +- C1) C1) 6500 ...... '---' ~ +- c.. C1) 6750 0 0 0 t 7000 C1) > ~ 7250 L.. l- I V 7500 (\<.(;- iYb\ .~ '?- <õøOj èf' " fDð <0" ~~v-!: ~ ~. -'\\) ~ ~". ";)b< ~<p. 5000 5250 5500 5750 Phillips Alaska, Inc. Structure: CD#2 Field: Alpine Field Well: 15 Location: North Slope, Alaska ~ ,,\)\) <:l òe,o, \)\) 0,' Cj- Ç)v <?,' (",,0, / Ç) Qv .(;-fD eo /«:; :,..~".~ èf- '?' ~<:l -<..,6-0; <0'" ,\",. 6000 6250 292.61 AZIMUTH 6065' (TO TARGET) ***Plone of Proposol*** 6500 6750 7000 TRUE TARGET/FINAL ANGLE 90.26 DEG 7250 7500 7750 8250 8500 8750 8000 Vertical Section (feet) -> Azimuth 292.61 with reference 0.00 N, 0.00 E from slot #15 9000 9250 9500 9750 ..-- ~ ,-- TO - Csg pt 15 10000 10250 C ::x:J - - rï) - - <: :t::::. r-- """" Q;..., """"'....2500 "~"""'" "..,...., "" """""""~~;~Òà>", ~._,.<:~::::,"'...- ~">;::;~~.:w,~. CiJ.....---....---....- ------~. --"""-"- "-"'-.... --'-"'.._-..j~_OO -'-""-.- ....-......--------------.-------...-...-......-- 1700--""~ i Created by bmicl>ael For: V Johnson i Dote plotted: 24-Jul-2001 i Plot Referonce is CD2-15 Versionl6. i Coordinates ore in feet referenee slot #15. ¡True Verticol Depths ore reference RKB (Doyon 19). ! - I ~ ¡ 1NTEQ 840 800 720 680 640 760 ~.,.". 24 ~ Q~T-""'--"--' .. 1900 2100 """"" ". "" "'. 3300 1100 -"'" -'-', "'100 , ""'.'-~ 30p "', .>, . 900 ----""--- '--""._"'\-:"'""~",--,,, ll00<'\::>.'?OO_~ /i r¡ ........----------:.:.> - 150.0.. '. .. \ 1.700 -'--""""""" 3l0.Q. 70 0 .' 700 ""::';::i9ÕU",-,~,1.300\ """""~~~'7~~~Ó~ ~ ~ 1700' "- -"'--\-.---"""" ..1100.. '. '~"2. 90Ct. 0 00 -900 '- ... -"""" " /J "-""'" .. 1500\.,.... """.~Q?"".?7..~Q.;~~00 "'. .... 'o'ð "" "',. 001300 '. 100 ~\, ',', . 500 '" '\ 170er "'. \. 1100 ~.~:=;OÓ 0 ~500 r1G 70~.~0?,::-'f1 ......~~OO 1 ~ @500... ~ - ~ - )PHILLIPS( !~~~- IIf' .116.- -...---- -- Phillips Alaska, Inc.! Structure: CD#2 Field: Alpine Field Well: 15 Location: North Slope, Alaska! 600 520 480 <- West (teet) 440 400 360 320 280 240 200 160 120 80 560 Q), %.. 'ð -. -, " -'-. "'" , " " -, -'x \ 2100 +\3700 1500 .,-"'. 1 700 -', -, , -, -'-.- , . "" -, ~-~ '-~'k~ 700 . -"~- "-. '",-.'500 -. -, -',--- -~------ -, \. "".- 3500 '.~,.'900 -, \'....,.1300 -, ---~ '---",2100 -"--""'.._2,500 -',-- --~ '. "-'-. '-, , -, ", -', ", 1700 1500 1300 ""'. 1300 '. ~ 1 500 .q¿¡"<~" 900 ;J "", . '... ... ... """""">."'1'100 $ 'n...... .. -'100 ->C@ J7 40 0 40 1300 400 360 320 G ,- 280 1100 of ~ 240 480 ---. 440 200 ^ I Z 0 ..., -+ :::r 160 " -+-. ct> ct> -+ '----' ,-- 120 80 40 0 40 C) :::0 - - c-> - - ==== )::::.. I - Phillips Alaska, Inc.! Created by bmichael For: V Johnson Date plaited: 24-Jul-2001 Plat Referenœ is CD2-15 Versian'6. Coordinates are in feet reference slot 115. True Vertical Depths ore reference RKB (Doyon 19). Structure: CO#2 Field: Alpine Field Well: 15 Location: North Slope. Alaska! .. IIfØLs IIfiIo:Q 2900 2700 2600 2400 2300 2100 2000 1900 <- West (feet) 1800 1700 1600 1500 ---,- ~--~-.~900 ----" --.--..---. -""------ -~-- ~'~--"-..2700 -"'~._- --~ --~-------- ----- -~'- -"-'----. 2500 -------'----- -'----- 2200 2500 2800 Qò,,4700 '-. Cò-- - - 31 00 --c._------ , -'- ".,4500 -, -'-'-- -, ------. --'.,2900 C!:J------,--, -----, 3100 .-'-----'--- -"-- ---'---,,--- ",.~~~O , -, -, -'-.- -"., ~,1 00 ---. QJ---._}J.~-~ ------------ - --------- _<20_°______-- ----- ------_??O~----- ~ , " """ \ , '. ""- " , " '...3900 '- '~>._2700 -, " " "..3700'... " -,... .,~ 3500 \~"'" 1400 1300 1200 ~ , -',,2500 , " " """'" " " " "'. 3300 " " " " " -'«,3100 . -- -. -- '-'--"--'-._~.300 -':-. '-'-.. ~ --~-------------- ------~--.._2500 ----------- -._~-----~-- ~' 3700 ~ 24 ----"""- ---.. -------..-?~~.~ , 11100 -. 4500 ^ 1000 I , ~ , Z ~ ~ 900 0 ..., 00+- :T ---. 800 --+-. <1> <1> 00+- '--" 700 1100 1000 " --.4900 " " -, " ". '" 4700 , -- '.,2300 , '. , '. -'.. 2900 , " 900 800 " , -.. 21 00 , --- - '" 2700 -'-'e- 21 00 "-- -- " , .}100 ~ 700 1500 ~. 1400 1300 1200 --. 600 500 400 300 200 \\ \,\ \. \ \ \ \ 00 \. "...5700 \ .'." \ 'o"'1iI 5500 .. '."""" \. "<11".5300 ... '" \ """'11- 5100 '\ " \ """".,4900 \ """""",4700 '\ "". , 7100 "'"",~50'b""", 6900 """!II,4.3(j¡Q6700 ,"'. ", 6500 "'ij,,~700 """",<II4,tQC6300 \ "".,~500 êJ ",,<~,~1,00 """" 4300 \. ',<::~5900 <g-. 5900 ~ """'" \ ":"I¡\ ~7ee ~"""""""""'....;¡ZOO . """.,4100 \"-." 5500 ""..,.,,~500 6700"'" 3900 \""#~ """" 5300 6300 "'¡""" \ '<""5100, """'."",,*, 51 00 5900"'"",,~?Q? '*"~'1If4:g,t?8° \ """.. 4900 IVïl . \ 4700 ...."'"'..,,., , . 4 700 ~. 5500"\~"~~00 '+., oS ~ ".,"',....",,'" 4500 \. \, """'.,?,300 Q} """""".....~4300 ,,' ~ 7100 "~"',..,.,.1100 \ 47ÒÒ"""'~,100 " \. """""11",3900 .. 43ÒÒ,.,?900 0.... -'" 6900 \. ""'",....}700 \. ' ;;- ~ ~"'-, 6700 \. """"""",~,?OO \. , 'iI'.... """"""- 6300' """'..,~..\ 3900 7 , 7300"'~"'-:i""",--. 5900 \. 330u "'\"""',*" . .s "- 7100 6/00 """-....'--......-.-. \ 5500 \. 310Ö"""""".... ""'*""""""""'II~.!?'?"""""",*~.??,~, 5900 5500 '-'-'-'-'~".'::",-'-_.._._...-.!~~ 00 4700 \, 2900"'" 9 "'""."""""....,. "..", 5100 \. 4700 .-.....-.-.......--..---..-. 4300 \ 3900 """"'11<"".,.., "" '~"""" 4300 3900-.-.-.--.-it'OÖ'.-... 350 24 \, 11<""""" "'*""""""""II<"'\\",,~';~;'~: 24PH ~ ~ ( ( , ¡Phillips Alaska, Inc.j i".--..---- - - ----- --....-" ".. - .--.. -- - . .-..- - ..-...... ..----- -.- -... --.... -...... _._-..- ~ I Structure: CD#2 Well: 15 II L Field: Alpine Field Location: North Slope. Alaska¡ Cntatod b)I bmõchaol For: V Johnson Doto plotlod : 24-Jul-2001 Plat Relentoco is CD2-15 Vo...iao'8. Coo<",oatu are in fool reforenco slat '15. True Vorfoc:al D.pth, or. ref.renco RKB (Doyoo 19). 8iI8 UIŒ8 - IN'I1<Q ".""..."......""......"......-.."..............""."""........".."-".."...-....",,. <- West (feet) 8400 5600 4400 3600 4000 5200 4800 8000 7600 7200 6800 6400 6000 ~ \ \\\ \ , , \ , , \ \. \\ \ \.. [ill, , \ \. , \. \ \ \, \\. \"\ \ \ Q)'..~900 ""'"",6700 "-"."..,~~OO "'-1iI,~~00 ""'.,6100 """'" Q)"", ".~,100 """'"",~900 ""',....?700 """" 5500 '*""'" """",*,?,~OO '. 5100 "'.".""". 49'òèr QQ] ~ 3200 2000 7200 2800 2400 ~ \\, 6800 \'\ , 6400 6000 \.. ~ 5600 5200 4800 4400 \ .. \ , \\', 4000 ^ I z 0 .., -+ -;s- 3600 '-II- 7100 " '", 6900 , * 6700 \ em,,6500 \" 2800 \,\~ \, ~ ........... 3200 - CD CD -+ ---- 2400 2000 1600 1200 800 400 0 ORIGINAL ( ( f" ,." -, -, --'"' -. -.. -... -- - '--""-' ...-.....- -........... ............. ....... '-""""'-"-" ....... ............- ...... -... -"...-. .................. ............... -.... IPhillips Alaska, Inc. 1---....--.----.....-......--. -.-.. '--'---'---'" --.... .--.. -.... .... ¡ Structure: CD#2 Well: 15 I Created by bmÔCl>ol!! For: V Johnson 'I' I Date platted: 24-J..1-2001 I Plot RoI.,.n.. ;. CD2-" V.noionfð. I COOrdinat.. a,. in f.. I ,.foro"'" 1101 115. ITrue Vertic:al DepthS are reference RKa (Doyon 19). , - I -:=.. I 1N1'~Q , L_.... ...... -.... ......-. no ......-..........-.... -....--.. -- - ---_...._.J Field: Alpine Field Location: North Slope, Alaska 330 TRUE NORTH ~ c::J 350 0 10 210 20 340 240 30 320 40 310 50 300 60 290 70 280 80 270 90 260 100 250 110 120 230 130 220 140 /,,/ 210 // ',,- 1 50 /" ",- ///200 "-'-.......,1 60 c§5 190 180 ~ ~ Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ORIGINAL ( Phillips Alaska. Inc. CD#2 15 slot #15 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref: CD2-15 Version#6 Our ref: prop4403 License: Date printed: 23-Jul-2001 Date created: 16-Jan-2001 Last revised: 23-Jul-2001 Field is centred on n70 20 37.100.w150 51 37.53 Structure is centred on n70 20 37.100.w151 1 42.976 Slot location is n70 20 20.225.w151 2 28.083 Slot Grid coordinates are N 5974641.661, E 371696.237 Slot local coordinates are 1715.67 S 1544.32 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( ORIGINAL ( ( Phillips Alaska, Inc. PROPOSAL LISTING Page 1 CD#2,15 Your ref : CD2-15 Version#6 Alpine Fie1d.North Slope. Alaska Last revised : 23-Jul-2001 Measured Inc1in Azimuth True Vert R E C TAN G U L A R G RID COO R D S GEOGRA PHI C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COORD I N ATE S 0.00 0.00 0.00 0.00 O.OON O.OOE 371696.24 5974641.66 n70 20 20.23 w151 2 28.08 100.00 0.00 290.40 100.00 O.OON O.OOE 371696.24 5974641.66 n70 2020.23 w151 2 28.08 200.00 0.00 290.40 200.00 O.OON O.OOE 371696.24 5974641.66 n70 20 20.23 w151 2 28.08 300.00 0.00 290.40 300.00 O.OON O.OOE 371696.24 5974641.66 n70 20 20.23 w151 2 28.08 400.00 0.00 290.40 400.00 O.OON O.OOE 371696.24 5974641.66 n70 20 20.23 w151 2 28.08 500.00 0.00 290.40 500.00 O.OON O.OOE 371696.24 5974641.66 n70 20 20.23 w151 2 28.08 600.00 2.00 290.40 599.98 0.61N 1. 64W 371694.61 5974642.30 n70 20 20.23 w151 2 28.13 700.00 4.00 290.40 699.84 2.43N 6.54W 371689.74 5974644.20 n70 20 20.25 w151 2 28.27 800.00 6.00 290.40 799.45 5.47N 14. 71W 371681.62 5974647.38 n70 20 20.28 w151 2 28.51 900.00 8.00 290.40 898.70 9.72N 26.13W 371670.28 5974651.82 n70 20 20.32 w151 2 28.85 1000.00 10.00 290.40 997.47 15.17N 40.79W 371655.71 5974657.52 n70 20 20.37 w151 2 29.27 1045.32 11.36 290.40 1042.00 18 . 09N 48.67W 371647.89 5974660.57 n70 20 20.40 w151 2 29.50 1066.67 12.00 290.40 1062.90 19.60N 52 .72W 371643.86 5974662.15 n70 20 20.42 w151 2 29.62 1166.67 15.00 290.40 1160.13 27.74N 74.59W 371622.13 5974670.65 n70 20 20.50 w151 2 30.26 1266.67 18.00 290.40 1256.00 37.63N 101.21W 371595.68 5974681.00 n70 20 20.59 w151 2 31.04 1366.67 21. 00 290.40 1350.25 49.27N 132. 50W 371564.60 5974693.15 n70 20 20.71 w151 2 31. 95 1466.67 24.00 290.40 1442.63 62.60N 168.36W 371528.97 5974707.09 n70 20 20.84 w151 2 33.00 1566.67 27.00 290.40 1532.88 77.60N 208. 71W 371488.89 5974722.77 n70 20 20.99 w151 2 34.18 1588.19 27.65 290.40 1552.00 81.05N 217.97W 371479.69 5974726.37 n70 20 21.02 w151 2 34.45 1666.67 30.00 290.40 1620.75 94.23N 253.43W 371444.46 5974740.15 n70 20 21.15 w151 2 35.49 1766.67 33.00 290.40 1706.01 112. 44N 302.40W 371395.81 5974759.19 n70 20 21.33 w151 2 36.92 1866.67 36.00 290.40 1788.41 132.18N 355.48W 371343.07 5974779.82 n70 20 21. 52 w151 2 38.47 1966.67 39.00 290.40 1867.74 153.39N 412. 53W 371286.39 5974801.99 n70 20 21.73 w151 2 40.13 2066.67 42.00 290.40 1943.77 176.02N 473.40W 371225.92 5974825.64 n70 20 21. 96 w151 2 41. 91 2166.67 45.00 290.40 2016.30 200.01N 537.91W 371161.83 5974850.72 n70 20 22.19 w151 2 43.80 2168.32 45.05 290.40 2017.46 200.41N 539.01W 371160.74 5974851.14 n70 20 22.19 w151 2 43.83 2394.13 45.05 290.40 2177.00 256.11N 688.80W 371011.92 5974909.36 n70 20 22.74 w151 2 48.20 2500.00 45.05 290.40 2251.80 282.22N 759.03W 370942.15 5974936.65 n70 20 23.00 w151 2 50.26 2698.45 45.05 290.40 2392.00 331.17N 890.67W 370811.37 5974987.81 n70 20 23.48 w151 2 54.10 2709.77 45.05 290.40 2400.00 333.96N 898.18W 370803.90 5974990.73 n70 20 23.51 w151 2 54.32 3000.00 45.05 290.40 2605.04 405.55N 1090.70W 370612.64 5975065.56 n70 20 24.21 w151 2 59.94 3215.09 45.05 290.40 2757.00 458.60N 1233.38W 370470.89 5975121.01 n70 20 24.73 w151 3 04. 11 3500.00 45.05 290.40 2958.29 528.87N 1422.37W 370283.12 5975194.46 n70 20 25.42 w151 3 09.63 4000.00 45.05 290.40 3311.54 652.20N 1754.05W 369953.61 5975323.36 n70 20 26.63 w151 3 19.32 4500.00 45.05 290.40 3664.79 775.52N 2085. 72W 369624.10 5975452.27 n70 20 27.85 w151 3 29.01 4757.91 45.05 290.40 3847.00 839.14N 2256.80W 369454.13 5975518.76 n70 20 28.47 w151 3 34.01 5000.00 45.05 290.40 4018.03 898.85N 2417.39W 369294.58 5975581.17 n70 20 29.06 w151 3 38.70 5076.38 45.05 290.40 4072.00 917.69N 2468.06W 369244.24 5975600.86 n70 20 29.24 w151 3 40.19 5500.00 45.05 290.40 4371.28 1022.17N 2749.07W 368965.07 5975710.07 n70 20 30.27 w151 3 48.40 6000.00 45.05 290.40 4724.53 1145.49N 3080.74W 368635.55 5975838.98 n70 20 31.48 w151 3 58.09 6500.00 45.05 290.40 5077.78 1268.82N 3412.41W 368306.04 5975967.88 n70 20 32.69 w151 4 07.78 7000.00 45.05 290.40 5431. 03 1392.14N 3744.08W 367976.53 5976096.78 n70 20 33.90 w151 4 17.47 7029.69 45.05 290.40 5452.00 1399.47N 3763. 78W 367956.96 5976104.44 n70 20 33.97 w151 4 18.05 7500.00 45.05 290.40 5784.27 1515.47N 4075.76W 367647.01 5976225.69 n70 20 35.11 w151 4 27.16 7850.64 45.05 290.40 6032.00 1601.95N 4308.35W 367415.93 5976316.08 n70 20 35.96 w151 4 33.96 8000.00 45.05 290.40 6137.52 1638.79N 4407.43W 367317.50 5976354.59 n70 20 36.32 w151 4 36.85 8500.00 45.05 290.40 6490.77 1762.12N 4739.10W 366987.99 5976483.49 n70 20 37.53 w151 4 46.55 8975.91 45.05 290.40 6827.00 1879.50N 5054.80W 366674.35 5976606.19 n70 20 38.68 w151 4 55.77 9000.00 45.05 290.40 6844.02 1885.44N 5070. 78W 366658.47 5976612.40 n70 20 38.74 w151 4 56.24 9190.05 45.05 290.40 6978.29 1932.32N 5196.85W 366533.22 5976661.39 n70 20 39.20 w151 4 59.93 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #15 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 10428.68 on azimuth 310.28 degrees from wellhead. Total Dogleg for we11path is 103.25 degrees. Vertical section is from wellhead on azimuth 292.61 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL ( ( PhillipS Alaska, Inc. PROPOSAL LISTING Page 2 CD#2,15 Your ref : CD2-15 Version#6 Alpine Fie1d,North Slope, Alaska Last revised: 23-Jul-2001 Measured Inclin Azimuth True Vert R E C T A N G U L A R G RID COORDS G E 0 G RAP HI C Depth Degrees Degrees Depth COO R DIN A T E S Easting Northing COO R DINATES 9200.00 45.61 291.37 6985.28 1934.84N 5203.46W 366526.66 5976664.03 n70 20 39.23 w151 5 00.12 9277.16 50.25 298.34 7037.00 1959.00N 5255.30W 366475.23 5976689.06 n70 20 39.46 w151 5 01. 63 9300.00 51. 70 300.22 7051.38 1967.68N 5270. 78W 366459.91 5976698.00 n70 20 39.55 w151 5 02.09 9324.00 53.25 302.12 7066.00 1977.53N 5287.06W 366443.80 5976708.12 n70 20 39.64 w151 5 02.56 9400.00 58.34 307.64 7108.73 2013. 52N 5338.52W 366392.95 5976744.97 n70 20 40.00 w151 5 04.07 9436.10 60.84 310.05 7127.00 2033.05N 5362.76W 366369.05 5976764.91 n70 20 40.19 w151 5 04.78 9500.00 65.36 314.05 7155.91 2071.23N 5405.02W 366327.44 5976803.79 n70 20 40.57 w151 5 06.01 9581.38 71.25 318.73 7186.00 2125.98N 5457.10W 366276.31 5976859.41 n70 20 41.10 w151 5 07.53 9600.00 72 .62 319.76 7191. 77 2139.39N 5468.65W 366264.98 5976873.01 n70 20 41.23 w151 5 07.87 9637.06 75.35 321. 75 7202.00 2166.97N 5491.18W 366242.92 5976900.97 n70 20 41. 51 w151 5 08.53 9700.00 80.02 325.02 7215.42 2216.31N 5527.83W 366207.12 5976950.92 n70 20 41.99 w151 5 09.60 9800.00 87.51 330.05 7226.29 2300.12N 5581.10W 366155.27 5977035.61 n70 20 42.81 w151 5 11.16 9B36.70 90.26 331.88 7227.00 2332.20N 559B.91W 366138.01 5977067.98 n70 20 43.13 w151 5 11.68 9B36.72 90.26 331.88 7227.00 2332.22N 5598. 92W 366138.00 5977068.00 n70 20 43.13 w151 5 11.68 10000.00 90.26 331. 88 7226.25 2476.22N 5675.88W 366063.49 5977213.27 n70 20 44.55 w151 5 13.94 10500.00 90.26 331.88 7223.95 2917.18N 5911.56W 365835.31 5977658.12 n70 20 48.88 w151 5 20.83 11000.00 90.26 331.88 7221.65 3358.14N 6147.24W 365607.14 5978102.97 n70 20 53.21 w151 5 27.73 11500.00 90.26 331.88 7219.35 3799.11N 6382.93W 365378.97 5978547.81 n70 20 57.55 w151 5 34.64 12000.00 90.26 331.88 7217.05 4240.07N 6618.61W 365150.79 5978992.66 n70 21 01.88 w151 5 41. 54 12500.00 90.26 331.B8 7214.75 4681.04N 6B54.29W 364922.62 5979437.51 n70 21 06.22 w151 5 48.44 13000.00 90.26 331.88 7212.45 5122.00N 7089.97W 364694.45 5979882.36 n70 21 10.55 w151 5 55.34 13500.00 90.26 331. 88 7210.15 5562.96N 7325.65W 364466.27 5980327.21 n70 21 14.89 w151 6 02.25 14000.00 90.26 331.88 7207.85 6003.93N 7561. 33W 364238.10 5980772.06 n70 21 19.22 w151 6 09.15 14500.00 90.26 331.88 7205.55 6444.89N 7797.01W 364009.92 5981216.91 n70 21 23.55 w151 6 16.06 14837.28 90.26 331.88 7204.00 6742.35N 7955.99W 363856.01 5981516.99 n70 21 26.48 w151 6 20.71 14837.30 90.26 331.88 7204.00 6742.36N 7956.00W 363B56.00 5981517.00 n70 21 26.48 w151 6 20.71 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #15 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 10428.6B on azimuth 310.28 degrees from wellhead. Total Dogleg for we11path is 103.25 degrees. Vertical section is from wellhead on azimuth 292.61 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL ( (, Phillips Alaska, Inc. CD#2,15 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: CD2-15 Version#6 Last revised: 23-Jul-2001 Comments in wellpath -------------------- -------------------- Rectangular Coords. TVD MD Comment ----------------------------------------------------------------------------------------------------------- 500.00 500.00 O.OON O.OOE KOP 1000.00 997.47 15.17N 40.79W Build 3!l 00 1045.32 1042.00 18.09N 48.67W West Sak 1588.19 1552.00 81. 05N 217.97W Base Permafrost 2168.32 2017.46 200.41N 539.01W EOC 2394.13 2177.00 256.llN 688.80W C-40 2698.45 2392.00 331.17N 890.67W C-30 2709.77 2400.00 333.96N 898.18W 9 5/8" Casing Pt. 3215.09 2757.00 458.60N 1233.38W C-20 4757.91 3847.00 839.14N 2256.80W K-3 5076.38 4072.00 917. 69N 2468.06W K-2 7029.69 5452.00 1399.47N 3763.78W Albian-97 7850.64 6032.00 1601.95N 4308.35W Albian- 96 8975.91 6827.00 1879.50N 5054.80W HRZ 9190.05 6978.29 1932.32N 5196.85W Begin Bld/Trn 9277.16 7037.00 1959.00N 5255.30W K-1 9324.00 7066.00 1977.53N 5287.06W Miluveach A 9436.10 7127.00 2033.05N 5362.76w LCU 9581. 38 7186.00 2125.98N 5457.10W Alpine D 9637.06 7202.00 2166.97N 5491.18W Alpine 9836.70 7227.00 2332.20N 5598.91W Target-EOC-Csg pt 9836.72 7227.00 2332.22N 5598. 92W CD2-15 Heel Rvsd 17-Jul-01 14837.28 7204.00 6742.35N 7955.99W TD - Csg pt 14837.30 7204.00 6742.36N 7956.00W CD2-15 Toe Rvsd 17-Ju1-01 Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE O.OOE 2709.77 9836.72 2400.00 7227.00 333.96N 2332.21N 898.18W 9 5/8" Casing 5598.92W 7" Casing Targets associated with this wel1path ------------------------------------- ------------------------------------- Geographic Location Rectangular Coordinates Revised Target name T.V.D. ----------------------------------------------------------------------------------------------------------- CD2-15 Heel Rvsd 17- 366138.000,5977068.000,0.0000 CD2-15 Toe Rvsd 17-J 363856.000,5981517.000,0.0000 7227.00 7204.00 2332.22N 6742.36N 5598.92W 7956.00W 17-Jul-2001 17-Jul-2001 ORIGINAL ( SUMMARY ( Phillips Alaska, Inc. CD#2 15 slot 1115 Alpine Field North Slope, Alaska C LEA RAN C E R E PO R T by Baker Hughes INTEQ Your ref: CD2-15 Version#6 Our ref: prop4403 License: Date printed: 24-Jul-2001 Date created: 16-Jan-2001 Last revised: 23-Jul-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 20.225,w151 2 28.083 Slot Grid coordinates are N 5974641.661, E 371696.237 Slot local coordinates are 1715.67 S 1544.32 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath PMSS <0-11984'>,,35,CD#2 MWD <0-9507'>,,42PH,CD#2 MWD <8480 - 13138'>, ,42,CD#2 MWD <0-10054'>,,24PH,CD#2 MWD <8715 - 14301'>, ,24,CD#2 MWD w/IFR <0 - ???>, ,33,CD#2 PMSS <0-7170'>, ,Neve #l,Neve #1 PMSS <1876-9940'>"A1p1A,A1pine #1 PMSS <0-3161'>, ,Alp1,Alpine #1 PMSS <1868-8850'>, ,Alp1B,A1pine #1 Reference North is True North Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 17-May-2001 199.9 0.0 0.0 27-May-2001 269.5 100.0 100.0 2-Jul-2001 269.5 100.0 100.0 18-Jun-2001 89.6 550.0 550.0 26-Jun-2001 89.6 550.0 13340.0 24-Jul-2001 179.3 100.0 100.0 16-Dec-1999 9412.6 0.0 0.0 21-Sep-1999 4119.6 1988.9 1988.9 21-Sep-1999 4335.3 0.0 0.0 21-Sep-1999 4335.3 0.0 13280.0 ORIGINAL ( ( Phillips Alaska. Inc. CD#2 15 slot #15 Alpine Field North Slope. Alaska 3-D M I N I MUM D I S TAN C E C LEA RAN C E INCLUDING POSITION UNCERTAINTIES R E PO R T by Baker Hughes INTEQ Your ref: CD2-15 Version#6 Our ref: prop4403 License: Date printed: 24-Jul-2001 Date created: 16-Jan-2001 Last revised: 23-Jul-2001 Field is centred on n70 20 37.100.w150 51 37.53 Structure is centred on n70 20 37.100.w151 1 42.976 Slot location is n70 20 20.225.w151 2 28.083 Slot Grid coordinates are N 5974641.661. E 371696.237 Slot local coordinates are 1715.67 S 1544.32 W Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets. e.g. )10.2(. where available. Object wellpath DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk. e.g. 487.4* CD2-35A Verso #2. .35A-61.CD#2 PMSS <0-11984'>. .35,CD#2 CD2-50 Vers#7. .50.CD#2 CD2-48 Version#3. .48,CD#2 CD2-25 Version#3..25,CD#2 CD2-58 Vers#3..58,CD#2 CD2-57 Vers#3..57.CD#2 CD2-56 Version#2. .56,CD#2 CD2-55 Vers#3..55,CD#2 CD2-54 Vers#5..54.CD#2 CD2-53 Vers#5..53,CD#2 CD2-52 Vers#5,,52,CD#2 CD2-51 Vers#6,,51.CD#2 CD2-49 Version#6,.49.CD#2 CD2-45 Vers#4,.45,CD#2 CD2-44 Vers#4,,44.CD#2 CD2-34 Vers#5.,34.CD#2 CD2-31 Vers#5,,31.CD#2 CD2-29 Version#3,,29.CD#2 CD2-28 Vers#6.,28.CD#2 CD2-27 Vers#6..27.CD#2 CD2-26 Version#4,,26.CD#2 CD2-22 Version#3.,22.CD#2 CD2-21 Version #? (Old 1-18),,21,CD#2 CD2-19 Vers#4..19.CD#2 CD2-18 Vers#4,.18.CD#2 CD2-11 Vers#5.,11.CD#2 CD2-10 Version#3,,10.CD#2 CD2-9 Vers#4. ,9.CD#2 CD2-8 Vers#4.,8.CD#2 CD2~7 Version#3,,7.CD#2 CD2-6 Vers#4.,6,CD#2 CD2-43 Leg#l Vers#2..43.CD#2 CD2-5 Version#5, .5.CD#2 CD2-30 Vers#5,,30.CD#2 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 8-Feb-2001 )7459.7( 2166.7 2900.0 17-May-2001 )199.3( 200.0 14837.3 9-Apr-2001 )347.8( 400.0 400.0 9-Apr-2001 )327.2( 512.5 13860.0 9-Apr-2001 )98.5( 300.0 8540.0 9-Apr-2001 )428.7( 300.0 12780.0 9-Apr-2001 )418.2( 400.0 10280.0 9-Apr-2001 )408.5( 300.0 9662.2 9-Apr-2001 )398.7( 300.0 300.0 9-Apr-2001 )388.6( 300.0 300.0 9-Apr-2001 )378.7( 300.0 9786.7 9-Apr-2001 )367.3( 512.5 12680.0 9-Apr-2001 )358.5( 300.0 300.0 19-Jun-2001 )338.3( 300.0 300.0 9-Apr-2001 )298.5( 300.0 300.0 9-Apr-2001 )288.5( 300.0 300.0 9-Apr-2001 )188.4( 300.0 300.0 9-Apr-2001 )157.2( 537.5 12940.0 9-Apr-2001 )137.1( 550.0 14837.3 9-Apr-2001 )123.3( 600.0 8900.0 9-Apr-2001 )116.7( 600.0 13140.0 9-Apr-2001 )107.2( 537.5 537.5 9-Apr-2001 )66.5( 525.0 8000.0 17-Apr-2001 )55.0( 500.0 12540.0 9-Apr-2001 )37.2( 537.5 537.5 9-Apr-2001 )27.5( 400.0 13700.0 9-Apr-2001 )39.0( 300.0 14837.3 9-Apr-2001 )48.8( 300.0 13060.0 9-Apr-2001 )58.6( 300.0 14837.3 9-Apr-2001 )68.8( 300.0 13200.0 9-Apr-2001 )78.8( 300.0 14837.3 9-Apr-2001 )88.9( 300.0 12940.0 8-May-2001 )278.5( 300.0 300.0 19-Jun-2001 )98.8( 300.0 14837.3 8-Jun-2001 )147.5( 500.0 9786.7 ORIGINAL ( CD2-41 VersH5, ,41,CDH2 CD2-40 VersionH3, ,40,CDH2 MWD <0-9507'>, ,42PH,CDH2 ~~D <8480 - 13138'>, ,42,CDH2 CD2-46 VersionH5,,46,CDH2 CD2-47 VersionH3,,47,CDH2 CD2-38 VersionH3,,38,CDH2 CD2-37PBl VersionH4,,37PBl,CDH2 CD2-39PBl VersionH12,,39PBl,CDH2 CD2-32 VersionH6, ,32,CDH2 CD2-12 VersionH3, ,12,CDH2 CD2-13 VersionH3,,13,CDH2 CD2-14 VersionH3,,14,CDH2 CD2-16 VersionH5,,16,CDH2 CD2-17 VersionH3,,17,CDH2 CD2-23 VersH8,,23,CDH2 CD2-20 VersionH5,,20,CDH2 MWD <0-10054'>,,24PH,CDH2 MWD <8715 - 14301'>, ,24,CDH2 33 VersionH11,,33,CDH2 MWD w/IFR <0 - ???>,,33,CDH2 PMSS <0-7170'>, ,Neve Hl,Neve H1 PMSS <1876-9940'>"AlplA,Alpine HI PMSS <0-3161'>"Alpl,A1pine HI PMSS <1868-8850'>"AlplB,Alpine #1 9-Apr-2001 9-Apr-2001 27-May-2001 2-Jul-2001 9-Apr-2001 14 -Mar-2001 9-Apr-2001 12 -Jul-2 001 13-Jul-2001 19-Jun-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 14-Mar-2001 14-Mar-2001 18-Jun-2001 26-Jun-2001 20-Jun-2001 24-Jul-2001 , 16-Dec-1999 21-Sep-1999 21-Sep-1999 21-Sep-1999 ) 257.2 ( ) 247.6 ( ) 268.4 ( ) 268.4 ( )307.2( ) 318.5 ( )228.3( ) 218.5 ( ) 238.4 ( )167.4( ) 22.6 ( ) 18.6 ( ) 8.1 ( ) 8.3 ( )17.2 ( ) 77.2 ( ) 36.3 ( ) 86.6 ( ) 86.6 ( ) 176.6 ( ) 177.5 ( )9410.3( ) 4051.3 ( ) 4333.7 ( )4333.7( 525.0 400.0 400.0 400.0 537.5 300.0 400.0 300.0 300.0 537.5 800.0 300.0 400.0 300.0 537.5 537.5 13 88.9 612.5 612.5 525.0 400.0 600.0 2077.8 512.5 512.5 ( 11560.0 400.0 400.0 400.0 537.5 300.0 400.0 11320.0 300.0 9212.9 14440.0 14200.0 7060.0 11520.0 7720.0 12840.0 14440.0 9442.5 13980.0 525.0 7200.0 12040.0 4480.0 512.5 13280.0 ORIGINAL (' ( Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 24, 2001 Re: Application for Permit to Drill CD2-15 RECEIVED JUL 3 1 2001 Alaska Oil & G as Cons C . Anchorag~ ommlssion Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Water Alternating Gas (WAG) injection well from the Alpine CD2 drilling pad. The intended spud date for this well is August 30, 2001. It is intended that Doyon Rig 19 be used to drill the well. The CD2-15 will be drilled to penetrate the Alpine reservoir horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole injector. At the end of the work program, the well will be shut in awaiting connection to surface facilities. It is intended to pre-produce the well for up to two months prior to beginning injection. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. 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. ~IY;Z P- <--- Vern J~SO Drilling Engineer Attachments cc: CD2-15 Well File I Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin e-mail: ATO 1530 A TO 868 A TO 848 A TO 844 Anadarko - Houston Kuukpik Corporation Tommy- Thompson@anadarko.com RECEIVED JUt 3 12001 Alaska Oil & Gas Cons. Commission Anchorage ( ( d , ;, ' " . ./ ... ,'" American Expressœ Cash Advance Draft 156 PAY TO THE ORDER OF . t ,;;> DOLLARS Issued by Integrated Payment System, Inc. Englewood. Colorado Payable at Norwest Bank of Grand junction - Downtown. NA Grand Junction. Colorado PERIOD ENDING ~a-l S- I: ~ 0 2 ~ 0 0 a. 0 0 I: :. 5 III 0 ~ ? 5000 5 :. b II. 0 ~ 5 b .. ( ( 1 KANSMIT AL LETTER CHECK LIS.' CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSNUTTAL LETTER WELL NAME CLJ 2- -oj .5 CHECK 1 STANDARD LETTER D EVELO PMENT DEVELOPMENT REDRILL EXPLORATION CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTILATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL <-)NO INJECTION WELL ANNULAR DISPOSAL cL YES ý INJECTION WELL REDRILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore 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(t), 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). .. Annular disposal has not been requested. . . Annular Disposalof drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . ~=~ ~} OTHER Please note that an disposal of Ouids generated. . . J YES + SPACING EXCEPTION .. Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. 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. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ' ,.- ...-....-...- .-' , . ~' (' ( ST ATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,...... , . Type of request Abandon - Suspend - Alter casing - Repair well- Change approved program - 2. Name of Operator Philli s Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 9951 07Ü360 4. Location of well at surface 1806' FNL, 1535' FEL, Sec. 2, T11 N, R4E, UM At top of productive interval 96' FNL, 2094' FWL, Sec. 3, T11 N, R4E, UM At effective depth At total depth 1410' FNL, .24' FEL, Sec. 33, T12N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 77' Surface 2755' Production 10774' Perforation depth: measured true ve rUcal None Tubing (size, grade. and measured depth 14301' 7202' 14301' 7202' Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - . Str~tlgraphic - Service - ----- Per APD ----- Per APD feet feet feet feet Plugs (measured) Junk (measured) Re-enter suspended wel- TIme extension - Stimulate - Variance - Perforate - 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Other _X Annular Disposal 4.5812.6#, L-80 @ 10,030' MD Packers & SSSV (type & measured depth) Collevile River Unit 8. Well number C02-24 . 9. Permit number J approval number 201-095 10. API number 50-103-20377 11. Field J Pool Coleville River Field I AI ine Oil Pool Size Cemented Measured Depth True vertical Depth 16" 10 yds portland 3 ready mix emt 114' 114' 9-5/811 379 Sx AS III L & 235 SX 2792' 2372' 15.8 class G 7" 160' Sx 15.8 class e 1 0811' 7232' None RECEIVED JUL 0 6 2001 . Alaska 011 & Gas Cons. Commission Anchorage 13. Attachments 7" Baker S.3 Permanent Packer @ 9954 MD. Cameo BAL-Q SSSV @ 2137' MD Description summary of proposal ~ Detailed operations program - BOP sketch- Refer to attached morning drilling report for LOT test. surface cement details and casing detail sheets, schematic _X 14. Estimated date for commencing operation 15. Status of well classification as: July 25, 2001 16. If proposal was verbally approved Oil_X Name of a rover Date a roved SelVice - 17. I hereby certify that the foregoing Is true and correct to the best of my knowledge. FOR COMMISSION US ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug Integrity - BOP Test - Location clearance - Mechanical Integrity Test- Subsequent form required 10- ~r.\.c~~",,~~, &t.~ \ ~ M, Jie~ Commissioner Date -r IIâ/O j Signed Form 10-403 Rev 06115188. "---...... "".'-' ... .. ...-........ .... ..... ...... Title: Alpine Drilling Team Leader Gas- Suspended - Questions? CaR Vøm Johnson 265--6081 Date 76/01 DUPL1 CATE .. ... ""."" SUBMIT IN TRIPUCATE -'.'... ..."-" '- ( ( WPHILLIPS Alaska, Inc. Casing Detail 9 518" Surface Casinq Well: Date: CD2- 24 6/3/01 A Subsidiary of PHilLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.95 FMC Gen V Hanger 2.40 36.95 Jts 3 to 67 65 Jts 9-5/8" 40# L-80 BTC Csg 2668.49 39.35 Davis Lynch Float Collar 1.50 2707.84 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 81.29 2709.34 Davis Lynch Float Shoe 1.79 2790.63 2792.42 TD 121/4" Surface Hole 2802.00 Run 1 bow spring centralizer on first 12 its. then one on jt # 14,16,18,20,22,24,26,28,30,32,34,36,38,40.42,44 46,48,50,52,54,56,58,60,62, & 64 38 total Last 8 jts. out # 68 to # 75 Use Best-o-Life 2000 pipe dope Remarks: Up Wt -180 k Dn Wt -140 k Block Wt - 70 Supervisor: Mickey/Dale t ( Phillips Alaska Drilling Well Name: CD2-24 Rig Name: Doyon 19 Report Date: 0610412001 AFC No.: 998D05 Cementing Details Report Number: 4 Field: Alpine Casing Size Hole Diameter: Angle lhru KRU: Shoe Depth: LC Depth: % washout: 95/8" 12114" 2792' 2708' Centralizers State type used, intervals covered and spacing Comments: Bow Spring centralizers - one each on first 12jts. then one on every other jt to 120' - total 38 Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.7 32 16 53 16 Gels before: Gels after: Total Volume Circulated: 42,74,92 9,18,26 Wash 0 Type: Volume: Weight: Comments: Water 40 bbls 8.3 ppg Vlscoslfled wI nut plug Spacer 0 Type: Volume: Weight: Comments: ARCO B45 50 bbls 10.5 ppg Lead Cement 0 Type: Mix wlr temp: No. of Sacks: Weight: Yield: Comments: A5111 70 379 10.7 ppg 4.44 Additives: 30 % D053, .70% D046, 1.5%D079, 1.5%5001, 50%D124, 9% DO44(BWOW) Tall Cement 0 Type: Mix wtr lemp: No. of Sacks: Weight: Yield: Comments: G 70 235 15.8 ppg 1.15 Additives: .2% D046, .3% D065, .8%5001, .36%D167 Displacement 0 Rate(before tall at shoe): Rate(tall around shoe): Str. WI. Up: Comments: 6.5 blm 6.5blm 180 Reciprocation length: Reciprocation speed: Str. WI. Down: 12' 140 Theoretical Displacement: Actual Displacement: Str. WI. in mud: 205.3 205.3 Calculated top of cement: CP: Bumped plug: Floats held: Suñace Date:614/01 Yes Yes Tlme:04:48 hrs ~emarks:Full clrc through out job. 100 bbls cmt retunrs to suñace Cement Company: Dowell Rig Contractor: DOYON TApproved By: I Don Mickev / John Dale ( (' Phillips Alaska Drilling Daily Drilling Report AFC No. Date RptNo Rig Accept - hrs Days Since AccepUEst: 3 / 3.5 Rig Relase - hrs: 998D05 06/04/2001 4 06/0212001 12:01 :00 AM Well: CD2-24 Depth (MDfTVD) 280212378 Prey Depth MD: 2802 Progress: 0 Contractor: DOYON Daily Cost $ 88685 Cum Cost $ 820264 Est Cost To Date S 850000 Rig Name: Doyon 19 Last Csg: 9 5/8" @ 2792' Next Csg: 7" @ 10,510' Shoe Test: )peration At 0600: Suñace check AutoTrak tools Jpcoming Operations: RIH wlAutoTrak . Test Csg . Peñorm LOT - Drill 8 1/2" hole MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL SPUD 2802 N TST 06/04/2001 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6ppg VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 55sQc N SPACE PVNP SOWT TYPE TYPE TYPE FUEL & WATER 13/14 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 1140 7/16126 API WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER 934 8.4 06/04/2001 USED - BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 90 mll30 mln INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 7% CD2.42 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 33 212bbl III / / CD2-24 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 3 22.5 1121 I - - 4 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 220' 8 5.51611 - - 1050 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 33.00 4.6% III Water Base Muds 1000 PIT VOL GPM2 JETS JETS Fresh Water PHILLIPS 2 280 III IIIII IIIII 100 PERSONNEL Diesel 45 DAILY MUD SPS 1 BIT COST BIT COST Other CONTRACTOR 27 $17396 III 600 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $40109 III III III 1745 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 MI III III III 4182 PERSONNEL TOTAL 47 BHADESCRIPTION . DRILLPIPE DATA BHA NO 00 ID .. . WEIGHT .... GRADE CONNECTION CLASS 2 LENGTH BHA LENGTH 5 4.281 19.5 G105 4.1/2" I.F. DATE LAST INSPECTED: HOURS ON JARS: TIME I END.... HOURS OPSCODE HOLE SECT IPHASEOPS I OPERATIONS FROM 0000 - 0000 12:00 AM 03:00 AM 3.00 CIRC SURF Making Hole Clrc and condition for cmtjob 03:00 AM 05:00 AM 2.00 CMT _CSG SURF Making Hole PJSM - cement 9 5/8" csg - Pumped 40 bbls vlscoslfled water wlnut plug marker - 5 bbls water - test lines to 2500 psi. drop btm plug. pumped 50 bbls 10.5 ppg Arco Spacer. Mixed & pumped 300 bbls 10.7 ppg lead slurry. observerd nut plug mark @ shakers - switch over to tall slurry. Mixed & pumped 48 bbls 15.8 ppg tall slurry. drop top plug wi 20 bbls water fl Dowell. switched over to rig pumps & displaced wi 185 bbls 9.6 ppg mud - bumped plug - floats held - CIP @ 04:48 hrs. 05:00 AM 06:00 AM 1.00 CASG SURF Making Hole UD cmt head - landing jt . elevators & long balls 06:00 AM 07:00 AM 1.00 OTHER P1 Making Hole Flush flow line & dlverter 07:00 AM 11:00AM 4.00 NU_ND P1 Making Hole N/D dlverter system. Install & test wellhead to 1000 psi- N/U BOP 11:00AM 12:00 PM 1.00 BOPE P1 Making Hole Install test equipment. held PJSM on testing BOPE 12:00 PM 05:00 PM 5.00 BOPE P1 Making Hole Test BOPE . Pipe rams, blind rams, choke manifold valves, kill and choke line valves, floor valves kelly valves on top drive to 250 psi low & 5000 psi high - Hydrll to 250 psi low - 3500 psi high. accumulator closure test - test gas detectors . wlttnesslng of test waived by Chuck Scheve AOGCC 05:00 PM 05:30 PM 0.50 BOPE P1 Making Hole Pull Test plug & run wear bushing 05:30 PM 06:00 PM 0.50 OTHER P1 Other Pick up elevator balls and 5" dp elevators 06:00 PM 12:00 AM 6.00 OTHER P1 Other Pick up 5" drill pipe & rack In derrlck162 jts picked up27 stds racked27 stds In hole48 jts more to pick up. 24.00 Daily Drilling Report: CD2-24 06/04/2001 Page 1 Supervisor: DON MICKEY / JOHN DALE Well Name: CASING TEST and FORMATION INTEGRITY TEST CD2-24 Date: 6/5/01 Supervisor: D. Mickey Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8",40#, L-80, BTC CSG Casing Setting Depth: 2,792' TMD 2,378' TVD Hole Depth: 2,822' TMD 2,397' TVD Mud Weight: 9.6 ppg 30' Length of Open Hole Section: EMW= Leak-off Press. + Mud Weight 0.052 x TVD 800 psi 0.052 x 2,378' + 9.6 ppg = EMW for open hole section = 16.1 ppg Used cement unit RiCl pump used NO #2 Pump output = 0.0997 bps Fluid Pumped = 1.1 bbls Fluid Bled Back = 1.0 bbls 2,800 psi 2,700 psi 2,600 psi 2,500 pSI 2,400 psi 2,300 pSI 2,200 psi 2,100 pSI 2,000 psi 1,900 psi 1,800 psi 1,700 pSI ~ 1,600 psi :;) 1,500 pSI rn 1400 PSI rn ' w 1,300 ps 0:: 1,200 ps' a. 1,100ps 1,000 ps 900 pSI 800 psi 700 pSI 600 ps' 500 ps' 400 ps 300 ps 200 ps 100 pSI 0 pSI 0 , " ., ¡", I I' , I I I I I 1 I I , \ . - , . I I " I I I . 1 . " 1 I I' I' ' I I I " L I "-!- I 1 I I I I I I I I I T ~~~,' ~ :-4-~'¡~ i I I i I ì I ì I I, ,I i r ITIME LINE > i I j,....,.... . .¡..." IT"" i r ¡. I i I, I ..- - -1 i ~ I - LEAK-OFF TES-r- i - i .I ...... CASING TEST - ¡ .I' - 4 I m,mm..m.. LOT SHUT IN TIME - i i "1 -,!~ CASING TEST SHUT IN TIME - i , I - i 4' I -+-TIME LINE - , I i ~ ~ I I IJ ""':"::""""" I cr ,; '"" {; {,If:', ,':,:,:, I II I í'" I .11' I '111 I ..JL.tIII I ,~ I i 10 20 30 STROKES 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA 60 MINUTES FOR LOT STROKES PRESSURE ,,-------------'--------------"I-----------~-----' I : 0 I 0 pSI: L._------------~--------------""-- ------ -------- A ! ! 1.0 ! 30 psi ! I--------------.-------------------------------f ! ! 2.0 ! 40 psi ! ...-- ------------~--------------- .,..---- ------------, : : 3.0 I 70 psi : ---------------i------------------- ---------;---f : I 4.0 I 110 pSI I L.--------------~-------------....---------______A ! ! 5.0 ! 180 psi! I--------------.-----------------------------f ! ! 6.0 ! 300 psi! ...-------------~--------------.,..--------------, : I 7.0 I 430 psi I --------------i----- ------------ ------ -----:---f : I 8.0 I 540 pSI: L._-----------~-----------___""__n_--_______-A ! ! 9.0 ! 650 psi! 1--------------.-------------------------------. ! ! 10.0 ! 740 psi i ...-------------~ --------------.,..-- - ___n__---- -, I I 11.0 I 800 psi I - - - - ------ - --- i -- --- -- - -- --- - --- - -- - - - - -------- - f I I , , I I , I L. -- - ------- --- ~ -- ---- -- ---- --.... -- - - - - - - - ___n- - A I I I I I I I I I I I I 1--------------.----- -------- ---- ---- -- --------- f I I I I I I I I I I I I ...-------------~-------------.,..----------------, I I I , I I I I -------------i------------ ----- ----- ---------- f I I I I I I I I L. -------------- ~-------------_....------- --___----A I I I I I I I I I I I I 1------------. -------------- -------- ------- - f I I I I I I I I I I I I ...-----------~-------------- .,..--- --- ---------, I I I I I I I I ---------------i-----------------------------f I I I I I I I I L.--------------~----- --- -----....----- ---- -______A I I I I I I I I I I I I 1---------------.-- --------- ---------- ---------f I I , I I I I I I I I I :-------------1 ; ; I I I I I ! ' . : SHUT IN TIME I SHUT IN PRESSURE L.---- ------- --~--- --------------- --------------- ! 0.0 min ! ! 800 psi! 1--------------. --------------- --_u_-----------f ! 1.0 min ! ! 780 psi! ...----------- --~---------------.,..---- ----- -------, I 2.0 min I I 700 psi I ----------;----i-------------+- ------- ----;---f I 3.0 mln I I 680 pSI: L... - ------ - - - ~ - - - -- - - - ------....- - - -- - -- ------ - A I 4 0 . I , 660 . I I . mln ; : pSI; 1-- ---- ------ - -. --- - - - -- ------- -- - -- - - -- ---- --- -. ! 5.0 min i ! 650 psi! ...------------~---------------.,..------ ____n__--, I 6.0 min I : 650 psi I -----------,;,----i------ - ----------------- ------;---f : 7.0 mln I : 640 pSI: L.-----------~ -------------....--------- -______A ! 8.0 min ! ! 630 psi! 1--------------.-------- ---------- -- ----- -------f ! 9.0 min ! ! 620 psi! ...-------------~---------------.,..----------------, I 10.0 min : : 620 psi I !------------ ---~--____n____- --~- - --- - ---- -------¡ ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ---- --------- ---,---- ---- - ------,----- - ------ ----, ! ; 0 stks: 0 psi I L. ---- --____----A____----------.&------ --- - -------' ! ! 2 stks ! 100 psi! I----------------f- - ---- - -------- f---- --- ----------t ! ! 4 stks ! 230 psi i ...----- ------- --,- ----- --- ------ ,--- - --- --------. I I 6 stks I 420 psi I '-------------- - -t- -------------- t---- ------------1 ! I 8 stks ; 650 psi: L.------------- _-A--------______A___- --- --------.... ! ! 10 stks ! 840 psi! 1-------------- --f--------- ------ f---- --- ----------t ! ! 12 stks ! 990 psi! ...---------------,-------- ------ ,---- ------- -----.. ~-- ------------- ¡--_!~-~~..k.~--¡--~-'_!~~_P.-~~--I : I 16 stks : 1,300 pSI I L.------ ____--A ---------______A____- ------------' L-------------- L-!~- ~-t-~~--L -~-'-~ !.~_P._~!-J ! ! 20 stks ! 1,650 psi! ...------- --------,- ------ ------- ,---------------. ; I 22 stks : 1,840 psi I :-------------- --t-- ------------- f---- ------ -----;--1 I I 24 stks : 2,050 pSI I 1-- ---------- --- r2 S-s"fks-¡--2,27Õ- psi! 1---------------- f---- ----------T- ----- ----------t ¡ ! 28 stks I 2,530 psi! ...-------------- ,------- --------,- - --- ------- ----.. I I I I I I I I :- ------- ------- -f --------------t-- --- - ---- ------1 I I I I I I I I '-- ------ ----- _--A_____- - -_____--A- ----- ----------' I I I I I I I I I I I I 1-- ------------ - -f------ --------- .--- -- ---- - ------.. I I I I I I I I ;.-------------- -1-- ------------- 1- ----- -----------1 I I I I I I I I I . , : SHUT IN TIME: SHUT IN PRESSURE 1-- õ~õ-ñiiñ---r-- ----------- r-2~53Õ- psi! 1-------- -------- f ----- -- -------.- - --------- -----.. ¡ 1.0min! !2,510psi! ...------- --~--- -, ------ - --------,- - --- - --------,,-.. I 2.0 mm : I 2,510 pSI I :-----------,;,----t------- --------t-- --- - ---------;--1 ; 3.0 mm : : 2,500 pSI: '-. ------------- _A_- ----- -------- A--- - ------------""' ! 4.0 min ! ! 2,500 psi! 1---------------- f---- -- -- ------- f--- - ---- ---------t ! 5.0 min ! ! 2,500 psi ¡ ...------ ------ ---, ---- ---- - ------ ,---- ---- --------.. I 6.0 min I I 2,500 psi: 1------- ----7- --- f ---- ----- ------t--- - --- --------;--1 I 7.0 mm I I 2,500 pSI: L. ---------______A---- ----______A______------ -----' ! 8.0 min ! ! 2,500 psi! 1-------- --------. -- - --- - --------.-- --- _n_--____-" ! 9.0 mín ! ! 2,500 psi! ... - ------------ --,--- --- - --------,----- - ------ ----.. ; 10.0 min : I 2,500 psi I 1------------:-- - -t------ - ____n_- f--- -- ---- - ----:--1 : 15.0 mm I I 2,490 pSI I ,----------___--_A__- --- - - ------ A--- -- ---- - ------""' ! 20.0 min ! ! 2,490 psi ¡ 1----- --- ----- ---. ---- ---- - ------. --- - ------------.. ! 25.0 min ! ! 2,480 psi ¡ ...---- --- -------,-- - -- -- -- ------, ------- --------.. I 30.0 min I : 2,480 psi: !---- - -----------¡ ---- - --- - ------¡ --- - --- - ---------1 ~ .'-"""'-. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY f ( Casing Detail 7" Intermediate Casing Well: Date: CD2-24 6/19101 ARca Alaska, Inc. Subsidiary of Atlar Subsidiary of Atlantic Richfield Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 35.20 FMC 11" X 7" Hanger 2.24 35.20 Jts 3 to 263 261 Jts 7" 26# L-80 BTCM Csg 10686.95 37.44 7" Davis Lynch Float Collar 1.38 10724.39 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 83.90 10725.77 7" Davis Lynch Float Shoe 1.73 10809.67 1 0811 .40 8-1/2" OPEN HOLE 10822.00 1 straight blade centralizer per jt #1-#18 1 spiral blade centralizer every other jt. #195-#261 Total 52 positive centralizers Use Best-a-Life 2000 pipe dope Remarks: Up Wi = 400k On Wt = 110k Block wt= 75k Supervisor: David Burley { Phillips Alaska Drilling Well Name: CD2-24 Rig Name: Doyon 19 Hole Diameter: 8-1/2" Angle thru KRU: Report Date: 06120/2001 AFC No.: 998D05 Shoe Depth: 10811' (' Cementing Details Report Number: 20 Field: Alpine Casing Size 7" % washout: Centralizers Comments: 52 Total Mud Comments: Wash 0 Comments: Spacer 0 Comments: Lead Cement 0 Comments: Tall Cement Comments: 0 Displacement 0 Comments: Calculated top of cement: 10080' with 60%excess LC Depth: 10724 State type used, intervals covered and spacing 188-3/8" straight blade Rotco centralizers 1 per joint #1-18.1 spiral blade Centralizer every other joint #195-261. Weight: 10.1 PV(prior cond): 10 PV(after cond): 9 Total Volume Circulated: 1280 bbls Volume: 20 bbls Volume: 50 No. of Sacks: No. of Sacks: 160 Rate(tail around shoe): 8bpm Reciprocation speed: 0 Actual Displacement: 410.8 YP(prior cond): 16 YP(after cond): 15 Gels before: 5/7/9 Gels after: 5/7/9 Weight: 8.5 Weight: 12.5 Weight: Yield: Type: ARCO Wash Type: ARCO 845 Type: Mix wtr temp: Weight: 15.8 Yield: 1.16 Additives: Type: G Mix wtr temp: 70 Str. WI. Up: Str. WI. Down: 110 Str. WI. in mud: CP: Date:6/20/01 Time:0600 ~emarks:Staged pumps up to 6 bpm and conditioned mud with 95% returns for first 600 bbls. Incresed rate to 7.5 bpm last 680 bbls pumped with 90% returns. þlsplaced cement at 6 bpm for first 327 bbls with full returns, Increased rate to 8 bpm for last 83 bbls with 90 % returns. Cement Company: Dowell Additives: 0.2% D046, 0.25% D065, 0.25%D800, 0.18%D167 Rate(before tall at shoe): 6bpm Reciprocation length: 0 Theoretical Displacement: 410.8 Rig Contractor: DOYON Bumped plug: yes Floats held: yes Approved By: DAVID P. BURLEY ( ( Phillips Alaska Drilling Daily. Drilling Report AFC No. Date RptNo Rig Accept - hrs Days Since AccepUEst: 19/19 Rig Relase - hrs: 998D05 0612012001 20 0610212001 12:01 :00 AM Well: CD2-24 Depth (MDfTVD) 1082217232 Prev Depth MD: 10822 Progress: 0 Contractor: DOYON Daily Cost S 164675 Cum Cost S 3685549 Est Cost To Date S 3800000 Rig Name: Doyon 19 last Csg: 7" @ 10811' Next Csg: Shoe Test: )peration At 0600: RIH with 6-1/8" BHA. Jpcoming Operations: RIH; Circ; Test Csg; Drill Out Shoe Track & 10 ft; Clrc; Perform FIT; Displace to Flo-pro; Drill Ahead. MUD DATA DRILLING DATA BIT DATA EH&S DRILLSIBOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRill lSND 10822 7 N TST 06/13/2001 06120/2001 WEIGHT ROT WT SIZE SIZE EMPLOYER lAST H2S DRill lAST FIRE DRILL 10.1ppg 6.125 05/01/2001 0611512001 VISCOSITY PUWT MAKE MAKE SPill lAST CONFINED lAST SPILL DRilL 41sQc HTC N SPACE 0611012001 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 8/12 STR386 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 698 4/5/6 1904978 APIWl MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRill WATER 0 4.8 06120/2001 USED. BBlS HTHP Wl TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 0 10.0m1/30 min 10822 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 9.0% 0 CD2-42 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 33.1 677bbl III / / CD2-24 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 9 13.8 1121 I - - 4.0 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 50' 9.0 5.51611 . - 1250 lGS SPM 1 TFA TFA INJECTION FLUIDS CHill FACTOR of 21.43 5.1% III 0.69 Water Base Muds 600 PIT VOL GPM2 JETS JETS Diesel PHilLIPS 2 124 III 1511511511511 11111 5 PERSONNEL Other 252 DAilY MUD SPS 1 BIT COST BIT COST CONTRACTOR 25 30140130140 10000 0 PERSONNEL $1943 0 TOTAL MUD SPP 1 DUll DUll TOTAL VOL (bbl) MISC PERSONNEL 5 $278602 III III III 857 COMPANY MUD WT GRADE GRADE TOT FOR WEll (bbl) SERVICE 18 MI 10.1 III III III 11069 PERSONNEL TOTAL 50 BHADESCRIPTION ~It; TB Stab; 1.2 deg AKO PDM; Stab; 10' NM CSDP; MWD/APSILWD; 2 x NM CSDP; XlO; 3 x HWDP; Jars; 2 x HWDP .. ÐRILLPIPEDATA BHA NO 8 00 10 WEIGHT . ..GRADE CONNECTION CLASS 2 lENGTH BHA LENGTH 360.50 4 3.234 15.7 S135 DATE LAST INSPECTED: HOURS ON JARS: 0 W:<=. I F.\r. I H:>LRS GI'S ':ODE HCI. E .5F.CT I PI-."":;::: erg I C¡::>::J~,\ -IC\S :=¡;.C': ~.~:':: - ::. ::~:~i 12:00 AM 01:00 AM 1.00 CASG S1P1 C.l!\lng anrt Continue washing & working 7", 2Gppf, l.80 BTC-mod CS!) Cementing to bttm. Land csg at 10811'. Top FC at 10724'. 01:00 AM 04:00 AM 3.00 CIRC S1P1 Casing and Clrc & cond mud/ hole for cmtg. (Stage up from 180 gpm to Cementing 285 gpm & start losing 40 to 50 bph. Slow to 250 gpm & stili losing mud, but less.) 04:00 AM 06:00 AM 2.00 CEMENT S1P1 Casing and RIU to cmt. Cement 7" csg with 160 sx (33 bbls), 15,8ppg, Cementing CL "G" cmt with nearly full returns at 6 to 8 bpm. (Lost 8 bbls during cmt job.) Bumped plug. Floats held. Est TOC = 10080' 06:00 AM 09:00 AM 3.00 CASG S1P1 Casing and UO cmtg tools & 7" csg tools. Pull 7" wear ring. Run 7" Cementing hanger packoff & test to 5000 psi - ok. 09:00 AM 10:00 AM 1.00 BOPE S1P1 Casing and Change BOP pipe rams to 4.5" x 7" and 3.5" x 6", Cementing 10:00 AM 02:30 PM 4.50 BOPE S1P1 Casing and Run test plug & test BOPE to PAl specs. (Test rams, BOP Cementing valves, floor vlaves, and TD IBOP to 2501 5000 psi & annular to 2501 3500 psi.) 02:30 PM 03:00 PM 0.50 CASG S1P1 Casing and Pull test plug & run wearbushing. CemenUng 03:00 PM 10:00 PM 7.00 TRIP_OUT S1P1 Trip Out RIU handling tools & UD excess 5" DP from derrick. 10:00 PM 12:00 AM 2.00 BHA S1P1 Trip In M/U 6.1/8" Horizontal drlg BHA & RIH. 24.00 Supervisor: SCOTT REYNOLDS/ ALAN E. WITTRY Daily Drilling Report: CD2-24 06/20/2001 Page 1 Well Name: CASING TEST and FORMATION INTEGRITY TEST Date: 6/20/01 CD2-24 Supervisor: ReynoldslWittry Reason(s) for test: D Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80 BTC CSG X 7" 26# L-80 BTC-MOD eSG Casing Setting Depth: Mud Weight: 2,792' TMD 2,378' TVD 9.6 ppg Hole Depth: Length of Open Hole Section: = 525 psi 0.052 x 2,378' 10,080' TMD 7,068' TVD 7,288' EMW= Leak-off Press. 0.052 x TVD + Mud Weight EMW for open hole section = 13.8 ppg + 9.6 ppg Used cement unit Riq pump used w . e:::: 400 pSI => en en w e:::: 300 psi Q. yes #2 700 psi 600 psi 500 psi 200 psi 100 psi 0 psi: 0 Modified by Scott Reynolds Pump output = bbls pumped LEAK-OFF TEST """"CASING TEST LOT SHUT IN TIME ....,-Á- CASING TEST SHUT IN TIME -+-TIME LINE 10 Barrels Fluid Pumped = 10.0 bbls Fluid Bled Back = 20 LEAK-OFF DATA 30 MINUTES FOR LOT BBLS PRESSURE ,----------------,-------------"\------------.-----T I 1 0 : 0 pSI 1 ¡------------r----r:Š----r ---12ff p-šr--¡ ...-------------~---------------+----------------. i ! 2.0 ! 175 psi! ,..---------------,--------------.,..----------------, : : 2.5 1 212 psi: -------------~-------------+------------';---~ 1 : 3.0 : 253 pSI I ..-------------. ---------------'---------- -------. ! ¡ 3.5 ! 298 psi! ...--------------~--------------+----------------. ! ! 4.0 ! 343 psi! ,.. -- - ------ - - - -,-- -- -- -- - --- - -.,..-- - - - - - - --------, : 1 4.5 : 380 psi: ----------------~ ------ -------- -+------------,;---f : : 5.0 I 429 pSI: ..-- - - - ---- - -- _.&- - ------ ---- - - -'- - - -- - - - - - ------. ! ! 5.5 I 464 psi! r- - - - ---- - - --r - ----6-.0-- - - - r - -š 1" ëfp--š¡- -: I I I I ,..-------------,---------------.,..- ------ ---------, : : 6.5 1 525 psi 1 --------------~------------ --+- - ----------,;--f : : 7.0 1 520 pSI 1 ..-------------.----------------'-----------------' ! ! 7.5 i 510 psi I ...-------------~---------------+----------------. ! ! 8.0 ! 485 psi ¡ ,..---------------,---------------.,..---- ----- -------, ; : 8.5 : 485 psi 1 ---------------i--------------+ ---- --------,;---f I : 9.0 : 485 pSI: ..-------------.----------------'----------------' ! ! 9.5 ¡ 485 psi ¡ ...--------------~---------------+-------- - -------. ¡ i 10.0 ! 485 psi I ,..--------------,-------------.,..----------------, I I I I I I I I -------------i--------------+ ---- ----------f I I I I I I I I ..------------.-------------- --'----- - ----------, I I I I I I , , I I I I ...--------------~-------------- +----- -----------. I I I I I I I I I I I , ,..-------------,---------------, , I I I I I I I I I I . . : SHUT IN TIME: SHUT IN PRESSURE ..--------------.--------------------------------- ! 0.0 min ! I 485 psi I ...---------------~--- -----------+-- --------------. ! 1.0 min ! I 350 psi I ,..---------------,---------------.,..---------------, : 2.0 min : : 328 psi 1 ---------7----~--------------+ -------- - ---,;---f : 3.0 mm : : 328 pSI I ..-------------.----------------'- ---- - --- - -------, I 4 0 . I I 318 . I : . mm : ; pSI I ...-------------~--------------+----------------. ¡ 5.0 min ! ! 313 psi! ,..---------------,-------------- -.,.. ---- - -----------, 1 6.0 min : I 308 psi: ----- -----;----- ~------ -------- -+------ - -----,;---f : 7.0 mm I I 303 PSI; ..--------------.------- ------- --'--- ---- - ---------, i 8.0 min ! I 298 psi i ...------------~ ------- ----- --+-- ---- --- ------. i 9.0 min I I 298 psi I ,..------------,------- ------.,..----------------, : 10.0 min : : 298 psi 1 !----------------~ ------- -------- -'--- ---- ---------, ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ------------- ---T-------- -------T-- -- -------------, ! I 0 stks: 0 psi I ..------------ ---,------ ---------, ---- -----------"'" I I I I I I I I I I I I t---- --- ---------. ---------------. - --- ----- --------t I I I I I I I I I I I I ,..-- - ---------- --,- - -- -----------, --------- --------, I I . I I I I I --- --------- --I ---- ---- ------f -- ----- -- - -------1 1 I : I ..--- --- ---------,--- --- ---------, - --- ----- -------"'" I I I I I I I I I I I I t---- --- ---------. ------ ---------.----- ------------t I I I I I I I I I I I I ,..--------------,----- - ---------,- --- - ----- -------, I I I I I I I I -------- --------f ---- -----------f - --- ----- -------1 I I I I I I I I ..------ ------- --, ---------------, -- - -------------"'" I I I I I I I I I I I I t--------------- -.- --- -----------. --- ------- -------t I I I I I I I I I I , I ,..--- ----------- -,-------- -------,-- - ---- - --- - ___°' I I I I 1------ -------- --f- - ------ ------- f-- ----- ----------1 I I I I I I I I .. ------------ --- ,----- - ---------, - ---- --- ---------' I I I I I I I I I I I I t- - ---- ------- ---. ----- - ---------.----- -----------t : I 1 I I I I I ,..- ---- ----------, ----- ----------, ----- --- - --- -----, I I I I I I I , :- ---------------f --- - ----------f - ---- ---- --------1 I I I I I I I I ..----- ----------, ----- ----------, ----------------"'" I I I I I I I I I I I , t-- --------------. ----- - ---------. - ---- --- -o------t I I I 1 I I I I I I I I ...----- ------- --- ,------ ---------,----------- ------, I I I 1 I I I I I I . . : SHUT IN TIME I SHUT IN PRESSURE ..------ --------, --------------- -----------------. I 0 0 . I I 0 . I : . mm I : pSI: t------- - ------.--- - ---- -------.-- - -- ------------t ! 1.0 min ! ! ! ,..----------.,.-- - -,- - ------- ------,-- - ---- ---- ------, ~--~:~--~~~---t- ------- -------t -----------------1 : 3.0 mm 1 I I ..-- ---------- ---,- - ------- ------,-- ----- - --- __n_-' ! 4.0 mín I ¡ ! t----- ---------- .-- ------ - ------.------- ---------t ! 5.0 min I ! ! ,..--------------- ,------ - -- -----,-------- ---- -----, : 6.0 min ; 1 I 1----- - -----;-----t ------ ---------f - ---- -- ---- - -----1 1 7.0 mm I 1 : ..- --- - ------- ---, ---------------, - ------- - --------' ! 8.0 min ! I ! t--- ---- -------- -. --- ------------. ------ ---- -------t ! 9.0 mín ! I ! ,..------ - --------, --- - ----------, ----- - --- - -------, ; 10.0 min I : : :--- - --- - ----:-- --f- --- ---- - ------f--- --------------1 : 15.0 mm I : : ..-- - ---------- - -,-------- ------- ¿_-- -- ---- ----___1 ! 20.0 min ! i ! t--- ----- ------ --.- --- ---- - ------.- -- ---- - ---- -----I i 25.0 min ! I ! ,..--------------,- - ------ - ------, -- ----- ---- ------, 1 30.0 mín ; I : !--- ----------- - -¡- -- ----- - ------¡--- ---- -- -- -----1 --- --~ ~I (' ST ATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 12639' (planned) feet 7134' (planned) feet 12639' (planned) feet 7134' (planned) feet 1. Type of request Abandon - Suspend - Alter casing - Repair well- Change approved prQ9ram - 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1984' FNL, 1513' FEL, Sec. 2 TUN, R4E, UM At top of productive interval 106' FNL, 359' FEL, Sec. 10, T11 N, R4E, UM At effective depth At total depth 2530' FSL, 1054' FWL, Sec. 11 T11 N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 114' 2544' Size 16" 9-5/8" Production 9596' 7" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Operational shutdown - Plugging - Pull tubing 5. Type of Well: Development _X Exploratory - Stratigraphic - Service Plugs (measured) Junk (measured) Cemented 10 yds portland 3 ready mix emt 380 Sx AS III L & 230 Sx 16.8 class G 117'Sx 15.8classG Packers & SSSV (type & measured depth) 4.6" 12.6#, L-80 @ 9292' MD (PLANNED) Re-enter suspended well - TIme extel1Sion - Stimulate - Variance Perforate 6. Datum elevation (OF or KB feet) RKB 52 feet 7. Unit or Property name Other _X Annular Disposal Collevile River Unit 8. Well number CD2-42 9. Permit number I approval number 201-067 10. API number 50-103-20374 11. Field / Pool Coleville River Field / Alpine ÖiI Pool Measured Depth 108' 2581' True vertical Depth 108' 2377' 9633' 7273' RECEIVED MAY 2 5 2001 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments 7" Baker S-3 Permanent Packer, 9224' MD (PLANNED) Description summary of proposal- Detailed operations program - BOP sketch - Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets. schematic _X 14. Estimated date for commencing operation « 15. Status of weil classification as: . ' May ~Ø2001 16. If proposal was verbally approved Oil_X Name of approver Date approved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . /1 I e.. ~ ChiD Alvord .~ Title: Alpine Drilling Team Leader Gas- Suspended - Questions? Call Vem Johnson 265-6081 Date £ {¿'5( 0 ( Prt!lf)lM'(d by V.,." Johnson FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may ",!itness .. I Approval no. Plug integrity - BOP Test - Location clearance -. ...... '2..CJ \ - l L{ 0 Mecbanlcallnteg'iWTos'- . Subsequnn' form required 10-~ O~ ~""-.) \....~ ,~ M.. \~ "::.~~ , . b/ I /l51 d' Commissioner Date Approved bv order of the Commission Form 10-403 Rev 06115188 . DUPLICATE SUBMIT IN TRIPLICATE (' i { IjPHILLlPS Alaska, Inc. Casing Detail 9 518" Surface Casing Well: Date: CD2-42 2/15/01 A Subsidiary of PHilLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.80 FMC Gen V Hanger 2.19 36.80 Jts 3 to 62 60 Jts 9-5/8" 40# L-80 BTC Csg 2453.48 38.99 Davis Lynch Float Collar 1.52 2492.47 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 85.70 2493.99 Davis Lynch Float Shoe 1.75 2579.69 2581 .44 TD 12 1/4" Surface Hole 2590.00 RUN TOTAL 36 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #3) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40, 42, 44, 46, 48, 50, 52,54,56,58,60. Last 11 jts, stay out # 63 to # 73 Use Best-a-Life 2000 pipe dope Remarks: Up Wt -155 k Dn Wt -148 k Block Wt - 70 Supervisor: DA VID BURLEY (' ( Phillips Alaska Drilling Well Name: CD2-42 Rig Name: Doyon 19 Report Date: 05/15/2001 AFC No.: 998D04 Cementing Details Report Number: 4 Field: Alpine Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 9.625 12.25 2581 2492 Centralizers State type used, intervals covered and spacing Comments: Ran 36 9.5/8" x 12-1/4" bow spring centralizers, 1 per joint on #'s 1-12 and every other joint #'s 14-60. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.7 15 16 27 18 Gels before: Gels after: Total Volume Circulated: 11/26/35 6/10/14 880 bbls Wash 0 Type: Volume: Weight: Comments: Water 40 8.4 Vlscoslfled & nutplug for marker Spacer 0 Type: Volume: Weight: Comments: ARCO 845 50 10.5 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS LIte 70 380 10.7 4.44 300 bbls Additives: 30% D053, 0.6% D046, 1.5% D079,1.5% 5001, 50% D124, 9% 8WOW DO44. Tall Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 70 230 15.8 1.17 48 bbls Additives: 0.2% D046, 0.3% D065, 1% 5001. Displacement 0 Rate(before tail at shoe): Rate{tail around shoe): Str. WI. Up: Comments: 8bpm 6bpm 155 Reciprocation length: Reciprocation speed: Str. WI. Down: 25' 20 fpm 148 Theoretical Displacement: Actual Displacement: Str. WI. in mud: 189.6 bbls 189.8 bbls Calculated top of cement: CP: Bumped plug: Floats held: Had 117 bbls of 10.7 ppg cement to surface. Date:5/15/01 YES YES Time:0655 hrs. ~emarks:Had full returns untllliast 22 bbls of displacement, conductor stood full after blugs bumped. - .. Cement Company: Rig Contractor: Approved By: Dowell DOYON David Burley { AFC No. 998D04 Phillips Alaska Drilling RptNo 4 Rig Accept - hrs Days Since AccepUEst: 3.1/3 05/121200110:00:00 PM Well: CD2-42 Date 05/15/2001 Depth (MDfTVD) 2590/2384 Prev Depth MD: 2590 Cum Cost $ 629155 Next Csg: 9-5/8" @ 2615' Contractor: DOVON Daily Cost $ 165732 Rig Name: Doyon 19 last Csg: 16" @ 114' )peration At 0600: Picking up 4" drill pipe. Jpcoming Operations: MU BHA #2, test casing, clean out cement, LOT, drill ahead. MUD DATA DRILLING DATA BIT DATA MUD TYPE DEPTH BIT NO. BIT NO. SPUD WEIGHT 9.7ppg VISCOSITY 58sqc PVIYP 16/18 GELS 6/10/14 API Wl 12 HTHP Wl mll30 min SOLIDS 7,5% HOLE VOLUME 179bbl MBT 22.5 ph 8.8 lGS 4.9% PIT VOL 404 DAll V MUD $6476 TOTAL MUD $20736 COMPANY MI ISH;, D:::SCRIPTIJ'\ ROT WT PUWT SOWT AVG DRAG MAX DRAG TRQ BTM TRQ OFF PUMP PRES III PUMP NO 1 121 I LINER SZ 5.51611 SPM 1 7417411 GPM2 572111 SPS 1 III SPP 1 III MUD WT III EH&S ACCIDENT (non-spill) V SIZE SIZE EMPLOYER Doyon SPill V l ( Daily Drilling Report Rig Relase - hrs: Progress: 0 Est Cost To Date S 652000 Shoe Test: DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRill TST 05/14/2001 05/13/2001 lAST H2S DRilL 05/01/2001 LAST CONFINED SPACE lAST FIRE DRilL 04/25/2001 lAST SPill DRill 05/03/2001 FUEL & WATER FUEL USED 1250 MAKE MAKE DRILL WATER USED - BBlS POTABLE WATER USED - BBlS 580 102 TYPE TYPE TYPE Mud VOLUME (gallons) 126 LAST SAFETY MTG 05/15/2001 WEATHER & PERSONNEL DATA TEMP OF 16 SERIAL NO SERIAL NO WIND SPEED 3 DEPTH OUT DEPTH OUT WIND DIRECTION 30° DEPTH IN DEPTH IN CHill FACTOR of 16.00 FOOT AGE INJECTION INJECTION WEll CD1.19 SOURCE WEll CD2.42 RATE (bpm) PHilLIPS PERSONNEL 1 FOOTAGE ADT/AST / WOB2 ADT/AST / WOB2 CONTRACTOR PERSONNEL 25 - - DUll III GRADE III DUll III GRADE III a TOTAL VOL (bbl) 0 TOT FOR WEll (bbl) SERVICE PERSONNEL RPM 1 PRESSURE (psi) Mise PERSONNEL 5 RPM 1 - - 13 TOT ~IT. M1C@1.4. XO. NMDC. NMSTAB, GRSUB, MWD. 2 Nr,mC. NMSTAB. NMDC. XO. 3 HWDP, JARS. 26 HWDP. TFA TFA INJECTION FLUIDS 44 DR llPI:::E C'; T/~. ßH'; \C 1 OD ID ':, EIGrlT GRADr.: Cü~.~,EC":"IO'" Cl/'S':; 2. -['.G-~' BHA lENGTH 1104.09 5 4.26 19.5 G105 4-1/2 IF Prem DATE lAST INSPECTED: HOURS ON JARS: 115.2 TIME I END I HOURS OPSeODE HOLE SECT IPHASEOPS J .. OPERATIONS FROM 0000 - 0000 12:00 AM 12:15 AM 0.25 CASG SURF Casing and Run casing to 1360', pushed last 40', displacement returns Cementing diminished. 12:15 AM 12:45 AM 0.50 CIRC SURF Casing and Staged pumps up to 7 bpm and clrc with full returns. Cementing 12:45 AM 03:00 AM 2.25 CASG SURF Casing and Run casing, MU LJ and land casing with shoe @ 2581', FC Cementing @ 2492'. LD Fill up tool and MU cement head. 03:00 AM 05:00 AM 2.00 CASG SURF Casing and Staged pumps up to 9 bpm, clrc and condition mud, PJSM Cementing with Dowell. 05:00 AM 07:00 AM 2.00 CASG SURF Casing and Pumped 40 bbls of vlscoslfled FW with nutplug marker, line Cementing up to cementers, test lines to 2600 psI. Pumped 50 bbls of 10.5 ppg spacer, 300 bbls of lead and 48 bbls of tall cement. Displaced with 20 bbls of FW and 169.8 bbls of mud @ 8 bpm. Bumped plugs to 1000 psi, floats held, CIP @ 0655 hrs. 07:00 AM 09:00 AM 2.00 CASG SURF Casing and RD cement head and flush conductor. lD LJ, MU wash tool Cementing and flush annular preventor, driller functioned dlvertor with out disabling knife valve resulting In 3 bbl spill on pad. 09:00 AM 09:30 AM 0.50 OTHER SURF Casing and Initiate spill response and establish containment. Cementing 09:30 AM 12:30 PM 3.00 CASG SURF Casing and ND Dlvertor system, Install Unlhead and test M/M seal to Cementing 1000 psi for 10 min. 12:30 PM 03:00 PM 2.50 NU_ND SURF Casing and NU BOPE. change drive sub on Top Drive to 4". Cementing 03:00 PM 08:30 PM 5.50 BOPE SURF Casing and Install test plug - test BOP's choke manifold and surface Cementing safety valves to 250/5000 psi. Annular Preventor 250/3500 psi. Install wear bushing Chuck Scheve (AOGCC) waived Daily Drilling Report: CD2-42 05/15/2001 witnessing tests. Page 1 a JETS 11111 JETS IIIII a 0 BIT COST BIT COST 0 08:30 PM 09:00 PM 10:30 PM 09:00 PM 10:30 PM 12:00 AM 0.50 1.50 1.50 24.00 (' OTHER SURF Casing and Cementing Other Other ( Install mousehole and second annulus gate valve on wellhead. Slip and cut drilling line. service Top Drive. PJSM. Grant-Prldeco Rep. spoke to crew on the new drill pipe Issues. Begin picking up drill pipe. RIGS OTHER SURF SURF Daily Drilling Report: CD2-42 05/15/2001 Supervisor: DAVID BURLEY Page 2 Well Name: CASING TEST and FORMATION INTEGRITY TEST Date: CD2-42 5116101 Supervisor: D. Burley Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8", 40#, L-80, BTC eSG Casing Setting Depth: 2,581' TMD Hole Depth: 2,610' TMD 2,376' TVD 2,399' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 29' EMW= Leak-off Press. + Mud Weight = 790 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,376' EMW for open hole section = 16.0 ppg Used cement unit RiCl pump used Pump output = 0.0997 bps ~ 1,600 psi ~ ~ 1,400 psi LU 0:: 1,200 psi Co NO #2 Fluid Pumped = 0.5 bbls Fluid Bled Back = 0.4 bbls 2,800 psi 2,400 psi 1 I , I ! ++++ 2,600 psi 2,200 psi 2,000 psi 1,800 psi !~I.EAK-OFF TEST i-:J- CASING TEST LOT SHUT IN TIME ..-.-_. CASING TEST SHUT IN TIME H ;-+-TIME LINE I- 1,000 psi I ! I T 1 T i i 800 psi 600 psi 400 psi I 200 psi ¡ I ill 25 STRðKES 35 50 55 0 psi 0 15 20 40 45 5 10 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r-------------r-------------r--------------- -'\ I I 0 ; 0 psi: }---------------+---------------~_u_---------.----i I I 1.0 I 200 pSI: L--------------...I--------- ---- -_L___- ----------.. ¡ ¡ 2.0 ¡ 390 psi ¡ 1-- - ----- ------ -+----------- --.. --- - -- ----- - - - - -.. ! ¡ 3.0 ¡ 540 psi ¡ r----------------r---------------r------------.-n,\ I : 4.0 I 670 pSI I }--------------+--------------~-------------.----i I : 5.0 I 790 pSI: L------------...I----------_----_L___------------" I I I 1 I I I 1 1 I I 1 1---------------+----------------"----------------" I I I I 1 I 1 1 ~-------------+--------------~---______n____~ I I I I I I I I }--------------+--------------~-----------------i I 1 I I I 1 I I L-------------...I--------------_L__-------- ---n" I I I I I I I I I 1 I I I---------____--+-n__-_---------.----______n--" I I I 1 I I I I I I I 1 r---------------r---------------r----------------'\ I I 1 1 1 I 1 1 }--------------+-------------~----------------i I I 1 1 1 1 1 I L-------- -------...I-------__----n-L--- ------------.. I 1 1 I I 1 1 1 I 1 1 1 I------_____n-+-_____------ ----._n_--------- --.. I I 1 , I I 1 1 ~-------------+--------------~----_--____nn~ I I I 1 I I I I }-------------+-------------~---------------i I I I 1 I I I 1 L-------------...I----_____-n----L----------------" I 1 1 1 1 I 1 1 1 I 1 I t----------- ----+----------------..----------- -----.. I 1 1 I I 1 1 I ~--------------+---------------~---------------~ I 1 1 1 I 1 I 1 }-------------- +-- ------------+----------- --- ---i I I I 1 I I I 1 L__-----------...I---------------_L_------------ --.. I I 1 1 I I I 1 I I 1 1 1-------------'" . , I I 1 1 1 I 1 1 1 . . . H H i SHUT IN TIME I SHUT IN PRESSURE }---------:- ---+---------------r------___n-:-n¡ I 0.0 mm : : 790 pSI: L----------___-...I-_n___-_------_L_--------------" ¡ 1.0 min ¡ ! 770 psi! 1-- ------- - - - - -+-- - ------- - -- - - -.- - -- - ------ - - - --.. ! 2.0 min i ! 760 psi! r---------------r------------ --r-- ---------- ----, : 3.0 min I I 760 psi: }---------:----+--------------~-------------.----i : 4.0 mm : : 750 pSI I L--------------...I---- --______n_- L----- -----------.. ! 5.0 min ! ! 750 psi! 1---------------+----------------.---------------" ¡ 6.0 min i ! 740 psi! r----------------r-------- ----- -r------------ ----, : 7.0 min : : 740 psi: }----------:----+-______n_--__~_------------.----i : 8.0 mm : : 740 pSI I L_--------------...I-----_-----_L----------------" ! 9.0 min ! ! 730 psi! [I[§ ~~ñJ ~ ~ r ~~~==~~ ~~ ~ ~ I~~ Ï~ ~~P. ~T ~ ] 60 ~PHILLIPS Alaska, Inc. ~ A Slbsidiary of PHilLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ,---------- -- ---'\----- - ---------'\-------- ---- - ---. : I 0 stks; 0 psi: ~--------- --- - --+ - --------___-+-n_- - --------- f ¡ : 2 stks : 340 psi: L--____-- --- - --...I- -- - --------___...I--_n- - ----____--1 ¡ ¡ 4 stks ! 590 psi ¡ "__n_______n__",,__----------__""___n- ---------. ! ! 6 stks ! 860 psi ¡ r-- ------------T-n------n--T---------------' : : 8 stks : 1,080 psi: }--- ------- - _n_+___- ------- ---+---- --- ----- -~--f : I 10 stks : 1,270 pSI: L-- ------- - ----""'----______n_-.L.-__- --- _____n_1 I ! 12 stks ! 1 ,460 psi ¡ .--- _--__n- - -------- --------- - ....----------------. ~--- --------- mL__1_~_~!~-~--L--!!~- ~.Q_p.~L! : : 16 stks : 1,870 psi I }----____--_n_- +-- ------------+------ --------. --f Lm___- -- --- L_1_~_~!~-~ __L~!~ -~.Q-p.~~ -.1 ! ! 20 stks ¡ 2,350 psi i r- - ------- - ----ï"iTšti< š--r -2 -, 531fp--šTl I 1 , 1 r- -- --__-_n_---T - -------------T----- -----------. I 1 1 I I I I I t--------- ------t-- - -----------t----- ----------- t 1 I 1 I L- -- ------- - ---- .....-- - _n__-_- - --...1------- ----______1 1 I 1 I I I 1 I 1 1 , I ..-- - ______n_- --- - --- - _____n_- ....--- - -------- ----. 1 1 I 1 I 1 I 1 I 1 I 1 r - - - ----- - - - - - - - T - - - - - ------ - - -T --- ---------- _n. I 1 I 1 I 1 I 1 }--------- ----- -+ ---- -------- - +------------- -_of I 1 1 I I 1 1 I L--n_____---- - -...1--- - _n___---__...I-___n- ____n_- __I I 1 1 1 1 1 1 1 I 1 1 1 ..----------- ----....----------- --....------ -------- --. 1 1 1 I 1 1 1 1 ,- , 1 . .-, I SHUT IN TIME: SHUT IN PRESSURE }--------- --:-- --+ --_u_------ - ¡-------------- -:--1 : 0.0 mm ; I 2,530 pSI: L--_____-- _n- - -.L.--- --______n_...I-- - ____n_---- --- I ¡ 1.0 mín ! ¡ 2,520 psi ¡ 1--------- ------....--- -----------....- ----- __n__-_--' : 2.0 min I : 2,520 Psi: 1 1 1 1 r----------- ---- T-- - -----------T- ------------ ---. : 3.0 min : : 2,520 psi: }-- - _n_----:----+ ---- - ------ --- +--- ---------- ~--f : 4.0 mm : : 2,510 pSI: L-- -------- ---- -.....- --- ------ ----.L.- --______n--__-I ! 5.0 min ! ! 2,510 psi! 1- - ----------- - -....- - -------- ----....- - ----------- ---. ~ --_?~Q-~J~--L-- m_---_m-L-~!~ ~ .Q-p.~} --1 I 7.0 min : : 2,500 psi: }-- - --------: - _n+-__- ______n__+ ---- --- ----- --. --f L- - ~~Q-~~~ __L______-- ---- L~!~_~.Q_P.~ ~-- i ¡ 9.0 min ! ! 2,500 psi! . -- ------- ___n__- -- _____n___""- --- ------- ----. I 10.0 min ! ! 2,490 psi! r- ----------- - -- T--- ------- --- --r---- --------- ---. I 15.0 mín : : 2,480 psi: }- ----------7---+--------------+-- ---- -------~- - f : 20.0 mln : : 2,470 pSI: r-- 2-5~ëfñi 1ñl----------- ---I -2~46-šï)šT 1 [~~Q~9.~ ~}~~r~~~~~~=~~~~~ r~~~~~~~p.~T] .-'" NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ( ~( <, ŒJPHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Casing Detail 7" Intermediate Casing Well: Date: CD2-42 5/24/01 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LOS 35.00 FMC 11" X 7" Hanger 2.27 35.00 Jts 3 to 235 233 Jts 7" 26# L-80 BTCM Csg 9512.13 37.27 7" Davis Lynch Float Collar 1.40 9549.40 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 80.95 9550.80 7" Davis Lynch Float Shoe 1.72 9631.75 9633.4 7 1 straight blade centralizer per jt #1 - #18 1 straight blade centralizer every other jt #172 - #232 Total - 49 centralizers ---.. Use Best-a-Life 2000 pipe dope Remarks: Up Wt - ???k On Wt - ???k ,., ", Supervisor:Don Mickey ( (' Phillips Alaska Drilling Well Name: CD2.42 Rig Name: Doyon 19 Report Date: 05/24/2001 AFC No,: 998D04 Cementing Details Report Number: 13 Field: Alpine Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 7" 81/2" 42 9633' 9549' 40 Centralizers State type used, intervals covered and spacing Comments: Slip on straight blade stand-ofts - 1 per jt on first 18jts. then every other jl fl # 172 to # 232 - 49 total Mud Weight: PV(prior cond): PV(after cond): YP(prior cend): YP(after cond): Comments: 9.9 10 9 22 17 Gels before: Gels after: Total Volume Circulated: 8/10112 7/8111 660 bbls Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 bbls 8.3 ppg Spacer 0 Type: Volume: Weight: Comments: ARCO 845 50 bbls 12.5 ppg Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 70 117 15.8 ppg 1.15 Additives: 0.2% DO-46 antlfoamer, 0.25% DO65 dispersant, 0.25% D800 retarder, .018% D167 fluid loss Tall Cement 0 Type: Mix wtr temp: No, of Sacks: Weight: Yield: Comments: Additives: Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6.5 b/m 5.5 b/m Reciprocation length: Reciprocation speed: Str. WI. Down: 6' 10'/mln Theoretical Displacement: Actual Displacement: Str. WI. In mud: 365.7 bbls 364.7 Calculated top of cement: CP: Bumped plug: Floats held: 8975' Date:5/25/01 Yes Yes Time:0345 hrs. ~emarks:Full returns during job. Unable to reciprocate pipe after 15 mlns. Into circulating up wt 350 K. dn wt 150 K Cement Company: Dowell I Rig Contractor: DOYON Approved By: Don Mickey I (" ( Phillips Alaska Drilling Daily Drilling Report AFC No. Date RptNo Rig Accept - hrs Days Since AccepUEst: 13.1/13.5 Rig Relase - hrs: 998D04 OS/25/2001 14 05/12/200110:00:00 PM Well: CD2-42 Depth (MD/1VD) 9644/7274 Prev Depth MD: 9644 Progress: 0 Contractor: DOYON Daily Cost $ 157301 Cum Cost $ 2284087 Est Cost To Date S 2250000 Rig Name: Doyon 19 Las! Csg: 7" @ 9633' Next Csg: 4 1/2" completion Shoe Test: ppg )peration At 0600: Clrc for LOTIFIT @ 7" csg shoe Jpcoming Operations: Perform LOTIFIT - Change over to FIe-Pro - Drill 6 1/8" hole MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL LSND 9522 4 N TST OS/25/2001 05/25/2001 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 10.0ppg 175 61/8" 05/01/2001 OS/22/2001 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 44sqc 235 HTC N SPACE 05/23/2001 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 11/21 145 STR-386 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2330 8/12/18 1904394 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER 870 5.8 OS/24/2001 USED - BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 90 11.6m1/30 mln 9644 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8.5% 11500 0 CD1-19 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP'F 15 379bbl 2050 III / / CD2.42 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 14 15.0 1121 I ' - ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 50' 9.8 5.51611 - - LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR 'F -9.67 5.0% \5411 .69 0 PIT VOL GPM2 JETS JETS PHILLIPS 1 1240 II 1511511511511 111\1 0 PERSONNEL 150 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 30140130140 0 PERSONNEL $1864 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $166500 III III III 0 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 14 MI 9.9+ III III III PERSONNEL TOTAL 46 BHA DESCRIPTION ~llt.stab,turbo back, Navldrlll Mach 1X wi 1.20 AKO, NM Stab, NM drill pipe -compr srv, MWD, AP sub, Neutron sub. MWD, 2 NM drill Ipe compr srv, XO, 3 HWDP 4" - Jars - 2 HWDP 4" DRILLPIPEDATA BHA NO 4 OD ID WEIGHT GRADE CONNECTION CLASS 2 LENGTH BHA LENGTH 361.73 4 2.562 25.16 HWDP Prem DATE LAST 4 3.240 15.7 S-135 Prem INSPECTED: HOURS ON JARS: 181.4 TI'.':= I F i\l~ I ~;OURS ::::FS COJF "IC-I.F..:;:=CT 'I Pi'¡;,S:OP:; I O?ER,\-I.:;\S :-RO'.'c.:::~-:::~ 12:00 AM 12:30 AM 0.50 CEMENT SIPI Milking Hule Install crnt huacJ 12:30 AM 02:00 AM 1.50 CIRC S1P1 Making Hole Clrc and condition mud for cmt Job 02:00 AM 04:00 AM 2.00 CMT_CSG S1P1 Making Hole Cmt 7" csg . test lines to 3000 psi. Pump 20 bbls Arco wash @ 8.3 ppg. 50 bbls Acro spacer @ 12.5 ppg. drop btm plug - mix & pump 117 Sacks Class G 24 bbls @ 15.8 ppg - drop top plug wi 20 bbls water fl Dowell. switch to rig pump & displace wi 345 bbls 9.9 ppg mud - bumped plug. floats held. CIP @ 0345 hrs. 04:00 AM 05:30 AM 1.50 CEMENT S1P1 Making Hole Rig down cmt head & csg tools - pull thin wall wear bushing - set & test pack-off to 5000 psi 05:30 AM 06:30 AM 1.00 BOPE PROD Making Hole Change top pipe rams f/7" to 3 1/2" x 6" 06:30 AM 02:00 PM 7.50 BOPE PROD Making Hole Set test plug - Test BOPE - pipe rams, blind rams, kill & choke line valves, choke manifold valves, floor valves, top drive valves to 250 psi low & 5000 psi high. Hydrll to 250 psi low & 3500 psi high. accumulator closure test - gas detectors. Test witnessed and approved by Jeff Jones AOGCC . pull test plug - set wear bushing - blown down choke and kill lines 02:00 PM 05:00 PM 3.00 BHA PROD Making Hole MIU BHA # 4 . RIH to 361' wi BHA 05:00 PM 08:30 PM 3.50 TRIP_IN PROD Making Hole RIH picking up 4" DP fl pipe shed to 738' . Test MWD . Continue RIH picking up 4" DP to 4080' - fill pipe 08:30 PM 10:30 PM 2.00 TRIP_IN PROD Making Hole RIH wi BHA #4 wi DP fl derrick to 9494'. took wt. 10:30 PM 11:00 PM 0.50 CLN_OUT PROD Making Hole Break clrc . clean out cmt stringers to 9522' 11:00 PM 12:00 AM 1.00 CIRC PROD Making Hole Clrc btms up and condition for casing test 24.00 Daily Drilling Report: CD2-42 OS/25/2001 Page 1 CASING TEST and FORMATION INTEGRITY TEST Well Name: 5/25/01 Supervisor: Don Mickey CD2-42 Date: Reason(s) for test: 0 Initial Casing Shoe Test [2] Formation Adequancy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 40# L-80 BTC CSG 7" 26# L-80 BTCM CSG TOC 8,975' TMD 7,035' TVD x Casing Setting Depth: 2,581' TMD 2,376' TVD Mud Weight: 9.9 ppg EMW= Press + Mud Weight .052 X TVD Hole Depth: Length of Open Hole: 6,394' 687 psi 0.052 x 2,376' + 9.9 ppg = EMW = 15.5 ppg Pump output = .020 BPS *****Used cement unit Fluid Pumped = 15.0 bbl BLED BACK 800 psi I 1 I 700 psi 600 psi I T I I 500 psi w 0::: :J (j) 400 psi (j) W 0::: Il. 300 psi I I I j i ¡ I ¡ , I I i I 1 I 'n=n. ~~~~:~ ~~~~ME 200 psi I I ì -1 I I I 100 psi Opsi 0.0 1.0 2.0 3.0 4.0 5.0 6.0 7.0 8.0 9.0 10.0 11.0 12.0 13.0 14.0 15.0 16.0 17.0 18.0 19.0 20.0 21.0 22.0 23.0 24.0 25.0 bbl. bbl. bbls bbl. bbl. bbls bbl. bbls bbls bbl. bbls bbls bbl. bbls bbls bbl. bbl. bbls bbls bbls bbls bbls bbls bbls bbl. bbl. BBLS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE I I 1 i J I r---------------'------ --------- --.-------- --------, I I I I I I I I ~-----------------~----- - -------- -~------- - --:----t : I 0.0 bbls I 0 pSI: ~----------------+---------------~------------.- ---I ; : 1.0 bbls : 20 pSI: 1-----------------'---- - - - -- -- - - - - - - -1.--- - - - - - - - - - - -- - I ! ! 2.0 bbls ! 136 psi! o---------------~--- --------- - ---1.------ - ___n---- I ! ! 3.0 bbls ! 283 psi! 0-----------------+----- ----- -------f------- ---------J ! ! 4.0 bbls ! 424 psi! .----------------1------------ -----.----- ----- - --- --J ! ! 5.0 bbls ! 550 psi! r-----------------,----------------r----------------' : : 6.0 bbls : 687 psi I ~-----_--____n_+____-----------~----------------I ; : 7.0 bbls : 676 psi: ~---------------~------------- - ---~------- ------. ---I ; ; 8.0 bbls : 626 pSI: ~-----------------i----- ------------~------ ----- --:,- --f : ; 9.0 bbls : 601 pSI: L_________n--__-.L.-----------------I.------______n_1 I I I I I I I I I I I I 0---- ------------~----___--__n_- --1.------- ---- - -_of I I I I I I I I I I I I 0-------------- --oJ-------- - --- ------,.---- - ------- - --of I I I I I I , I I I I I .-_n___--__-----_,,-__--n______nnf-_____-----------' I I I I I I I I I I I I r----------------,------------------r----------------' I I I I I I I I ~-------------- ---~--- - ---- ---- - ---~------ ----- -----1 I I , I I I I I :------______n___~__----______n___~______n_--___nt I I I I I I I I :-----------------+-----------------~----------------t I I I I I I I I L_----_----------'-----------------I.---------------' I I I I I I I I I I I I >---------------.t----______n_n_-O-__n_--___n___' I I I I I I I I I I I I 0------------ ----+----- ---- --------,.--- ---- ---------J I I I I I I I I I I I I .-----------------..-------------____,..._n_--__--_----' I I I I I I I I I I I I r---- ______n____-,-__n______-- -----r---- _n_- -------, I I I I I I I I ! I ----------------' , I SHUT IN TIME; SHUT IN PRESSURE ~----------:-----i------ - --- - --- - ---r--8O--- --- - --:-- -, : 0.0 mln : : 601 pSI: ~__n______-,:-_n-i-----_n_____n_n~________n_--.---f ; 1.0 mln I I 464 pSI: 1.----------------'-----------------1.----------------' I 2 O. I I 449 . I I . mln : : pSI: ....----------- ----...0-.-- -------- - --- - -1.-------- - -------, I 3 O. I I 419 . I : . mln : : pSI: O--------------_--1-__n_- --______n_f-__- ____n_- ----- J ! 4.0 mín ! ! 404 psi! .-----------------..-----------------.--- --- - --- - -----. ! 5.0 min ! ! 394 psi! r---------- --- ----.,..------------- - ---r---------- - ---- -, ; 6.0 min ; : 374 psi: ~_n______- _n- --+-_---__n____nn~___- ------------1 ; 7.0 min : : 369 psi: ~---------------i------- --- ---- ----r-- ---- --- - ---- - t : 8.0 mín I : 369 psi: '----_____n_____.J_---------------- -~---- -------- ---f ! 9.0 mín ! : 364 psi: I.-______n__n__.l____nn - --- _n___I.__-- --- _____n_' ! 10.0 min ! ! 359 psi! O----__nn__---.t--__n_______n_n"_____n______---J i J I j ,..--- --- - ---- ---.,--------------. _____-n-- ----or I I I I I I I I 1-- ----- ----- ----t---- - ---- --- __+80__--__----- --I I I I I I , I I -- -------- ---- --t---- - ---- ---- -_~____n_---_n--I I I I I I I I I '- --- - --- ------ ¿_---- ___n__n_I.____----______n' I , I I I I I I , I I I ..- -------- ---- -¿----- - - ---- -- - -to- ----------- ----I I I I I I I I I 1--- _n- --------~------ - ---- ---_~____n____- --_nl --'c I I I ' I I I I I I . ..--- -------- ---..---------------.----------------1 I I I I , I I I , I I I ,..n__- --- - ---- - 't---- ----- ---- - -r----- ------ ---or I , r I I I I I 1-- --- _n--__-- - f------ - ------- -~_____n___- --_nl I I I I I I I I 1------ ---- ---- --t------ - ---- -___~__n__-__- ------1 I I I I ~-- - ---- -------t----------- ----~----------- ----- ¡ I I I I I I I I Ln______n_- --¿_--- - ----- --- -_I._----__--___n__1 I I I I I , r , I I I , ..---- - ---- ----- .---- - ----- -----f------- --- --- ----I I I I I I I I , I I I I "__n- -- ------ - ..---------- --- --..------ ____n- ---. I I I I I I I I I I I I ..-_n_- -- - -- _n..-____-- -- -- -- -_f-____n__- - -----. I I I I I I I I . I I I ...----- ___n__- -'t------- -- --n--r- ----------- ---or I I I I ~-- ---- --- ---- _¡__n__- --------~- ------------ --- i I I I I I I I I 1--- - ---- ---- - ---t---- ------- ----~---------------I I I I I I I I I rn_____---- -- -t----- ---- - -----~----- - ------- --I I I I I I I I I L.._n- -------- -¿_-------------_I.- ---- - ------ ___I I I I I I I I I I I I , I I I I I I I I I I I 1-- --------- - -- ..-------- _n-_-_" -------- ------- -, I , I I I I I I I I I I ..---- ----- ----- ..--__n___- --- --f------- --- -------, : : I : I I I , ...---- - ---- ---- - 'tn--- __n___- - -r- ------- _n- ---, I : : :r~c 1--- - ---- ---- - --f------- - --- - ---~ - --------------- I I I ' I I I I 1-_80__--___--- - -t----- ---- - ____+n___- --- ----- --I I I I I I I I I -- --- - __n- --- - t ----- ----- --- --~------- ----- ----I I I I I I I I I L- -------- - --- - ¿_---- ---- - -----1.- ------ ---______1 I I I I I I I I I I I I I-__n_--- ---- -.--------- --- -- -..- ----- - ------ ---I , I I I , I I I I I I I t--- - ---- - --- - --..--- ----- --- - ---,.- --------- ------1 I , , I I I I I I I I I ..-- - ----- - - - ---..------ -- --- - ---f- ---------- ---- --J I I I I I I , I I I I I ,..n__--_- -- ---- 't----- - --- - -----r --------- --- --r I I I I I I I I I-_n__--- _n__- f_n_- - --- - - -__+___n- ------ ----I I I I I I I I I -- ----------- - - -t_n__- --- ------~ _____n- - ----- --I I I I I I I I I -- -------- ---- - t----- - ------- - -~------ - --- -- - ---I I I I I I I I I L- - - -- --- - -- - - -¿ ----- - - - - - -- - - -I._u_-- - -- -______1 , I I I I , , , I I I I ..---- ___n__n_. _nn___- ---- --"-______n____---' NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY WELL PERMIT CHECKLIST COMPANY WELL NAM&::tIz -) S PROGRAM: exp - dev - redrll FIELD & POOL f 2.01 /"'}I".) INIT CLASS GEOL AREA ?7'd ADMINISTRATION 1. Pennitfee attached. . . . . . . . . . . . . . . . . . . . . . . Y 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. 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Pennit can be issued without conservation order. . . . . . . . Y N 12. Pennit can.be issued without administrative approval.. . . . . Y N 13. Can permit be approved before 15-day wait.. . . . . . . . . . 'YJ N 14. Conductor string provided ., . . . . . . .. . . . . . . . . . N 15. Surface casing protects all known USDWs. . .. . . . . . . . N 16. GMT vol adequate to circulate on conductor & surf csg. . . . . $ ~ ~~: g~:il::~:~k~~i~::~,:;~~~:~:,~g:..::: ::: ~. Nj~;:'~U~~~~~~~~ 19. Casing designs adequate for C, T, B & permafrost. . . . . . . CD 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . C? N ~~~c-....c.:f\ ':> I G'Ð~ ~ . 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~ \...J ~ . 22. Adequate well bore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling .fluid program schematic & equip list adequate. . . . . N A~ Jf!J!E. 1£ ~~: :g~~sp~~~~::,~~~~~~;nt~sit~ . . . "> SGJ . Psig: ~ ~ ";;Ç> <1:""" ~ ~ "-5 <.{ ') f~ '\ ~ ~ . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N . 28. Work will occur without operation shutdbwn. . . . . . . . . . . Y 'ÂN ' 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Q::!) 30. Pennit can be issued w/o hydrogen sulfide measures. . . . ,. Y N 31. Data presented on potential overpressure zones. . . . . . . Y N' /! ) /J J 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . -.LJL.Z:l R _D))!Jl 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N ' . ~ 34. Contact name/phone for weekly progress reports [exploratory onl Y N ~ AN N U LAR DlS POSAL35. With proper cementing records, this plan. 0. tJi\ \ '"" ~ ~ -\C> e,,\>\.>~~ QtN'l'>\ ~ < À ~ "'-Ì\ \ , blit ~~ . (A) will contain waste in a suitable receiving zone; . . . . . . . w N ~&\J{.S l'E-.JÐ N/P7rD {\Pf>. ' (B) will not contaminate freshwater; or cause drilling waste. .. ~ N to surface;. .. (C) will not impair mechanical integrity of the well used for disposal; ~ N (0) will not damage producing formation or impair recovery from a ø N pool; and . E will not circumvent 20 MC 25.252 or 20 MC 25.412. GEOL GY: ENGINEERING: UIC/Annular COMMISSION: ~þ WM '8~s JM serv ~ wellbore seg _ann. disposal para req - UNIT# ~o S"a3'~ðON/OFF SHORE ð.J c 0 Z 0 -I :E ::a ( R E.~E¡ ~) ENGINEERING - -I' m - Z -I ,:I:' GEOLOGY - en » ::a m » ( APPR DATE WN\ ~, N Com m e nts/l ns tructi ons: ~ 7/6 J c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ( (: Well H ¡story 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 information. information of this . , nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically . . organize this category of information. ,. ( i{ C)O/-J5/ /0790 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 16 15:18:32 2001 Reel Header Service name............ .LISTPE Date.....................Ol/ll/16 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.....................Ol/11/16 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Physical EOF Writing Library. Scientific Technical Services Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. CD2-15 PB2 501032038671 PHILLIPS Alaska, Inc. Sperry Sun 16-NOV-Ol MWD RUN 3 MWD RUN 4 MWD RUN 6 AK-MM-1l163 AK-MM-1l163 AK-MM-l1163 R. KRELL R. KRELL M. HANIK D. BURLEY D. MICKEY D. MICKEY MWD RUN 7 AK-MM-1l163 M. HANIK D. MICKEY 2 llN 4E 1716 1545 MSL 0) .00 52.42 15.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2655.0 6.500 7.000 9830.0 ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE (' { ;t NOTED. 2. MWD RUNS 1&2 ARE DIRECTIONAL ONLY, AND NOT PRESENTED. 3. MWD RUNS 3-7 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 5 MADE NO FOOTAGE IN THIS WELL AND IS NOT PRESENTED, AND MWD RUN 6 IS PRESENTED FOR ROP DATA ONLY. 4. GAMMA RAY DATA FOR MWD RUNS 4&7 HAS BEEN CORRECTED FOR 6% BY WEIGHT KCL IN THE MUD, AS WELL AS FOR HOLE SIZE AND MUD WEIGHT. 5. THIS WELL SIDETRACKS FROM CD2-15 PB1 AT 11806'MD, 7192'TVD (IN MWD RUN 6), AND CD2-15 SIDETRACKS FROM THIS WELL AT 13450'MD, 7190'TVD AND IS TIED TO THOSE WELLBORES AT THE KICKOFF POINTS. 6. MWD DATA IS CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 09/26/01. DFE FOR THIS WELL IS 52.42' AMSL. 7. MWD RUNS 1-7 REPRESENT WELL CD2-15 PB2 WITH API#: 50-103-20386-71. THIS WELL REACHED A TOTAL DEPTH (TO) OF 13776'MD, 7187'TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ WHILE DRILLING. RESISTIVITY (EXTRA RESISTIVITY RESISTIVITY (MEDIUM RESISTIVITY (DEEP File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/16 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 FET RPD RPM RPS RPX SROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2636.0 2645.0 2645.0 2645.0 2645.0 2645.0 2667.0 STOP DEPTH 13732.5 13740.0 13740.0 13740.0 13740.0 13740.0 13775.5 # (' ~. BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE B IT RUN NO MERGE TOP MERGE BASE MWD 3 2636.0 9840.0 MWD 4 9840.0 11806.0 MWD 6 11806.0 11865.0 MWD 7 11865.0 13775.5 $ # 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 2636 13775.5 8205.75 22280 2636 13775.5 ROP MWD FPH 0.03 356.97 135.74 22218 2667 13775.5 GR MWD API 31. 73 405.77 92.4559 22194 2636 13732.5 RPX MWD OHMM 0.19 2000 7.99995 22152 2645 13740 RPS MWD OHMM 0.1 2000 8.84308 22152 2645 13740 RPM MWD OHMM 0.06 2000 10.4684 22152 2645 13740 RPD MWD OHMM 0.03 2000 12.2051 22152 2645 13740 FET MWD HOUR 0.17 110.64 1. 1695 22152 2645 13740 First Reading For Entire File......... .2636 Last Reading For Entire File.......... .13775.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/16 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...... .01/11/16 Maximum Physical Record. .65535 (,' File Type..... ... .... ... .LO Previous File Name.... ...STSLIB.001 Comment Record FI LE HEADER FI LE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 2 I( header data for each bit run in separate files. 3 .5000 START DEPTH 2636.0 2645.0 2645.0 2645.0 2645.0 2645.0 2667.0 STOP DEPTH 9807.5 9800.0 9800.0 9800.0 9800.0 9800.0 9840.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined 14-0CT-01 Insite 66.16 Memory 9840.0 42.2 80.7 TOOL NUMBER PB02203HWRGV6 PB02203HWRGV6 8.500 2655.0 LSND 9.60 42.0 8.8 500 5.0 1.960 .953 1. 950 1. 970 67.0 145.0 67.0 67.0 ( ( Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value......... ...,........ .-999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FPH 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 2636 9840 6238 14409 2636 9840 ROP MWD030 FPH 0.06 356.97 158.603 14347 2667 9840 GR MWD030 API 42.04 405.77 111.711 14344 2636 9807.5 RPX MWD030 OHMM 0.29 2000 5.19679 14311 2645 9800 RPS MWD030 OHMM 0.1 2000 5.38658 14311 2645 9800 RPM MWD030 OHMM 0.06 2000 5.75417 14311 2645 9800 RPD MWD030 OHMM 0.03 2000 9.28692 14311 2645 9800 FET MWD030 HOUR 0.17 43.58 0.830202 14311 2645 9800 First Reading For Entire File......... .2636 Last Reading For Entire File.......... .9840 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/16 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...... .01/11/16 Maximum Physical Record. .65535 File Type... ......... ... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 3 header data for each bit run in separate files. 4 .5000 START DEPTH 9808.0 9820.0 9820.0 9820.0 9820.0 9820.0 9840.5 STOP DEPTH 11806.0 11806.0 11806.0 11806.0 11806.0 11806.0 11806.0 # LOG HEADER DATA It DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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: $ # 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 ( 19-0CT-01 Insite 66.16 Memory 12209.0 86.6 93.8 TOOL NUMBER PB02079HA4 PB02079HA4 6.125 9830.0 Flo Pro 9.20 48.0 8.9 31000 3.6 .140 .060 .100 .160 65.0 159.8 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FPH 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 9808 11806 10807 3997 9808 11806 ROP MWD040 FPH 0.1 209.49 102.654 3932 9840.5 11806 GR MWD040 API 31.73 86.86 58.1106 3997 9808 11806 ( RPX RPS RPM RPD FET MWD040 MWD040 MWD040 MWD040 MWD040 1078.2 1079.28 2000 2000 72.31 OHMM OHMM OHMM OHMM HOUR 0.19 0.23 4.46 0.26 0.24 First Reading For Entire File........ ..9808 Last Reading For Entire File.......... .11806 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/16 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 4 12.1653 14.0203 20.9973 18.0466 1.51077 3973 3973 3973 3973 3973 header data for each bit run in separate files. 6 .5000 START DEPTH 11806.5 STOP DEPTH 11865.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # 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) 22-0CT-Ol Insite 66.16 Memory 11865.0 90.4 91. 9 TOOL NUMBER 6.125 Flo Pro 9.20 48.0 8.8 31500 3.2 ( 9820 9820 9820 9820 9820 11806 11806 11806 11806 11806 ( MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .300 .124 .070 .220 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD060 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FPH 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD060 FPH Min 11806.5 0.03 Max 11865 97.18 Mean Nsam 11835.8 118 22.6253 118 First Reading For Entire File......... .11806.5 Last Reading For Entire File.......... .11865 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .01/11/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/16 Maximum Physical Record. .65535 File Type............... .LO . Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log B IT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 5 'I ( 62.0 159.8 62.0 62.0 First Reading 11806.5 11806.5 Last Reading 11865 11865 header data for each bit run in separate files. 7 .5000 START DEPTH STOP DEPTH ( RPD RPM RPS RPX GR FET ROP $ 11806.5 11806.5 11806.5 11806.5 11806.5 11806.5 11865.5 13740.0 13740.0 13740.0 13740.0 13732.5 13740.0 13775.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O II ':~ 25-0CT-01 Insite 66.16 Memory 13776.0 86.7 91. 8 TOOL NUMBER PB02226HA4 PB02226HA4 6.125 Flo Pro 9.20 50.0 9.5 32000 3.2 .140 .062 .100 .150 65.0 156.2 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FPH 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 ( ( RPD FET MWD070 MWD070 OHMM HOUR 4 4 1 1 68 68 24 28 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11806.5 13775.5 12791 3939 11806.5 13775.5 ROP MWD070 FPH 0.06 212.57 87.4337 3821 11865.5 13775.5 GR MWD070 API 37.47 125.04 56.4017 3853 11806.5 13732.5 RPX MWD070 OHMM 2.62 25.66 14.0928 3868 11806.5 13740 RPS MWD070 OHMM 3.98 25.94 16.3138 3868 11806.5 13740 RPM MWD070 OHMM 4.88 24.27 17.0955 3868 11806.5 13740 RPD MWD070 OHMM 6.31 23.87 17 . 0019 3868 11806.5 13740 FET MWD070 HOUR 0.21 110.64 2.07432 3868 11806.5 13740 First Reading For Entire File......... .11806.5 Last Reading For Entire File.......... .13775.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................01/11/16 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.....................01/11/16 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name......... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ( (' Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Nov 14 16:46:10 2001 Reel Header Service name. ........... .LISTPE Date.....................01/11/14 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.....................01/11/14 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments.................STS LIS Physical EOF Writing Library. Scientific Technical Services Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: CD2-15 PB1 501032038670 PHILLIPS Alaska, Inc. Sperry Sun 14-NOV-01 MWD RUN 3 MWD RUN 4 MWD RUN 5 AK-MM-11163 AK-MM-11163 AK-MM-11163 R. KRELL R. KRELL M. HANIK D. BURLEY D. MICKEY D. MICKEY 2 llN 4E 1716 1545 MSL 0) .00 52.42 15.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2655.0 6.125 7.000 9830.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1&2 ARE DIRECTIONAL ONLY, AND NOT PRESENTED. 3. MWD RUNS 3-5 ARE DIRECTIONAL WITH DUAL GAMMA RAY dOJ-J51 JOÎ9û ( ( (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. GAMMA RAY DATA FOR MWD RUNS 4-5 HAS BEEN CORRECTED FOR 6% BY WEIGHT KCL IN THE MUD, AS WELL AS FOR HOLE SIZE AND MUD WEIGHT. 5. CD2-15 FINAL WELLBORE SIDETRACKS FROM THIS WELL AT 11806'MD, 7192'TVD AND IS TIED TO THIS WELLBORE AT THE KICKOFF POINT. 6. MWD DATA IS CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 09/26/01. DFE FOR THIS WELL IS 52.42' AMSL. 7. MWD RUNS 1-5 REPRESENT WELL CD2-15PB1 WITH API#: 50-103-20386-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12273'MD, 7177'TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ WHILE DRILLING. RESISTIVITY (EXTRA RESISTIVITY RESISTIVITY (MEDIUM RESISTIVITY (DEEP File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/14 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 FET RPD RPM RPS RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2636.0 2645.0 2645.0 2645.0 2645.0 2645.0 2667.0 STOP DEPTH 12230.5 12237.5 12237.5 12237.5 12237.5 12237.5 12273.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 3 4 5 MERGE TOP 2636.0 9840.0 12209.0 MERGE BASE 9840.0 12209.0 12273.0 # { (' REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.......... .... ....0 Data Specification Block Type.. ...0 Logging Direction....... ..... .... . Down Optical log depth units.......... .Feet Data Reference Point.... ...... ....Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...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 2636 12273 7454.5 19275 2636 12273 ROP MWD FPH 0.05 356.97 143.119 19213 2667 12273 GR MWD API 31.73 405.77 98.4293 19190 2636 12230.5 RPX MWD OHMM 0.19 2000 6.92057 19147 2645 12237.5 RPS MWD OHMM 0.1 2000 7.54634 19147 2645 12237.5 RPM MWD OHMM 0.06 2000 9.30613 19147 2645 12237.5 RPD MWD OHMM 0.03 2000 11.3444 19147 2645 12237.5 FET MWD HOUR 0.17 72.31 1.11309 19147 2645 12237.5 First Reading For Entire File......... .2636 Last Reading For Entire File......... ..12273 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/14 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...... .01/11/14 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR 2 header data for each bit run in separate files. 3 .5000 START DEPTH 2636.0 STOP DEPTH 9807.5 ,( RPD RPM RPS RPX FET ROP $ 2645.0 2645.0 2645.0 2645.0 2645.0 2667.0 9800.0 9800.0 9800.0 9800.0 9800.0 9840.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.. .'................. .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O (' 14-0CT-01 Insite 66.16 Memory 9840.0 42.2 80.7 TOOL NUMBER PB02203HWRGV6 PB02203HWRGV6 8.500 2655.0 LSND 9.60 42.0 8.8 500 5.0 1.960 .953 1.950 1. 970 67.0 145.0 67.0 67.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FPH 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 2636 9840 6238 14409 2636 9840 ROP MWD030 FPH 0.06 356.97 158.607 14347 2667 9840 GR MWD030 API 42.04 405.77 111.711 14344 2636 9807.5 RPX MWD030 OHMM 0.29 2000 5.19679 14311 2645 9800 RPS MWD030 OHMM 0.1 2000 5.38658 14311 2645 9800 RPM MWD030 OHMM 0.06 2000 5.75417 14311 2645 9800 RPD MWD030 OHMM 0.03 2000 9.28692 14311 2645 9800 FET MWD030 HOUR 0.17 43.58 0.830202 14311 2645 9800 First Reading For Entire File......... .2636 Last Reading For Entire File.......... .9840 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/14 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...... .01/11/14 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Corrunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SGRC FET RPD RPM RPS RPX ROP $ 3 header data for each bit run in separate files. 4 .5000 START DEPTH 9808.0 9820.0 9820.0 9820.0 9820.0 9820.0 9840.5 STOP DEPTH 12165.5 12172.5 12172.5 12172.5 12172.5 12172.5 12209.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 19-0CT-01 Insite 66.16 Memory 12209.0 86.6 93.8 # TOOL STRING (TOP TO BOTTOM) I( VENDOR TOOL CODE DGR EWR4 $ TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.....................60 .lIN Max frames per record............ .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O ( TOOL NUMBER PB02108GR4 PB02108GR4 6.125 9830.0 Flo Pro 9.20 48.0 8.9 31000 3.6 .140 .060 .100 .160 65.0 159.8 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FPH 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 9808 12209 11008.5 4803 9808 12209 ROP MWD040 FPH 0.05 209.49 99.8086 4738 9840.5 12209 GR MWD040 API 31. 73 86.86 57.6943 4716 9808 12165.5 RPX MWD040 OHMM 0.19 1078.2 12.2654 4706 9820 12172.5 RPS MWD040 OHMM 0.23 1079.28 14.2076 4706 9820 12172.5 RPM MWD040 OHMM 4.46 2000 20.2203 4706 9820 12172.5 RPD MWD040 OHMM 0.26 2000 17.7405 4706 9820 12172.5 FET MWD040 HOUR 0.24 72.31 1.41456 4706 9820 12172.5 First Reading For Entire File......... .9808 Last Reading For Entire File.......... .12209 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... ( Version Number..... ..... .1.0.0 Date of Generation...... .01/11/14 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/11/14 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 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 $ 4 { header data for each bit run in separate files. 5 .5000 START DEPTH 12167.0 12173.5 12173.5 12173.5 12173.5 12173.5 12209.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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 $ STOP DEPTH 12230.5 12237.5 12237.5 12237.5 12237.5 12237.5 12273.0 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 20-0CT-01 Insite 66.16 Memory 12273.0 92.4 92.4 TOOL NUMBER PB02108GR4 PB02108GR4 6.125 Flo Pro 9.20 47.0 9.1 31000 3.4 .300 .124 .070 .220 62.0 159.8 62.0 62.0 ( { MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ..............0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent va1ue......................-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 MWD050 FPH 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12167 12273 12220 213 12167 12273 ROP MWD050 FPH 0.11 75 10.2438 128 12209.5 12273 GR MWD050 API 78.91 128.63 111.246 128 12167 12230.5 RPX MWD050 OHMM 1. 98 6.03 3.18636 129 12173.5 12237.5 RPS MWD050 OHMM 2.42 7.63 4.15147 129 12173.5 12237.5 RPM MWD050 OHMM 2.57 10.62 5.20574 129 12173.5 12237.5 RPD MWD050 OHMM 3.07 13.86 6.27202 129 12173.5 12237.5 FET MWD050 HOUR 10.62 33.71 21.4429 129 12173.5 12237.5 First Reading For Entire File......... .12167 Last Reading For Entire File.......... .12273 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .01/11/14 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................01/11/14 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.....................01/11/14 Origin...................STS 'I ( Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File ( Scientific Technical Services e' . ( Sperry-Sun Drilling Se~vjces LIS Scan Utility $Revi sian: ~~ :3 ~isLib $Revisian: 4 $ fri Nov 09 14:45:03 :001 Reel Header Service name...... ... ....LISTPE Date.....................O1/11/I:J~; Ori,;¡in...................STS Reel Name................UNKNOlIiJN Continuation Number. .... .01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Tape Header Service name......... ....LISTPE Date.....................Ol/ll/09 Origin...................STS Tape Name................UNKNOWN Continuation Number......O1 Previous Tape Name.......UN~~OWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) ¡V¡WD/MAD LOGS II WELL NþJv[E: API NUMBER: OPERATOR: LOGGING COMPJ.\NY: TAPE CREATION DATE: if JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AI{-MM-11163 R. KRELL D. BURLEY ,JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN '7 AK-MM-1l163 M. BANIK D. MICKEY II SURFACE, LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSI-IIN(~: DERRICK FLOOR: GROUND LEVEL: MSL 0) II WELL CASING RECORD Writing Library. Writing Libcary. 'I" ( Scientific Technical Services Scientific Technical Services CO2-I5 501032038600 PHILLIPS Alaska, Inc. Sperry Sun 09-NOV-Ol MWO RUN 4 AK-MM-l1163 R. KRELL D. MICKEY MW.D [{UN EI AK-MM-11163 M. BANIK D. MICKEY :,; I1N 4E 1716 1545 .00 52.42 15.90 MWD RUN 6 AK-MM-11163 M. HANIK D. MICKEY MWD RUN 9 J.\K-MM-1l163 M. HANIK D. BURLEY 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2655.0 6.125 7.000 9830.0 # REMARKS: ¿;;OJ-)51 10790 ( !( ~. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE ìWTED. MÍ'JO RUNS 1&2 .r>..RE DIRECTION.r>..L ONLY, .r>..ND NOT PRESENTED. 3. HWD RUNS 3-9 ARE DIRECTION.r>..L 1'JITH DUAL Gp.J.l]v1A RfI,'c. (DGR) UTILIZING GEIGER-HUELLER TUBE DETECTORS, AND ELECTROt-1AGNETIC :-vAVE RESISTIVITY PHASE-4 (EWR4). HWD RUN 5 MADE NO FOOTAGE IN THIS WELL AND IS NOT PRESENTED, AND MWD RUN 6 IS PRESENTED FOR ROP DATA ONLY. o}:\T,r>.. FROM 13450't-'!D, 7190'TVD TO 13929'MD, 7216'TVD NAS OBTI-\INED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED ~'JHILE RUNNING IN THE HOLE FOR MND RUN 9. THE MAD DATA ARE PRESENTED AS MERGED MWD RUN 9 DATA FILLING IN A MISSING INTERVAL IN MND RUN 8. 4. GAMMA RAY DATA FOR MWD RUNS 4-9 HAS BEEN CORRECTED FOR 6% BY WEIGHT KCL IN THE MUD, AS WELL J\.S FOR HOLE SIZE AND MUD WEIGHT. 5. THIS WELL SIDETRACKS FROM CO2-L5 PBl AT 11806 'MD, 7l92'TVD (IN Míti!D RUN 6), AND FROM CD2-1S PB2 AT 134S0'Þ1D, 7190'TVD (IN MWD RUN 8), AND IS TIED TO TII0SE WELLBORES AT THE KICKOFF POIN'l'S. 6. MWD DATA IS CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 09/26/01. DFE FOR THIS WELL IS 52.42' AMSI,. 7. MWD RUNS 1-9 REPRESENT WELL CD2-1S WITH API#: 50-103-20386-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14161'MD, 7227'TVD. SROP = SMOO'I'HED RATE or PENE'rRA'l'ION WHILE DRILLING. SGRC = S}100THED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIPl'-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIfT-DERIVED RESISTIVITY (DEEP SPACING) . srXE ~-= SMOO'l'HED FORMA'l'ION EXPOSURE 'rIME. $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......01/l1/09 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 SUHHARY 1 clipped curves; all bit runs merged. .5000 f t ;:EU TOOL CODE START DEPTH :2636.0 2645.0 2645.0 2645.0 2645.0 2645.5 STOP DEPTH 14118.0 14125.0 14125.0 14125.0 14125 . C' ,3R :-;Pl-I :£1' RPS RP;': RPD ROP $ 2667.0 14125.(' 14161. I:' # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH __n____- B.7\SELINE DEPTH :~ » MERGED PBU MWD MWD MWD MWD MWD MWD $ DATA TOOL SOURCE CODE BIT RUN NO MERGE TOP MERGE BASE 3 2636.0 9840.0 4 9840.0 11806.0 6 11806.0 11865.0 7 11865.0 13450.0 8 13450.0 13929.0 9 13929.0 14161.0 MERGED MAIN PASS. $ # 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 .lIN Max frames per record.............Undefined Absent va1ue......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Oreie:c Units Size Nsarn Rr::~p Code Offset Channel DEPT PI' 4 1 6e 0 1 ROP !V¡WD FPH 4 1 68 4 2 GR MWD A.PI 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM HTriID OHM}!] 4 1 68 20 6 RPD MWD OHMM <1 1 68 24 7 FET HWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2636 141.61 8398.5 23051 2636 14161 ROP MWD FPE 0 356.97 133.111 22989 2667 14161 GR MWD API 30.89 405.77 91. 236 22965 2636 14118 RPX HWD OHMH 0.19 2000 8.01278 22922 2645 14125 RPS MWD OHMM 0.1 2000 9.01357 22922 2645 14125 RPM MWD OHMM 0.06 2000 10.8275 22922 t~64 5 14125 RPD MWD OHMM 0.03 2000 12.5304 22921 2645.5 14125 FET MWD HOUR 0.17 110.64 2.42338 22922 2645 14125 First Reading For Entire File..........2636 Last Reading For Entire File...........14161 File Trailer Service name......,......STSLIB.OO1 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......01/11/09 Maximum Physical Record..65535 ( ?ile TYl=,e................10 Next File Name....... ....3T31IB.002 Physical EOr File Header Service name.. ....... ....8TSLIB.Oû~ Service Sub Level Name... Version Number.. ..... ....1.0.0 Date of Generation.......Ol/l1/09 Maximum Physical Record. .65535 File Type................LO Previous File Name... ....ST8LIB.001 Comment Record FILE HEADER fILE ¡'-lUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD FET RFS RPX RP~1 ROP $ 2 ( header data for each bit run in separate files. :3 . ~)OOO START DEPTH 2636.0 2645.0 2645.0 2645.0 2645.0 2645.0 2667.0 Ii LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOF1'WARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY ORREAL-TH1E): 'I'D DRILLER (F'1'): TOP LOG INTERVAL (F'r): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: tvIAXIMUtvI ANGLE: # STOP DEPTH 9807.5 9800.0 9800.0 9800.0 9800.0 9800.0 9840.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) '1'OOL 'T'Y PE: DUJ-\L GJ\MMA RJW ELECTRO¡VIAG. RESIS. 4 II BOREHOLE AND Cl-\SING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEP'l'H (F1~): # BOREHOl,E CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT 'rEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD 1\'1' JVlAX CIF\CULA'l'ING TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSIT'Y: 14-0CT-01 Insi-te 66.16 Memory 9840.0 42.2 80.7 TOOL NUMBER PB02203HWRGV6 PB02203HWRGV6 8.S00 2655.0 LSND 9.60 42.0 0 0 u.u 500 5.0 1.960 .953 1. 950 1.970 67.0 145.0 67.0 67.0 ( :( HOLE CORRECTION (IN): TOOL ST}\¡\JDOFF (IN): EWR FREQUENCY (HZ): it REf-'Li\RKS: $ # Data Format Specification Record Data Record Type... '" ... ....... ..0 Data Specification Block TYJ..-,e..... (J 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 Specificat.ion Block sub-type... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT E"I' 4 1 68 0 1 ROP MWD030 FPH 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 RP¡v] MWD030 OHMM 4 1 68 20 6 RPD IVIWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 c, - First Last Name Service Unit Min tvlax Mean Nsam Reading Reading DEPT FT 2636 9840 6238 14409 2636 9840 ROP MWD030 fPH 0 356.97 158.603 14347 2667 9840 GR MWD030 API 42.04 405.'77 111.711 14344 2636 9807.5 EPX JvIWD030 OHMM 0.29 2000 5.19679 14311 2645 9800 RPS MWD030 OHMM 0.1 2000 5.38658 14311 2645 9800 RPM MWD030 OHMM 0.06 2000 5.75417 14311 2645 9800 RPD MWD030 OHMM 0.03 2000 9.28692 14311 2645 9800 fET MWD030 HOUR 0.17 43.58 0.830202 14311 2645 9800 First Reading For Entire File..........2636 Last Reading For Entire File...........9840 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......Ol/ll/09 Maximum Physical Eecord..65535 File Type................LO Next file Name...........STSLIB.003 Physical EOF file Header Service name.............STSLIB.OO3 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......Ol/11/09 Maximum Physical Record..65535 File Type................LO Previous file Name.......STSLIB.002 Comment Record fILE HEADER FILE NUHBER: 3 RATÑ MWD Curves and log header data for each bit run in separate files. ( BIT RUN NUHBER: DEPTH INCRE]\1ENT: cj . SOL) L' J; " :'1 LE SUH]\lP"R '~' VENDOR TOOL CODE GR START DEPTH 9808.0 9820.0 9820.0 9820.0 9E:20.0 9820.0 98<10.5 STOP DEPTH 11806.0 11806.0 11806.0 11806.0 11806. (I 11806.0 118Cí6.0 RPD E'ET RPt--1 RPS RP;,: ROP <, ,,' # LOG HEl\DER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: HAXI},1UIV] ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOT'rOH) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 Ii BOREHOLE AND CASING DAn\ OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHI.,ORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMH) NT TEMPERATURE (DEGF) MUD J\'I' MEASUl<-.ED 'I'EMPERATLJRE (MT): MUD AT MAX CIRCULA.TING TERMPERATLJRE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units...........Feet Data Reference Point.... """" ..Undefined Frame Spacing.....................60 .1IN Max frames per record..... """ ..Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order { 19-0CT-Ol Insite 66.16 Memory 11806.0 86.6 93.8 TOOL NUMBER I?B02079HA4 PBO2079HA4 6.125 9830.0 Flo Pro 9.20 48.0 8.9 31000 3.6 .140 .060 .100 .160 65.0 159.8 65.0 65.0 Units Size Nsam Rep Code Offset Channel t " I( ?- ;:OJ;.: Ì"H"JDO 4 0 l"nli'DO 40 1-!WOO -40 H\~OO4 0 H1^JDO cJ I] 1'-!\-'JDO-40 !'1WDO-40 FT FPH API OHMM OH1'-11'-1 O!-JH!'1 OHH1'-1 HOUR 4 4 4 4 8 .j. RFS K PJ'¡ RPD FET 4 cJ cJ 1 1 1 1 1 1 1 1 68 68 68 68 -'- JE. PT ;:;;OP ::ìR rQ 0,-, 0 4 1 68 68 12 16 :::: CI 24 -4 h G -; 4 6~: '-'0 -- '-' ~. First Last Name Service Unit Min Max Mean Nsam Reading Reading OEPT FT 9808 11806 10807 3997 9808 11806 ROP HWD040 FPH 0 209.49 102.654 3932 9840.5 11806 GR HWO040 API 31.73 86.86 58.1106 3997 9808 11806 RPX MWD040 OHMM 0.19 1078.2 12.1653 3973 9820 11806 RPS MWD040 OHMM 0.23 1079.:28 14.0:~03 3973 9820 11806 RPH M\iiJD040 OHHM 4.46 2000 20.9973 3973 9820 11806 RPD MWD040 OHMM 0.26 2000 18.0466 3973 9820 11806 FET MWD040 HOUR 0.24 72.31 1.51077 3973 9820 11806 First Reading For Entire File. ..,... ...980B Last Reading For Entire File...........11806 File Trailer Service name...,.........STSLIB.O03 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......01/11/09 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.OO4 Physical EOF File Header Service name.............STSLIB.OO4 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......Ol/11/09 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUl'mER: RAiN MWD Curves and log header data for each bit run in separate files. BIT RUN NUM.BE.R: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 11806.5 4 6 .5000 STOP DEPTH 11865.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOH LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIHUH ANGLE: MAXIHUM ANGLE: 22-0CT-Ol Insite 66.16 Memory 11865.0 90.4 91. 9 ( .. TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ~GR DUAL G.~ RAY EWR4 ELECTROMAG. RESIS. 4 r # 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: ~1ATRIX 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 .lIN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O ( TOOL NUMBER PB02079HA4 PP.O:::O7 ?'HA4 6.1:25 Flo Pro 9.2(1 48.0 8.8 31500 3.2 .300 .124 .070 .220 62.0 159.8 62.0 62.0 Name Service Order Un:Lts S:Lze Nsarn Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MTrW060 FPH 4 1 68 4 :2 F.irst I,ast Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11806.5 11865 11835.8 118 11806.5 11865 ROP MWD060 FPH 0.03 97.18 22.6253 118 11806.5 11865 First Reading For Entire File..........11806.5 Last Reading For Entire File...........11865 File Trailer Service name..... ........STSLIB.004 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......O1/11/09 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.005 I?hyst.caJ. EOF ,II I( file Header Service name............. STSLIE. 005 Service Sub Level Name... 'iersion Number.......... .1.0.0 Date of Generation.......Ol/ll/09 Maximum Physical Record..65535 File TY'Pe................LO Previous File Name.... ...STSLI8.004 C'~~,mment Record FILE HEADER FILE NUMBER: RAW HWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS GR RPX RPM FET ¡{PO ROP 5 i~ \ header data for each bit run in separate files. ï .5000 START DEPTH 11806.5 11806.5 11806.5 11806.5 11806.5 11806.,5 IH!65.5 $ Ii LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR FŒAL-TIME): 'I'D DRILLER (F'!'): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 13450.0 13450.0 13450.0 13450.0 13450.0 13450.0 13450.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 .$ BOT'I'OM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND Cl\SING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING OEP'r¡-I (FT'): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (1B/G): MUD VISCOSITY (S): HUD PH: HUD CHLORIDES (PPM): FLUI 0 LOSS (C3): RESIS'l'IVTl'Y (OHlJilVI) AT TEMPEEATUEE (DEGF) MUD AT MEASURED TEMPE,RATUEE (MT): MUD AT MAX CIRCULA'l'ING 'I'ERMPERA'I'URE: MUD FILTRATE AT HT: MUD CAKE AT MT: # NEUTRON TOOL HATRIX: HATRIX DENSITY: HOLE CORRECTION (IN): # TOOL ST.ANDOFF (IN): EWE FREQUENCY (HZ): # REHARIŒ : 25-0CT-01 Insite 66.16 ¡VJemory 13450.0 86.7 91. 8 TOOL NUMBER PB02226HA4 PB02226HA4 6.125 Flo Pro 9.20 50.0 9.5 32000 3.2 .140 .062 .100 .150 65.0 156.2 65.0 65.0 ( I( $ # Data ~ormat Specification Record Data Record Ty-pe..................O Data Speci ficatic'n Sl,:>c}: TY1='e..... I) Logging Direction..... ............Dow~ Optical log depth units...........Feet Data Reference Point.... ..........Undefined Frame Spacing.....................60 .1IN Max frames per record.... .........Undefined .J\bsent value......................-999 Depth Units....................... Datum Specification Slock sub-type...O RPX RPS RPM RPD FET MWD070 MWD070 MWD070 MWD070 MWD070 MWD070 MWD070 Units FT FPH API OHMM OHMM OHMM OHMM HOUR Size Nsam Rep Code .1 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 Offset Channel (I 1 4 Name Service Order DEFT ROP GR 0 u 3 4 5 6 12 16 20 24 7 28 0 u First Last. Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11806.5 13450 12628.3 3288 11806.5 13450 ROP MWD070 ~PH () 212.57 85.5567 3170 11865.5 13450 GR MWD070 API 38.36 12b.O4 ~)7 . 2501 3~~f)8 11806.5 13450 RPX }1WD070 OHHM 2.62 25.66 13.899f3 3288 11806.5 13450 RPS MWD070 OHM'M 3.98 25.94 16.0667 3288 11806.5 13450 RPM MÞ\7DO70 OHMM 4.88 24.27 16.B711 3288 lHW6.5 13450 RPD MÞ'iID070 OHMM 6.31 23.87 16.8918 3288 11806.5 13450 F'ET MWD070 HOUR 0.21 11. 0.64 2. 3rr17 3288 11806.5 13450 First Reading For Entire File..........11806.5 Last. Reading For Entire File...........13450 File Trailc~l:' Service name.............STSLIB,O05 Service Sub Level Name... Version Number. . . . . . . . . . .1. 0.0 Date of Generation... ....01/11/09 Haximum Physical Record..65535 File Type................LO Next. File Name...........STSLIB.O06 Physj.cal EOF ~ile Header Service name........ .....STSLIB.006 Service Sub Level Name... Version Number. . . . . . . . . . .1.0.0 Date of Generation.......Ol/l1/09 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.O05 Comment Record FILE HEADER FILE NU!'1BER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS 6 header data for each bit run in separate files. 8 .5000 START DEPTH 13450.5 STOP DEPTH 13467.5 'I': ( ;. Pl'! 13450.5 13450.5 13450.5 13450.5 13450.5 13450.5 13467.5 1346ì.5 13461.0 13467.5 13928.5 ;;;PX 0" ;'PD ROP rE::T 13468.~ $ " LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (1'-1EHORY OR REAL-TIHE): 'I'D DRILLER (FT): TOP LOG INTERVl\L (17"1'): BOTTOH LOG INTERVAL (17'1'): BIT ROTATING SPEED (RPH): 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 (17"1'): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHfvIM) AT TEMPERATURE (DEGF) MUD ]\T MEASURED 'I'EMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATlŒE: MUD FILTRNEE AT MT: MUD CAKE AT MT: ff NEUTRON TOOL MA'l'RIX: ~1ATRIX DENSI'TY: HOLE CORRECTION (IN): # TOOL STJ-\NDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................(1 Data Spec.i. ficati.on Block Type..... (I 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 j( :::6-0CT-cn Insite 66.16 tc1emor:,l 13929. (, 86.4 88.6 TOOL NUMBER PB02226HM PB02226HA4 6.125 F.la Pro 9.20 50.0 9.3 31000 3.2 .080 .036 .100 .160 66.0 156.2 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO80 FPH 4 .1 68 4 .") L GR MWD080 l\PI 4 .1 68 8 3 RPX MWD080 OHMM 4 .1 68 12 4 RPS HWD080 O!-IHM <1 1 68 16 5 RPM MWD080 OHMM 4 .1 68 20 6 ;'PD Hl'1D080 Ì"!V^] D 0 8 0 r'ET Name Service Unit DEPT FT R.OP !v!\,'i'DCI80 FPH GR MWD080 API RPX MWD080 OHMM RPS MWD080 OHMM RPM MWD080 OHMM RPD MWD080 OHMM FET MWD03Ci HOur" { OHt'l!'1 HOUR Min 13450.5 O. (13 43.01 3.49 5.58 8.71 13.39 5.5(; ( :1 4 1 1 68 24 7 68 '")0 "'-'-' ù '-, Fi.rst Las~ 1'1 a x l'1ean Nsam Readinq ReadinJ 13928.5 13689.5 957 13450.5 13 ~<: 8 . :', 145.6 84.~)78S 957 1345(\.5 1392f:.:- 51.22 48.7723 22 13450.5 13461 9.32 5.46486 35 13450.5 13467.5 9.76 6_64971 35 13450.5 13467.5 11.91 10.0571 35 13450.5 13467.5 16. en 14.5889 35 13450.5 13467 .5 30-53 11.3151 37 13450.5 13468.~i First Reading For Entire File___.--____13450_5 Last Readinq For Entire File...........13928.5 File Trailer Service name........ .....ST8LIB.006 Service 8ub Level Name... Version Number......... ..1.0.0 Date of Generation.......Ol/ll/O9 Maximum Physical Record..65535 File Type................LO Next File Name....... ... .8T8LI8.007 Physical EOF rUe Header Service name........ .....8T8LI8.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......Ol/11/09 Maximum Physical Record. .65535 File Type................LO Previous File Name... ....8T8LI8.006 Comment Reco.rd FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE 8UMMARY VENDOR TOOL CODE GR RPX RPM RPD RPS 7 header data for each bit run in separate files. 9 .5000 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE', SOfTWARE VERSION: DOWNHOLE 80FTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVl-\L (FT): BIT ROTATING 8PEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: FET ROP $ ~)TART DE PTH 13461.5 13468.0 13468.0 13468.0 13468.0 13469.0 .l39~29.0 STOP DEPTH 14118.0 14125.0 14125.0 14125.0 14125.0 14125.0 14161.0 28-0CT-01 Insite 66.16 Memory 14161.0 86.4 87.4 ( TOOL STRING (TOP TO BOTTOM) 'iENDOR TOOL CODE TOOL TYPE =GR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 11 BOREHOLE AND C.".3ING O./\Tf\ OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): ¡VIUD PH: MUD CHLORIDES (PPM): E'LUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: ~. " # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction... ... ... ........Down Optical log depth units..... ......Feet Data Reference Point...... ...... ..Undefined Frame Spacing..... """'" ..... ..60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O ~, TOOL NUMBER PE022 5 4 H.I\GR4 PBO2254 HN~R4 6.125 Fla Pro 9.20 49.0 8.6 34000 3.4 .050 68.0 159.8 68.0 68.0 .022 .100 .120 Name Servic~: Order' Units Size Nsarn Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MV\ìD090 FP]-] 4 1 68 4 2 GR MWD090 A.PI 4 1 68 8 3 RPX MWD090 O¡'IM¡V¡ 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 0 HMJvI 4 1 68 24 7 FET MWD090 HOUE 4 1 68 28 8 F.irst Last Name Service Unit Min Max ~1ean Nsam Reading Reading DEPT FT 13461.5 14161 l3all.3 1400 13461. 5 14161 EOP MWDO90 E'PH 0 130.08 56.2414 465 13929 14161 GR MWD090 API 30.89 .122 54.2411 1314 .13461.5 14118 RPX MWDO90 OHMM 3.14 30.a8 11.4609 1315 13468 14125 RP3 Jv¡WD090 OHMM 3. c15 32.07 15.7863 1315 13468 14125 RPM MWDO90 OHMM 4.41 37.33 20.2232 1315 13468 141 ;?!:) RPD MWD090 OHMM 4.48 50.55 21. 7143 1315 13468 14125 FET MWDO90 HOUR 0.35 37.67 22.5385 1313 13469 14125 First Reading For Entire File..........13461.5 Last Reading For Entire File...........14161 ( ?ile Trailer Service name.............STSLIB.OO7 Service Sub Level Name... "/ersion Number...........l.0.0 Date of Generation..... ..01/11/09 Maximum Physical Record..65535 File T::lpe................LO Next File Name...........STSLIB.OOS Physical EOF Tape Trailer Service name............. LISTPE Date.....................01/11/09 Oriqin...................STS Tape Name....... .... .....UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Reel Trailer Service name....... ......LISTPE Date.....................Ol/ll/O9 Origin...................8TS Reel Name................UNKNOWN Continuation Number...... 01 Next Reel Name...........UNKNOWN Comments.................8T8 LIS Wri.ting Library. Physical EOI' E'hysical EOr End Of LIS File { Scientific Technical Services Scientific Technical Services