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Home My WebLink About202-148CAUTION: 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 CD2-29 (PTD# 202-148) AOGCC Notification Date:Monday, June 2, 2025 2:33:53 PM Attachments:image001.png AnnComm Surveillance TIO for CD2-29.pdf From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Monday, June 2, 2025 11:34 AM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD2-29 (PTD# 202-148) AOGCC Notification Well Name: CD2-29 Facility: WNS PTD: 202-148 Well Type: Injector AA Number (if applicable): Internal Waiver (Yes/No if applicable): No Type of Issue: Plan forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): 5/29/25 Chris, CRU CD2-29 (PTD# 202-148) was placed on a 30-day monitoring period to watch to watch IA pressures while on gas injection. During the 30 days, the IA has not exhibited problematic behavior and has been stable on injection. Attached is the 90-day TIO plot and wellbore schematic. The plan is to stop the 30- day monitor and continue gas injection. Please let me know if you have any questions or disagree with the plan forward. Thanks, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD2-29 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD2-29 2025-05-10 1000 750 -250 OA CD2-29 2025-05-15 1000 600 -400 OA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD2-29 haggea Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, Drift, SBHP, Re-set A1 CD2-29 6/21/2024 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.09/1/2010 haggea Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR1614.69 36.0 114.0 114.0 109.00 H-40 WELDED SURFACE 9 5/8 8.92 36.5 2,672.1 2,354.8 36.00 J-55 BTC PRODUCTION 7 6.28 34.7 9,556.3 7,134.1 26.00 L-80 BTCM OPEN HOLE 6 1/8 6.13 9,556.3 12,560.0 7,127.4 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.7 Set Depth… 9,026.3 Set Depth… 7,030.1 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.7 32.7 0.02HANGER 10.800 FMC TUBING HANGER 4.500 2,240.4 2,029.0 40.41 NIPPLE 5.620 CAMCO DB NIPPLE CAMCO DB 3.812 8,796.5 6,914.0 53.36 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 8,906.4 6,975.3 59.26 PACKER 5.970 BAKER S-3 PACKER w/Millout extension BAKER S-33.875 9,014.1 7,025.1 65.28 NIPPLE 5.000 HES XN NIPPLE HES XN 3.725 9,025.1 7,029.6 65.81 WLEG 5.000 BAKER WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,240.4 2,029.0 40.41 INJ VALVE 4.5" A1 Injection Valve on 3.812" DB Lock Camco A1 HYS- 444 6/21/2024 1.250 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 8,796.5 6,914.0 53.36 1 GAS LIFT DMY BK 1 0.0 2/26/2024 WI pkg 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,556.3 7,134.1 87.24 OPEN HOLE 6.125 6.125 CD2-29, 6/22/2024 5:25:53 AM Vertical schematic (actual) OPEN HOLE; 9,556.3-12,560.0 PRODUCTION; 34.7-9,556.3 FLOAT SHOE; 9,554.9-9,556.3 FLOAT COLLAR; 9,470.0- 9,471.4 WLEG; 9,025.1 NIPPLE; 9,014.1 PACKER; 8,906.4 GAS LIFT; 8,796.5 SURFACE; 36.5-2,672.1 FLOAT SHOE; 2,670.4-2,672.1 FLOAT COLLAR; 2,584.4- 2,586.0 INJ VALVE; 2,240.4 NIPPLE; 2,240.4 CONDUCTOR; 36.0-114.0 HANGER; 36.5-38.8 HANGER; 34.7-37.1 HANGER; 32.7 WNS INJ KB-Grd (ft) 36.65 RR Date 10/7/2002 Other Elev… CD2-29 ... TD Act Btm (ftKB) 12,580.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032042700 Wellbore Status INJ Max Angle & MD Incl (°) 94.31 MD (ftKB) 12,487.70 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from wnsintegrity@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD2-29 (PTD# 202-148) Date:Wednesday, March 27, 2024 3:52:57 PM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Wednesday, March 27, 2024 12:05 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD2-29 (PTD# 202-148) Chris, The 30-day monitor on water will end on 3/29/2024. The well is stable. The next step is to wag the well to gas for a 30-day monitor. I will follow up with proper notifications after the 30-day monitor. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: WNS Integrity Sent: Thursday, February 15, 2024 10:23 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD2-29 (PTD# 202-148) Chris, The results from initial diagnostics are suspect. The plan for this well is to wag the well to water for a 30-day monitor. I will follow up with proper notifications after the 30-day monitor. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: WNS Integrity Sent: Monday, January 29, 2024 11:18 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD2-29 (PTD# 202-148) Chris, CRU CD2-29 (PTD# 202-148) has suspect IA. Initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from wnsintegrity@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD2-29 (PTD# 202-148) Date:Thursday, February 15, 2024 10:43:27 AM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, February 15, 2024 10:23 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD2-29 (PTD# 202-148) Chris, The results from initial diagnostics are suspect. The plan for this well is to wag the well to water for a 30-day monitor. I will follow up with proper notifications after the 30-day monitor. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: WNS Integrity Sent: Monday, January 29, 2024 11:18 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD2-29 (PTD# 202-148) Chris, CRU CD2-29 (PTD# 202-148) has suspect IA. Initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from wnsintegrity@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD2-29 (PTD# 202-148) Date:Monday, January 29, 2024 12:28:32 PM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Monday, January 29, 2024 11:18 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD2-29 (PTD# 202-148) Chris, CRU CD2-29 (PTD# 202-148) has suspect IA. Initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, September 1, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Lou Laubenstein P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-29 COLVILLE RIV UNIT CD2-29 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2022 CD2-29 50-103-20427-00-00 202-148-0 G SPT 6974 2021480 1744 3918 3918 3918 3918 745 832 831 833 4YRTST P Lou Laubenstein 7/17/2022 4-year test 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD2-29 Inspection Date: Tubing OA Packer Depth 1350 2110 2060 2050IA 45 Min 60 Min Rel Insp Num: Insp Num:mitLOL220718144404 BBL Pumped:0.8 BBL Returned:0.8 Thursday, September 1, 2022 Page 1 of 1 9 9 99 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.09.01 14:03:23 -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: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC 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 MMec h an i c all In t eg r ityy Tes t 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 9 9 9 9 9 9 9 - 5HJJ CD2-29 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 11,2018 TO: Jim Regg P.I.Supervisor /131 j SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD2-29 FROM: Brian Bixby COLVILLE RIV UNIT CD2-29 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD2-29 API Well Number 50-103-20427-00-00 Inspector Name: Brian Bixby Permit Number: 202-148-0 Inspection Date: 6/5/2018 Insp Num: mitBDB180610165921 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD2-29 'Type Inj W 'TVD 6974 Tubing 1940 ' 1940 1940 ' 1940 - PTD I 2021480 Type Test SPT Test psi 1744 ' IA 780 2800 - 2720 2710 1 P/F BBL Pumped: 1.9� 2 BBL Returned: i OA � 550 - 780 . 780 780 Interval 4YRTST P Notes: SCANNED J Monday,June 11,2018 Page 1 of 1 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q 0:1.. - 1 Y- ~ Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~escan Needed 1111111111111111111 R~CAN '\Ø'color Items: 0 Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Diskettes, No. D Other, NolType: D Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: BY: Helen ~ 0 Other:: Date J 1'1 D f Isl m,.:) , , 1111111111111111111 Date II Of t;'f IS/Mt , . BY: Helen ~ Project Proofing Scanning Preparation ~~ x 30 = 10 + ~ () = TOTA:- PAGES I J 0 - (Count doe~ not ncl,uge cover sI1e¡~..J.J Date: il 1 °1 Isl rrf, I 1111111111111111111 BY: Helen Maria Production Scanning Stage 1 Page Count from Scanned File: J J I (Count does include cover sheet) Stage 1 If NO in stage 1, page(s) discrepancies were found: VYES Date IlIO/Dtj- YES NO NO BY: Page Count Matches Number in Scanning Preparation: Helen~ Is! Wlf BY: Helen Maria Date: Isl 1II11IIII1111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Helen Maria Date: Is/ Comments about this file: Quality Checked 1II1I11111111111111 8/24/2004 Well History File Cover Page.doc MEMORANDUM To: Jim Regg P.I. Supervisor ~~ ~ ~ 1Z~) ~,~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 28, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-29 COLVILLE RIV UNIT CD2-29 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~' --- Comm Well Name: COLVILLE RIV UNIT CD2-29 API Well Number: 50-103-20427-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ100615084806 Permit Number: 202-148-0 Inspection Date: 6/11/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ cDZ-z9 ~ Type Inj. w TVD ~ 6974 IA 700 2550 ~i 2500 2490 P.T.Di 2021480 TypeTest SPT i TCSt pSl 1743 ' OA 560 800 820 820 __ Interval 4YRTST P~F P ~ TUbing 1800 1800 1800 1780 i Notes: 1.8 BBLS diesel pumped; no exceptions noted. '~~ , ~ ~,~~ ~ 111.. ... 1-1 ~ U f Monday, June 28, 2010 Page 1 of 1 . . ConocJf)hillips Alaska V¡ÙP jb,; P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 !~~" ~W i ~ ~etll: 5eMWlRJ8R i~'iJcliill'z¡œ ¡~TIi;rmT~gt: March 24, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 $~E[) 2 B Z007 atJ~- ~ ~ 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 respectively was coated with a corrosion inhibiter, RG2401 engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on March 21st, 2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor sealant was pumped in a similar manner March 21 st_ 22ß , 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, \]7¢ ~ Arend- ConocoPhillips Well Integrity Field Supervisor ~ Attadunent . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name pro # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name PTO # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation CommissIon TO: Jim Regg P.I. Supervisor -----, Ut.'0' , ! :' ì~ "í f (~ I .> " ·1 &'''. ' -~) I < "', DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-29 COLVILLE RlV UNIT CD2-29 ~o().- J4tij' FROM: Chuck Scheve Petroleum Inspector 8rc: Inspector Reviewed By: P.I. Suprv ,:f!3?-. Comm NON-CONFIDENTIAL Well Name: COLVILLE RIV UNIT CD2-29 API Well Number 50-103-20427-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060828 1423 16 Permit Number: 202-148-0 Inspection Date: 8/26/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD2-29 Type Inj. w TVD 6974 IA 1000 2120 2110 2110 P.T. 2021480 TypeTest SPT Test psi 1743.5 OA 720 900 900 900 Interval 4YRTST P/F P .-/ Tubing 2000 2000 2000 2000 Notes Pretest pressure observed and found stable SCANNED SEP 082006 Wednesday, August 30,2006 Page I of 1 . . ...···r······.·······-·····..·· ,,. .. ", '," ,.' 0 ".J-" ; .:'. MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 7 ¡1J d 11 )~~ ~'f DATA SUBMITTAL COMPLIANCE REPORT 10/29/2004 Permit to Drill 2021480 Well Name/No. COLVILLE RIV UNIT CD2-29 Operator CONOCOPHILLlPS ALASKA INC S(J~ ~f{~~2- API No. 50-103-20427-00-00 MD 12560 -' TVD 7127;, Completion Date 10/7/2002 ~ REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name GR/Res ED D Directional surveY ED D Directional Survey pr£ Directional Survey ..-f(pt Directional Survey ¿D ~ement Evaluation ~U... t) ttS ;t C)-~ '),.. C(1691 LIS Verification ~ ....cfs Verification dD D ~691 LIS Verification Rt>t' ~ Verification ~ C Pdf ~605 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Completion Status WAGIN ~Y J--- Current Status WAGIN Samples No Directional Surv~ Yev (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No Interval OH / Start Stop CH ~ Received Comments A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 7/15/2002. 341 12560 Open 1 0/15/2002 0 341 Open 10/15/2002 GYRO 341 12560 Open 1 0/15/2002 0 341 Open 1 0/15/2002 GYRO 5 Col 0 9170 Case 11/29/2002 2626 12508 Open 4/17/2003 REPLACED BY NEW DATA RCVD 7/24/2003 2626 12508 Open 4/17/2003 REPLACED BY NEW DATA RCVD 7/24/2003 3 2635 12501 Open 7/24/2003 REPLACES DATA RCVD ~ ON 04/17/2003 3 2635 12501 Open 7/24/2003 REPLACES DATA RCVD ON 4/17/2003 114 12560 Open 4/23/2004 ROP,DGR,EWR,GRAPHIC S,MWD Sample Set Sent Received Number Comments Permit to Drill 2021480 MD 12560 TVD 7127 ADDITIONAL INFORMATION Well Cored? Y I(j[) Chips Received? - Y / N . Analysis Received? .Y/N Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/29/2004 Well Name/No. COLVILLE RIV UNIT CD2.29 Operator CONOCOPHILLIPS ALASKA INC Completion Date 1017/2002 Completion Status WAGIN Daily History Received? Formation Tops ~ API No. 50-103-20427-00-00 Current Status WAGIN (YyN (1)N Date: UIC Y ó N,v J..b-'D VI ",-," STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation D or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG0 GINJ D WINJ D WDSPl D Sa. Sundry number: 5b. Sundry approval date: ~, 303-249 (h)(3) Other Commission approved substances (include descriptions in block 12) 8/25/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 380* 380 0 0 0 0 100 0 28656 39 0 0 0 0 0 0 0 0 100 380 29036 39 Pressure vs. Time D Step Rate Test D 2003 I 3rd 0 2003 / 4th 28556 2004 I 1st 0 2004 / 2nd .~ 0 I otal Ending Volume (bbls): 28556 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoinq is true and correct to the best of my knowledge. Signature: ' \ ~ \. 'v::.:>c - . Printed Name: Randy Thomas Title: Date: Kuparuk Drilling Team leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 202-148 C02-29 8. API Number: 50-103-20427 -00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 10/8/2003 11/17/2003 C02-06, C02-30, C02-27, C02- 55 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. to (ter. (0'-( Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h}(1) drilling mud, drilling (h}(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 I 3rd 0 2003 14th 28556 2004/1st 0 2004 I 2nd 0 Total Ending Volume 28556 (bbls): 0 100 0 0 100 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG0 GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 303-249 (h)(3) Other Commission approved substances (include descriptions in block 12) 8/25/2003 Volume (bbls): Number of days disposal occurred 380* 380 0 0 0 28656 0 0 0 0 39 380 29036 39 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ~ - - Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 Step Rate Test D Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 202-148 CD2-29 8. API Number: 50-1 03-20427 -00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: "-' 0 10/8/2003 11/17/2003 CD2-06, CD2-30, CD2-27, CD2- 55 0 0 ::¡',~i Report ;s due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7(ð (07' Phone Number: (907) 265-6830 Submit in Duplicate ) ) tL~. ?-o ~ ., t cf3' WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cotnm. Attn.: Howard Okland 333 West 7t11 Avenue, Suite 100 Anchorage, Alaska 99501-3539 April 20, 2004 RE: MWD Fonnation Evaluation Logs: CD2-29, AK-MW-22162 CD2-29: Digital Log Images: 50-103-20427-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF TIiE TRANS:MITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: lJ)V þf STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 I 3rd 0 0 28556 100 0 0 2003 14th 2004/1st 2004 I 2nd Total Ending Volume (bbls): 28556 100 Form 10-423 Rev. 9/2003 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG0 GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: 303-249 (h)(3) Other Commission approved substances (include descriptions in block 12) 8/25/2003 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 202-148 CD2-29 8. API Number: 50-1 03-20427-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: '~ 380* 380 0 0 0 0 28656 39 1 0/8/2003 11/17/2003 CD2-06, CD2-30, CD2-27, CD2- 55 0 0 0 380 29036 39 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the forego~e and co~rect to th~ bes~ of my knowledge. Signature: ~ ~ \ ~- - Printed Name: ~ "'-,.<\ ì ~'" - - t Title: Step Rate Test D Date: ~ f"". b 1~-.. Le--...Jl INSTRUCTIONS ON REVERSE SIDE ~. Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the. fourth quarter. y ( (6 (0 ~ Phone Number: ¿'- S(; ~ .; () Submit in Duolicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation of Disposal 0 10. . (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 14th YYYY /0# YYYY /0# YYYY 10# Total Ending Volume (bbls): 28556 100 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry numþer: 5b. Sundry approval date: 303~249 (h)(3) Other Commission approved substances (include descriptions in block 12) 8/25/2003 Volume (bbls): Number of days disposal occurred 28556 100 380* 380 0 28656 380 29036 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the f~g is true and correct to the best of my knowledge. Signature: . \ ~~ ~ -- Printed Name: ~ --J. ~ ~ ""-""'} Title: Form 1 0-423 Rev. 9/2003 Step Rate Test 0 Date: ~ (' ~ -c-e~-- Le~~ INSTRUCTIONS ON REVERSE SIDE 39 39 6. Permit to Drill Number: 7. Well Name: 202-148 CD2~29 8. API Number: 50-103-20427 -00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: '~" 10/8/2003 11/17/2003 CD2~06, CD2~30, CD2-27, CD2~ 55 4 ~ Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \ ( ?'-'(o 0/ Phone Number: <.GS"' - "'8 3-0 Submit in Duplicate Note to File CD2-29 (202-148.. .303-249) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface holes of the well. --Surface casing was cemented to surface. Approximately 82 bbls of cement was circulated to surface. The net cement remaining in the surface hole was still 62% XS of the calculated hole volume. --On the initial leak off test, it was not possible to pump into the well at 16 ppg EMW. --The casing test and leak off pressure plot of CD2-29 overlay each other and demonstrate linear response to pumping. During the 10 minute observation period, the applied leak off pressure declined from 800 psi to 700 psi. --CPA experienced some lost circulation while running the 7" casing. The losses were remed ied to some extent and the casing was cemented with what is stated as 80% retu rns. --A subsequent injectivity test was done down the 9-5/8" x 7" annulus. The pressure increases smoothly to 700 psi where it breaks. Approximately 4 bbls of mud were injected at with the pressure near 700 psi. On shut down, the pressure decreased to 600 psi in 2 minutes and further decreased to 550 psi at 9 minutes. --CPA provided a listing of all surface casing shoes within ~ mile of CD2-29. The records of wells within 900' radius were examined and no problems were identified that would preclude granting CPA's request for CD2-29. Based on examination of the submitted information, I recommend approval of ¡::h;;=:;;e subject well. Tom Maunder, PE Sr. Petroleum Engineer ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ') ) Conoc~illips August 21, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drillin2 Waste on well CD2-29 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2-29 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD2-29 approximately September 15,2003. Please find attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. Further details regarding wells on CD2 pad within 1,4 mile radius should be on file at the AOGCC. If you have any questions or require further information, please contact Vem Johnson at 265-6081, or Chip Alvord at 265-6120. S~~~I.Y'7. ~'v /" ~ L.,. " Vem Johnson Drilling Engineer Z 7- { c 2>( oj cc: CD2-29 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake A TO-868 Anadarko ATO-1530 ) 1. Type of Request: STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPL.ICATION FOR SUNDRY APPROV A~ 20 AAC 25.280 Operational shutdown 0 0 0 Suspend 0 Repair well 0 Pull Tubing 0 Abandon Perforate 0 Stimulate 0 0 Alter casing 0 Change approved program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Plug Perforations Perforate New Pool 4. Current Well Class: Development 0 Exploratory 0 Stratigraphic 0 Service 0 P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 36' / 52.7' MSL 8. Property Designation: ADL 380075 ~ %. ~~ o....~ ;~f~ t Annular D spos. ~ DC~ . Time Extension 0 Variance Other 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 202-148 6. API Number: 50-1 03-20427 -00 9. Well Name and Number: CD2-29 10. Field/Pools(s): Colville River Field / Alpine River Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 7127' MD Perforation Depth TVD (ft): 71341 - 7121' Packers and SSSV MD (ft): Land Nipple @ 2240', packer @ 8906' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 12560' 7127' 12560' Casing Length Size Structural Conductor 71' 16/1 Surface 26361 9.625/1 Intermediate Production 95201 7/1 Liner TVD 1141 1141 2672' 23551 9556' 71341 Perforation Depth MD (ft): open hole completion from 9556' - 12560' Packers and SSSV Type: Baker S-3 pkr, Camco DB Land Nipple 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tubing Size: 4.5/1 9/15/2003 Date: Contact Printed Name G. Alvord ß(M Title Alpine Drilling Team Leader 265-6120 Signature Phone COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 Mechanical Integrity Test 0 Location Clearance 0 BOP Test 0 Other: Subsequent Form Required: i<t. \ð~.ç o.~Ù \o.-,~ s. r s.CJ... \ ~ fJ () ~ BY ORDER OF Approved by: c7 ")~~ COMMISSIONER THE COMMISSION RBDMSBFl AlJ62R 2003 ORIGINAL Form 10-403 Revised 2/2003 Burst Collapse Tubing Grade: l-80 Tubing MD (ft): 9026' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Vern Johnson @ 265-6081 Date 8 (LZ.(o,$ Sundry Number: 1/~. :d'lq Date: ~Z51r/3. SUBMIT IN DUPLICATE ') Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-29 b. The depth to the base of freshwater aquifers and There are no USDW aquifers in the Colville River permafrost, if present. Unit. Base of Permafrost = 1552' TVD (RKB) c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) d. A list of all publicly recorded wells within one- See attached map indicating wells within 1/4 mile. quarter mile and all publicly recorded water There are no water wells within 1 mile. wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of Types of fluids can be mud, diesel, cement, and waste to be disposed of and the estimated density water. Maximum volume to be pumped is 35,000 of the waste slurry. bbls. f. An estimate of maximum anticipated pressure at Maximum anticipated pressure at casing shoe the outer casing shoe during annular disposal during disposal operations is 1904 psi. See operation and calculations showing how this attached calculation page. value was determined. g. Details that show the shoe of the outer casing is See attached cementing reports, LOT /FIT reports, set below the base of any freshwater aquifer and and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing See attached casing summary sheet and calculation strings have sufficient strength in collapse and page. burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission NA to confirm containment of drilling wastes. ) CD2-29 Pressure Calculations for Annular Disposal DETAILS: ~ ê6 ~ "C Q) a:s "C Q) a:s .r:. Q) .r:. 'ëi) 'ëi) Co Co o 0 C) 0 0 0 c:::: C\I 0 'ëi) C\I a:s + + 0 E E ~ 'ëi) 'ëi) LO Co Co I ,... ,... ~ ci ci ~ en ~ a:s C) C) Ç=9-5/8" 36 lb/ft, J-55 BTC casing @ 2672 ft MD (2355 ft TVD) Pburst = 3520 psi, @ 85%: Pburst85% = 2992 psi ,."",.,. .", ",. ..., "tö'ë Z Z Estimated Top of Cement @ 8578 ft MD (6771 ft TVD) (7" csg x 8-1/2" Open hole annulus) C) c:::: :ë ;j I- ~ C) ,... c:::: , 'ëi) .q- a:s 0 <=4-1/2" 12.6 lb/ft L-80 tubing to 9026 ft MD f.. L ~ Ç=7" 26Ib/ft, L-80, BTC casing @ 9556 ft MD (7135 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 - PPormation Pmax = 12.0 (0.052) (2355)+1500 - 0.4525 (2355) Pmax = 1904 psi Maximum fluid density to burst 9-5/8" casing: Pburst85% = PHydrostatic + P Applied - PPormation 2992 = MW max (0.052) (2355) + 1500 - 0.4525 (2355) MW max = 20.9 ppg Maximum Fluid Density to Collapse 7" Casing: Pcollapse85% = PHydrostatic + P Applied - PGasGradient - PHeader 4598 = MWmax (0.052) (6771) + 1500 - (0.1) (6771) - 2000 MW max = 16.4 ppg ) ) Casing Detail 9 518" Surface Casing fI~~lb~!~H~LI~~~~~d~~ Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 62 Doyon 19 RKB to LOS FMC Gen V Hanger 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe 60 Jts Jts 1 to 2 2 Jts 9- 5/8" shoe @ TO 12 1/4" Surface Hole RUN TOTAL 36 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, and 60. 68 joints total in shed - 62 joints total to run Last 6 joints stay out, # 63 thru # 68. Use API Mod Best 0 Life Artic Grade Csg Compound. Remarks: Up Wt - 152K Ibs On Wt - 140K Ibs Block Wt 75K Ibs Supervisor: David Burley Well: CD2-29 Date: 9/26/2002 LENGTH 36.50 2.30 2545.60 1.60 84.40 1.72 DEPTH TOPS 36.50 38.80 2584.40 2586.00 2670.40 2672.12 2682.00 ) ') ConocoPhillips Alaska Cementing Report Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Hole Size: TM D Set: Date Set: Csg Type: Csg Size: Primary 12.250 (in) 2,672(ft) 9/26/2002 Surface Casing 9.625 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Report #: Start: Spud Date: 9/24/2002 1 Report Date: 9/27/2002 9/24/2002 End: 10/7/2002 Cement Job Type: Primary Squeeze Open Hple Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Squeeze Célsing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Cementer: Jim Thompson Pipe Movement Pipe Movement: Reciprocating Rot Time Start:: Time End:: RPM: Rec Time Start: 08:00 Time End: 11 :30 SPM: 1 Type: Cement Casing Volume Excess %: 150.00 Meas. From: 82 Time Ckc Prior To Cementing: 1.75 Mud Circ Rate: 336 (gpm) Mud Circ Press: 360 (psi) Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 152 (Ibs) Stage No: 1 of 1 Start Mix Cmt: 10:17 Start Slurry Displ: 10:18 Start Displ: 11 :08 End Pumping: 11 :40 End Pump Date: 9/26/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 8.00 (bbl/min) 9.00 (bbl/min) Y 600 (psi) 1 000 (psi) 2 (min) Y Max Torque: (ft-Ibf) Drag Down: 140 (Ibs) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 82.00 (bbl) Ann Flow After: N Mixing Method: recirculat Density Meas By: densometer Type: Spud Mud Density: 9.6 (ppg) Visc: 60 (s/qt) Bottom Hole Circulating Temperature: 70 (OF) Displacement Fluid Type: Mud PVIYP: 10 (cp)/17 (lb/100ft2) Gels 10 sec: 14 (lb/100ft2) Gels 10 min: 16 (lb/100ft2) Bottom Hole Static Temperature: 54 (OF) Density: 9.6 (ppg) Volume: 200.20 (bbl) Slurry Data Fluid Type: Mud Push Slurry Interval: (ft) Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Mud Däta Stage No: 1 Slurry No: 1 of 3 To: (ft) Description: 10.5 ppg mud push Class: Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: CF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 3/412003 4:46:39 PM ') ) C.onoco.8hiUipsAlaska CemeintingReport Page 2 of 3 Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Report #: Start: Spud Date: 9/24/2002 1 Report Date: 9/27/2002 9/24/2002 End: 10/7/2002 Slurry Data Fluid Type: LEAD Description: ASLite Class: G Slurry Interval: 36.40 (ft) To: 2,172.00 (ft) Cmt Vol: 275.0 (bbl) Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Water Source: lake Slurry Vol:348 (sk) Water Vol: 166.8 (bbl) Other Vol: 0 Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: 30.0 (cc) Fluid loss Pressure: 65 (OF) Temperature: 65 (OF) Temperature: 65 (OF) Temperature: 65 (OF) Purpose: ZONAL ISOLA Mix Water: 20.13 (gal) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure 50 (psi) 250 (psi) Concentration Trade Name Type Stage No: 1 Slurry No: 20f 3 -Additivøs Units Liquid Cone. CIG D-124 D-53 S1 D-46 D-79 D-44 FllLlTE GYPSUM ACCELERATOR DEFOAMER EXTENDER ACCELERATOR 50.00 %BWOC 30.00 %BWOC 1.50 %BWOC 0.60 %BWOC 1.50 %BWOC % 9.00 Stage No: 1 Slurry No: 30f3 Slurry Data Fluid Type: TAil Description: CI G Slurry Interval: 2,672.00 (ft)To: 2,172.00 (ft) Cmt Vol: 45.0 (bbl) Water Source: lake Slurry Vol:231 (sk) Test Data Thickening Time: 2.50 Free Water: (%) Fluid loss: (cc) Fluid loss Pressure: Temperature: 65 CF) Temperature: (OF) Temperature: (OF) (OF) Class: G Density: 15.80 (ppg) Yield: 1.17 (frIsk) Water Vol: 30.4 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Trade Name Stage No: 1 Slurry No: 3 of. 3 - Additives Units D-46 D-65 S1 Type DEFOAMER DISPERSANT ACCELERATOR Concentration Units Liquid Cone. 0.20 %BWOC 0.30 %BWOC 2.00 %BWOC Printed: 3/412003 4:46:39 PM ') Page 3 of3 Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Report #: Start: Spud Date: 9/24/2002 1 Report Date: 9/27/2002 9/24/2002 End: 10/7/2002 Casing Test Shoe Test Liner Top Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 16.00 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N Printed: 3/412003 4:46:39 PM :) WELL NAME SUPERVISOR David Burley CURRENT STATUS Drilling 8 1/2" hole from 2740'. 24 HR FORECAST LITHOLOGY ITEM DESCRIPTION NOJTS 1 1 1 1 1 1 1 3 3 1 8 1 Bit Mud Motor Drill Collar - Pony Stabilizer - Non Mag MWD MWD Sub - Float Drill Collar - Non Mag Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt Crossover ") LENGTH 1.00 25.15 15.43 3.12 27.65 20.36 2.42 91.60 90.47 32.74 240.23 1.42 O.D. 8.500 7.050 6.650 6.500 6.750 6.640 6.750 6.650 6.250 5.000 6.500 BIT I RUN 1 I 21 BITS SIZE MANUF. TYPE SERIAL NO. JETS OR TFA 12.250 HUGHES-CHR MX-C1 6005642 16/16/18/10// 8.500 HUGHES-CHR HCM605 7101195 14/14/14/14/14/ CønQc.QPhillips ..Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS CD2-29 ODR 2,682.0 2,363.0 2.48 I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Doyon 19 Alpine 12,545.0 0 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD 0 DATE OF LAST SAFETY MEETING DAILY TOTAL Drill 8 1/2" hole. 9/25/2002 313,001 I JAR HRS OF SERVICE \ BHA HRS SINCE INSP I LEAKOFF AFE WCD.W3A.0009.01 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 9/25/2002 2,624.14 41.300 68.020 9.625 (in) @ 2,672.0 (ft) 7.000 (in) @ 9,545.0 (ft) QI;:NSI.T'((Ppg) I 9.40 PP I EÇDI9.40 IMUDDÄTAI DAIL.Yc:PST I 0 FV PV/YP GELS WLlHTHP FCIT.SOL OILIWAT %Sand/MBTPh/pPJI Pf/Mf 34 714 1/1 10.81 1/0 I 0.1110.0 8.21 /1 ~HA NO~ I 2 I BHA I HOLE CONDITIONS BHAWT.BELOWJARS STRINGWT. UP STRINGWT.DN STRINGWT.ROT BIT I RUN 1 I GPM BIT OPERATIONS PRESS P BIT HRS 24Hr DIST 24Hr ROP . CUM HRS 2,568.0 2,568.0 WOB I RPM / I REPT NO. IDA TE 3 9/26/2002 I CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 597,953 AUTH. 3,314,075 LAST BOP PRES TEST 9/26/2002 1,400 40 TORQUE I UNITS I BIT NO. 2 BHALENGTH 551.59 CONN SIZE CONN TYPE I.D. 2.250 4.250 2.813 2.750 1.920 1.920 2.813 2.875 2.250 3.000 2.500 DEPTH IN DATE IN I-O-D-L-B~G-O-R 114.0 9/24/20020-0------ 2,682.0 9/26/20020-0-EC-A-D-I-NO-TD OPERATIONS SUMMARY PHASE SURFAC LD bha and clean rig floor. SURFAC Rig up to run 95/8" casing, monitor well on trip tank. SURFAC Held safety and opts meeting with rig crew. SURFAC Ran 62 joints of 95/8",36#, J-55 BTM casing, MU hanger and landing joint, land casing with shoe @ 2672', FC @ 2584'. SURFAC LD fill-up tool and MU cement head. SURFAC Staged pumps up to 8 bpm, circ and cond mud. Lower yield point from 54 to 17, reciprocated pipe 25' strokes, added nutplug for marker to last 50 bbls pumped, full returns throughout. Final circ pressure 360 psi, PUW 152k SOW 140k. PJSM. FROM TO HOURS CODE TROUBLE SUB 00:00 01:30 1.50 DRILL P PULD 01:30 02:30 1.00 CASE P RURD 02:30 03:00 0.50 CASE P SFTY 03:00 07:30 4.50 CASE P RUNC 07:30 08:00 0.50 CEMENT P PULD 08:00 09:45 1.75 CEMENT P CIRC DESCRIPTION Printed: 3/4/2003 4:52:38 PM ConocoPhillips Inc. Daily Drilling Report I JOB NUMBER I EVE~T;~DE 124 HRS PROG I T~~682.0 ) WELL NAME CD2-29 HOURS CODE TROUBLE SUB 09:45 11:15 1.50 CEMENT P PUMP 11:15 12:00 0.75 CEMENT P DISP 12:00 12:30 0.50 CEMENT P PULD 12:30 13:00 0.50 CASE P RURD 13:00 14:00 1.00 DRILL P PULD 14:00 16:00 2.00 WELCTL "IEQIP NUND 16:00 18:00 2.00 WELCTL P NUND 18:00 21 :00 3.00 WELCTL P BOPE 21 :00 21 :30 0.50 DRILL P 21 :30 00:00 2.50 DRILL P PULD PULD Page 2 of2 IlVD I DFS I REPT NO. I DATE 2,363.0 2.48 3 9/26/2002 OPERATIONS. SUMMARY PHASE DESCRIPTION SURFAC Test lines to 2500 psi, rig pumped 40 bbls of Biozan preflush wI nutplug marker. Drop bottom plug, Dowell pumped 50 bbls of 10.5 ppg Mud Push spacer, 340 sxs (275 bbls) lead cmt AS Lite 3 @ 10.7 ppg and 231 sxs (45 bbls) of 15.8 ppg tail cmt - G wI adds. SURFAC Dropped top plug with 20bbls of FW from Dowell, switched to rig pumps and displaced with 180.2 bbls of 9.7 ppg mud @ 8-9 bpm - bumped plugs to 1000 psi - floats held - CIP @ 1140 hrs. Full returns throughout job with 82 bbls of 10.7 ppg cement returns to surface. SURFAC Flush riser, LD cement head and LJ. SURFAC RD Casing running equipment. SURFAC ND surface conducter I riser assembly. SURFAC Attemped to install Unibody wellhead onto mandrel hanger, unable to seat for proper M/M seal. Pulled wellhead off and changed out secondary seal. Changed saver sub to 4" XT-39. SURFAC Installed wellhead, no problems, tested M/M seal to 1000 psi for 10 min. NU 13 5/8" 5k BOPE. SURFAC Set test plug, test Pipe and Blind rams, choke and kill line valves, IBOP and floor safety valves to 250 I 5000 psi. Tested annular preventer to 2150 I 3500 psi. chuck Scheve (AOGCC) waived witnessing tests. Pull test plug and install wear bushing. SURFAC Hang drilling bails - RU 5" running tools. SURFAC MU BHA #2 - initialize LWD. Tested choke manifold valves 205/5000 psi while MU bha. 24 HR SUMMARY: LD bha, RU and run 62 jts 9 5/8" casing, landed with shoe @ 2672', FC @ 2584'. Cond mud and cement casing. ND riser, NU wellhead and BOPE. Test BOPE, MU bha #2. COMPANY Phillips ARCA Doyon Dowell SERVICE ITEM UNITS gals bbls USAGE 1 ,406 295 Fuel Water, Drilling TYPE CD2-26 NO. 2,302 CD2-29 PERSONNEL DATA NO; HOURS COMPANY 1 MI 5 DSR 24 Sperry-Sun 2 FMC SERVICE 3 4 4 1 MATERIALS I CONSUMPTION ON HAND ITEM -3,750 Water, Potable -1,890 USAGE 120 UNITS bbls -355 REMARKS SUPPORT CRAFT TYPE NO. REMARKS RESERVOIR NAME CD2-26 RESERVOIR AND INTERVAL DATA ZONE TOP BASE 2302 2 1100 COMMENTS CD2-29 Printed: 3/412003 4:52:38 PM PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 9/27/2002 I Volume Input Pump used: 1 #1 Mud Pump I... Strokes ... 0.1000 Bbls/Strk ... .. Pumping down annulus and DP. .. Well Name: Drilling Supervisor: CD2-29 I Rig: David Burley Type of Test: Casing Shoe Test LOT/FIT Hole Size: I USE PICK UST I. Casing Shoe Depth RKB-CHF: 36.5 Ft 2,672 Ft-MD 2,355 Ft-TVD Casina Size and Description: 19-5/8" 36#/Ft J-55 BfC Casina Test Mud Weight: 9.6 ppg Mud 10 min Gel 14.0 Lb/100 Ft2 Test Pressure 2,500 psi Rotating Weight 125,000 Lbs BlockslTop Drive Weight: 75,000 Lbs Estimates for Test: 1.8 bbls Hole Depth 2,702 Ft-MD 2,385 Ft-TVD I. Pressure IntearitvTes1 Mud Weight: 9.5 ppg Mud 10 min Gel: 16.0 Lb/100 Ft2 Rotating Weight: 124,000 Lbs BlockslTop Drive Weight: 75,000 Lbs Desired PIT EMW: 16.0 ppg Estimates for Test: 796 psi 0.6 bbls I. I. PIT 15 Second Shut-in Pressure, psi 780 EMW = Leak-off Pressure + Mud Weight = 800 + 9 5 0.052 x TVD 0.052 x 2355 . EMW at 2672 Ft-MD (2355 Ft-TVD) = 16.0 PPQ 3000 . - Lost 35 psi during test, held = 98.6% of test pressure. nfLul~LLLL¡.. 2500 - .... / 2000 - w IX: :J ~ 1500- W IX: 0.. 1000 - ~ 1 500 - 0 0 3 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point 2 Barrels ---CASING TEST ~LEAK-OFF TEST Comments: 30 Volume/Stroke Casing Test Pumping Shut-in Strks psi Min psi 0 0 0 2550 2 150 1 2550 4 310 2 2550 6 505 3 2550 8 735 4 2545 10 975 5 2545 12 1195 6 2545 14 1395 7 2540 16 1610 8 2540 18 1820 9 2540 20 2030 10 2540 22 2250 15 2530 24 2460 20 2525 25 2560 25 2520 30 2515 Volume Volume Pumped Bled Back 2.~ tSbls - Hbls Pump Rate: 7.0 Strkjmin ... Pressure Integrity Tes1 Pumping Shut-in Strks psi Min psi 0 0 0 790 1 65 0.25 780 2 140 0.5 770 3 220 1 760 4 305 1.5 7 , 5 400 2 74Tr 6 495 2.5 740 7 595 3 735 8 695 3.5 730 9 800 4 730 4.5 725 5 725 5.5 720 6 720 6.5 715 7 715 7.5 710 8 710 8.5 705 9 705 9.5 7r~ 10 7~ Volume Volume Pumped Bled Back 0.9 Hbls - Hbls Phillips Alaska, Inc. ') Casing Detail 7" Intermediate Casing Jt Number Num of Jts Jts 3 to 229 Jts 1 to 2 Remarks: 227 Jts 2 Jts Up Wt =325 COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKS to LOS FMC 11" X 7" Hanger 7" 26# L-80 STCM Csg 7" Davis Lynch Float Collar 7" 26# L-80 STCM Csg 7" Davis Lynch Float Shoe 1 straight blade centralizer per jt # 1 thru # 20 #'s 165, 166, 167 then every other jt fl # 169 to # 227. Total Centralizers: 53 ) 7" shoe @ 8-1/2" TO 240 joints in pipe shed - 229 total jts. to run I last 11 joints stay OL Use Best-a-Life 2000 pipe dope On Wt =175 Block Wt= 75K Well: CD2-29 Date: 10/1/2002 LENGTH 34.70 2.45 9432.81 1.47 83.50 1.40 SupeNisor: David Burley DEPTH TOPS 34.70 37.15 9469.96 9471.43 9554.93 9556.33 9566.00 ) ) ConocoRh i I lips Alaska Cementing iRe port Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 8.500 (in) 9,556 (ft) 10/2/2002 Intermediate Casing/Li 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Report #: Start: Spud Date: 9/24/2002 2 Report Date: 10/3/2002 9/24/2002 End: 10/7/2002 CemenfJób Type: Prirnary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Squeeze Casing Hole Size: TM D Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Cementer: Jim Thompson Pipe.l\llovement Pipe Movement: Reciprocating Rot Time Start:: Time End:: RPM: Rec Time Start: 14:30 Time End: 17:45 SPM: 1 Type: Cement Casing Volume Excess %: 40.00 Meas. From: 0 Time Circ Prior To Cementing: 4.00 Mud Circ Rate: 168 (gpm) Mud Circ Press: 620 (psi) Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 320 (Ibs) Stage No: 1 011 Start Mix Cmt: 16:34 Start Slurry Displ: 16:36 Start Displ: 16:45 End Pumping: 17:50 End Pump Date: 10/2/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.50 (bbl/min) 6.10 (bbl/min) Y 610 (psi) 1,000 (psi) 2 (min) Y Max Torque: (ft-Ibf) Drag Down: 175 (Ibs) Returns: 80 Total Mud Lost: 90.00 (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: densometer Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 38 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PV/yP: 8 (cp)/14 (lb/100ft2) Gels 10 sec: 7 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Static Temperature: 159 (OF) Density: 9.6 (ppg) Volume: 359.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Mud Data Stage No: 1 Slurry No: 1 .013 To: (ft) Description: ARCo wash Class: Cmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: Flush Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 3/412003 4:47:20 PM ) ) ConocoPhillips Alaska Cementing Report Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Report #: Start: Spud Date: 9/24/2002 2 Report Date: 10/3/2002 9/24/2002 End: 10/7/2002 Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: Spacer Slurry Interval: (ft) Water Source: To: (ft) Description: MUDPUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: CF) Temperature: (OF) Temperature: (OF) (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 3 013 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 9,556.00 (ft)To: 8,740.00 (ft) Cmt Vol: 34.0 (bbl) Water Source: lake water Slurry Vol:168 (sk) Test Data Thickening Time: 2.28 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: 130 (OF) Temperature: (OF) Temperature: (OF) (OF) Stage No: 1 Slurry No: 30f3- Additives Units Trade Name Type DEFOAMER DISPERSANT RETARDR MID-T Fluid Loss D-46 D-65 D-800 D-167 Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: 20.4 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Concentration Liquid Conc. 0.20 %BWOC 0.30 %BWOC 0.04 %BWOC 0.35 %BWOC Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Pressure (psi) (psi) Units Printed: 3/412003 4:47:20 PM ') ) GonocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Report #: Start: Spud Date: 9/24/2002 2 Report Date: 10/3/2002 9/24/2002 End: 10/7/2002 ShôeTest Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 12.10 (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 L.Qg/SLJOl~Y EYêlluêltiQn CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N Remarks Staged pumps up to 4 bpm as returns increased from 25% to 80%. Conditioned mud for cementing, maintained 9.6 ppg mud wt w/5 ppb LCM additions, peak mud wt out= 10.4 ppg. PUW 320 SOW 175 - PJSM. Line up to cementers, pumped 5 bbls of Arco wash and test lines to 3500 psi. Pumped additional 15 bbls of Arco wash @ 4.1 bpm / 700 psi - 50 bbls of 12.5 ppg MudpushXL spacer @ 4.1 bpm 1625 psi - dropped bottom plug and pumped 34 bbls of (168 sxs) of 15.8 ppg G cmt w/adds @ 4.0 bpm 600 psi. Dropped top plug - pumped 20 bbls of FW from cementers - switch to rig pumps and displace with 339 bbls of 9.6 ppg LSND mud @ 6 bpm 1240-610 psi. slowed pumps to 5 bpm last 10 bbls 540 - 610 psi. Reciprocated pipe untilllast 20 bbls of displacement, bumped plugs to 1000 psi, floats held, CIP @ 1750 hrs. Flow check annulus static. Maintained 80% returns while cementing - lost 398 bbls of mud while circulating and cementing - total losses for day = 1003 bbls. Printed: 3/412003 4:47:20 PM ) ) I JOB NUMBER EVENT CODE 24 HRS PROG ' TMD CD2-29 ODR 9,566.0 7,137.0 8.48 I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Doyon 19 Alpine 12,545.0 0 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD RIH with bha # 3. 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL RIH, test csg, drill out - 12.5 ppg FIT, drill 6 1/8" hole. 10/2/2002 299,301 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 15.96 WCD.W3A.0009.01 LAST SURVEY: DATE TMD INC AZlM LASTCASING NEXTCASING 10/1/2002 9,486.26 85.450 146.040 7.000 (in) @ 9,556.0 (ft) 7.000 (in) @ 9,545.0 (ft) DENSITY(ppg) I 9.65 I PP I IECD9.65MUD DATAl DAILY COST I 0 I CUM COST I FV PVNP GELS WL/HTHP FCIT.SOL OILlWAT %Sand/MBT Ph/pM Pf/Mf CI Ca H2S 38 8/14 7/9 6.61 11 / 0.1/12.5 7.61 11 300 40 WELL NAME SUPERVISOR David Burley CURRENT STATUS ~t-IANQ.I 3 I BHA WT. BELOW JARS STRING WT. UP BHAI HOLE CONDITIONS STRING WT. DN STRING WT. ROT ITEM DESCRIPTION NO JTS 1 1 1 1 1 1 1 1 1 1 1 1 1 3 1 2 Bit Mud Motor Drill Collar - Pony Stabilizer - Non Mag Sub - Float MWD MWD MWD Sub - Hang Off Flex Joint Flex Joint Flex Joint Crossover Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt LENGTH 0.70 24.93 8.70 5.45 2.47 24.46 8.55 10.86 10.92 30.78 31.15 31.15 1.13 92.14 32.12 61.33 BIT/RUN 3/ 3 SIZE MANUF. 6.125 SMITH BITS TYPE SERIAL NO. JETS OR TFA M20PX JS4128 15/15/15/1511 TORQUE / UNITS O.D. I.D. 6.125 1.500 4.750 2.794 4.780 2.250 4.750 1.250 4.720 1.250 4.730 1.250 4.750 1.250 4.680 2.310 4.750 2.310 4.680 2.310 4.750 2.310 4.000 2.563 4.750 2.000 4.000 2.563 9 10/2/2002 I CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 1,582,182 AUTH. 3,314,075 LAST BOP PRES TEST 10/2/2002 0 LIME ES BIT NO. I 3 BHA LENGTH 376.84 CONN SIZE CONN TYPE 9,566.0 10/2/20020-0-EC-A-D-I-NO-TD BIT / RUN WOB BIT OPERATIONS RPM GPM PRESS I P BIT HRS 24Hr DIST I 24HrROP I CUM HRS CUMDEPTHCOMiROP OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 00:30 0.50 CASE P RUNC INTRM1 Run casing to 3980' (95 jts total) PUW 155k SOW 135k 00:30 01 :00 0.50 CASE P CIRC INTRM1 Circ and cond mud @ 6 bpm ICP= 510 psi / FCP=450. 01 :00 03:00 2.00 CASE P RUNC INTRM1 Run casing to 6029' (145 jts total) PUW 210k SOW 155k 03:00 04:00 1.00 CASE P CIRC INTRM1 Stage pumps up to 6.0 bpm and cond mud ICP=620 psi FCP=520 psi. Maintain mud wt. in @ 9.6 ppg - peak mud wt. out 10.4 ppg - final 9.7 ppg. 04:00 06:30 2.50 CASE P RUNC INTRM1 Run casing to 8084' (194 jts total) had good returns until! # 194 - no returns. MU jnt # 195. PUW 275k SOW 170k 06:30 08:45 2.25 CASE NP DH CIRC INTRM1 Attempt to circ @ 2.0 bpm - no returns, reciprocate pipe from 8125' - 8050'. Printed: 3/412003 4:50:53 PM ) ') CD2-29 Cono.co.Pbillips.lnc. Dailý>DriIUmgRQP()rt. ¡JOB NUMBER I EVE~TDC~DE 124 HRS PROG IT~~566.0 WELL NAME OPERATIONS SUMMARY HOU.RS CODE TROUBLE SUB PHASE DESCRIPTION 06:30 08:45 2.25 CASE NP DH CIRC INTRM1 Continue to pump @ 2.0 - 2.5 bpm adding 5 ppb Mix II fine LCM to suction pit. Established partial returns- increased from slight to 30 % - no change in PO or SO wt's. Lost 260 bbls of mud. 08:45 14:00 5.25 CASE P RUNC INTRM1 Run casing to 9152' (220 jts total) PU & SO WT.'s stable @ 300k up and 175k down. Run casing from 9152'- SOW dropped 35-55k, pumped down last 9 jts with slight returns - SOW 150-120k. MU hanger and LJ, landed Casing with FS @ 9556', FC @ 9470'. Last 60' to bottom SOW improved 165k -140k with an increase in returns to 25%. Lost 345 bbls of mud. 14:00 14:30 0.50 CASE P RURD INTRM1 Ld fill-up tool, blow down TD, MU cement head. 14:30 16:15 1.75 CEMENT P CIRC I NTRM 1 Staged pumps up to 4 bpm as returns increased from 25% to 80%. Conditioned mud for cementing, maintained 9.6 ppg mud wt wI 5 ppb LCM additions, peak mud wt out= 10.4 ppg. PUW 320 SOW 175 - PJSM. 16:15 16:45 0.50 CEMENT P PUMP INTRM1 Line up to cementers, pumped 5 bbls of Arco wash and test lines to 3500 psi. Pumped additional 15 bbls of Arco wash @ 4.1 bpm 1 700 psi - 50 bbls of 12.5 ppg MudpushXL spacer @ 4.1 bpm I 625 psi - dropped bottom plug and pumped 34 bbls of (168 sxs) of 15.8 ppg G cmt wladds @ 4.0 bpm 600 psi. 16:45 18:00 1.25 CEMENT P DISP INTRM1 Dropped top plug - pumped 20 bbls of FW from cementers - switch to rig pumps and displace with 339 bbls of 9.6 ppg LSND mud @ 6 bpm 1240-610 psi. slowed pumps to 5 bpm last 10 bbls 540 - 610 psi. Reciprocated pipe untill last 20 bbls of displacement, bumped plugs to 1000 psi, floats held, CIP @ 1750 hrs. Flow check annulus static. Maintained 80% returns while cementing - lost 398 bbls of mud while circulating and cementing - total losses for day = 1003 bbls. 18:00 18:30 0.50 CEMENT P PULD INTRM1 RD cement head and lines, lay down LJ. 18:30 19:30 1.00 CASE P PTCH INTRM1 Pull thin wall wear bushing, install and test 9 5/8" X 7" packoff to 5000 psi for 10 min. 19:30 20:30 1.00 CASE P NUND INTRM1 Change top pipe rams to 31/2" X 6" VBR, clear casing tools from rig floor. 20:30 23:30 3.00 CASE INTRM1 Install test plug and test BOPE 250/5000 psi, Annular preventor 250/3500 psi. Perform Accumulator test, Chuck Scheve (AOGCC) waived witnessing tests. Pull test plug and install wear bushing. 23:30 00:00 0.50 DRILL P PULD INTRM1 MU BHA #3. 24 HR SUMMARY: Run and cement 7" casing FS @ 9556', install and test packoff. Test BOPE. MU BHA #3. SERVICE PERSONNEL. DATA NO. HOURS COMPANY 2 DSR 5 Sperry-Sun 27 Epoch 2 FMC 3 HOURS COMPANY Phillips ARCA Doyon Dowell MI SERVICE NO. 4 4 2 1 ITEM UNITS gals bbls USAGE 1,075 405 MATERIALS I CONSUMPTION ON HAND ITEM -11,430 Water, Potable -6,108 UNITS bbls USAGE 115 ON HAND -1,055 Fuel Water, Drilling TYPE CD2-26 NO. REMARKS SUPPORT CRAFT TYPE NO. REMARKS CD2-29 Printed: 3/412003 4:50:53 PM WELL NAME CD2-29 RESERVOIR NAME CD2-26 CD2-29 ) GonøcøPhlllipslnc. Daily DriUingRepon IJOBNUMBER \EVE~T;~DE !24HRSPROG IT~566.0 RESERVOIR AND INTERVAL DATA ZONE TOP BASE 20 2 1380 ) \TVD DFS \REPTNO. \ DATE 7,137.0 8.48 9 10/2/2002 COMMENTS Printed: 3/412003 4:50:53 PM PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Well Name: CD2-29 I Rig: Doyon 19 I Date: 10/3/2002 I Volume Input Drilling Supervisor: David Burley Pump used: I Cement Unit I.. Barrels ... Type of Test: Annulus Leak Off Test for Disposal Adequacy ... Pumping down annulus. ... Hole Size: la-1/2" r. Casing Shoe Depth I Hole Depth RKB-CHF: 36.5 Ft 2,672 Ft-MD 2,355 Ft-TVD ---Ft-MD Ft-TVD CasinQ Size and Description: 17" 26#/Ft L-ao BTC-MOD I. ChanQes for Annular Adeauacv Tes Pressure InteQritvTes1 Enter outer casing shoe test results in comments Mud Weight: 9.6 ppg Casing Description references outel casing string Inner casing 00 7.0 In. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. 16.0 ppg 784 psi Desired PIT EMW: Estimates for Test: I. EMW = Leak-off Pressure + Mud Weight = 697 9 6 0.052 x TVD 0.052 x 2355 + . EMW at 2672 Ft-MD (2355 Ft-TVD) = 15.3 1000 - w r:t: :) U) 500, U) w r:t: Q. 0 0 6 Barrels 10 12 8 2 4 ---CASING TEST ---LEAK-OFF TEST Comments: 9-5/8" shoe tested to 16.0 ppg EM\A -0.3 bbls I. PIT 15 Second Shut-in Pressure, psi 661 14 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point Casing Test Pumping Shut-in Bbls psi Min psi 0 1 2 3 4 5 6 7 8 9 10 15 20 25 30 30 ... Pump Rate: 0.5 Bbl/min ... Pressure Integrity Tes1 Pumping Shut-in Bbls psi Min psi 0 5 0 697 0.5 15 0.25 661 1 25. 0.5 641 1 .5 40 1 626 2 60 1.5 6 i 2.5 95 2 6mr"' 3 127 2.5 601 3.5 180 3 596 4 245 3.5 591 4.5 300 4 586 5 380 4.5 581 5.5 455 5 581 6 505 5.5 576 6.5 590 6 570 7 640 6.5 565 7.5 692 7 565 8 682 7.5 560 8.5 712 8 555 9 732' 8.5 550 9.5 722 9 545 10 712 9.5 54&" 10.5 712 10 5k~ 11 717 11.5 712 12 725 12.5 730 Volume Volume Volume Volume Pumped Bled Back Pumped Bled Back 0.0 tsbls _tsbls 12.~ tsbls _tsbls Name CDl-29-13S.764 -1320 --1238 -1031 ---825 -619 -413 +N/~S +FJ.W 17.398 5974502.63 WEI.I, DET AILS N(,rthin,g ANTI-COlliSION SETTINGS COMPANY DETAILS WELLPATH DETAILS E.{~tin,g I.ulitude I.ongitude Sk)[ C('llocoPhillips Alaska Ioe Engineering Kuparuk CD2-29 Interpolation Method: MD Interval: 1.000 Depth Range From 2660.000 To: 2680.000 Maximum Range: 1320.000 Reterence' Definitive Path Ref. Da~~ 0-]9 CD2-29 ;52.55 371711.16 7fY'20'18.8:60N 151"Ol'27.575W N/A Origin Origin +NI-S +E1-W OeM! 0,000 52550ft Calculati<m Method: Minimum Curvature Err(>T Sy~tem; ISCWSA SC~1ll ~{cthod: Horizontal Planc L'.lT(>r ~urfacc: Elliptical + Casing Warning Method: Ru~s Based 0.000 ~~:tVD V.Section Angle 100.593" 0 lJ20 From Colour 0 250 500 750 WOO 1250 1500 1750 2000 2500 3000 3500 4000 4500 5500 6500 7500 8500 9500 10000 10500 11000 11500 12500 --206 -0 270 -206 -413 ---(j I 9 ---825 -1031 -1238 -1320 90 ToMD 250 500 .750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5500 6500 7500 8500 9500 10000 10500 11000 11500 12500 13500 '~ ~ 1/4 Mile Radius of CD2-29... 9-518"Csg Pt (@ 2670 MD 12353' TVD) Reference Azimuth Angle [deg] vs Centre to Centre Separation [ft] ) ) SURFACE CASING SHOE SEPARATION FROM CD2-29 CD2-29 x V Surface Casing Shoe ASP 4 Coordinates: 372652.44 5974896.02 ulstance from Surface csg. Surface csg. Ann. Object Shoe X Shoe V Wells Permit # Permit Date Source well Vol. **** Start Date End Date well* Coord. Coord. CD2-35** ---- --- --- ----- 942 372312.31 5974017.68 CD2-24, CD2-33, CD2-33A, CD2-42 301-140 6/1/2001 CD2-15 33992 6/1/2001 10/10/2001 1798 371098.46 5973992.48 CD2-33 (+A&B), CD2-39, CD2-24 301-186 7/13/2001 CD2-14, CD2-15 33999 7/16/2001 10/9/2001 2030 370630.11 5974721.81 CD2-33 B*** ----- --- --- ---- 2693 370155.64 5973886.23 CD2-39 301-281 10/9/2001 CD2-15, CD2-47, CD2-44 29945 10/1 0/2001 9/16/2002 1298 372350.61 5973633.17 CD2-14 301-288 10/9/2001 CD2-45, CD2-47, CD2-32 31073 11/13/2001 3/5/2002 455 372202.47 5974960.87 CD2-15 301-308 11/6/2001 CD2-50, CD2-25, CD2-44 31652 3/6/2002 9/21/2002 1823 370832.00 5974984.02 CD2-47 301-322 12/3/2001 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 2141 371231.72 5973294.19 CD2-45 301-345 12/13/2001 CD2-49, CD2-17 22991 1/20/2002 2/19/2002 1048 372765.13 5973853.74 CD2-34 302-069 3/4/2002 CD2-13, CD2-37 22842 10/17/2002 11/28/2002 964 371803.06 5974439.79 CD2-26 302-068 3/4/2002 CD2-44, CD2-29, CD2-13 29626 9/7/2002 10/17/2002 920 371798.52 5974554.55 CD2-49 302-070 3/4/2002 CD2-50, CD2-46, CD2-22 27960 4/22/2002 5/28/2002 1628 371252.38 5974065.93 CD2-17 302-122 4/10/2002 CD-48, CD2-08 18181 5/29/2002 217/2003 914 371774.00 5974645.00 CD2-32 302-119 4/30/2002 CD2-19, CD2-41 , CD2-23 31113 6/14/2002 7/23/2002 1481 371295.61 5974302.38 CD2-41, CD2-19, CD2-16, CD2-50 302-121 4/30/2002 CD2-38 32000 7/24/2002 9/7/2002 1192 371665.21 5974227.65 CD2-25 NA 1138 371594.00 5974479.00 CD2-46 302-273 9/20/2002 CD2-51, CD2-12 31864 4/15/2003 5/19/2003 1122 371694.80 5974310.85 CD2-22 302-274 9/20/2002 CD2-08, CD2-36, CD2-51 31253 217/2003 3/16/2003 1029 371678.61 5974562.30 CD2-28, CD2-35a, CD2-48 302-275 9/20/2002 CD2-45, CD2-08 32000 12/10/2002 2/4/2003 1545 371631.74 5973736.14 C02-19 303-083 4/28/2003 CO2-58, CO2-52 31337 5/19/2003 6/27/2003 426 372284.88 5974681.33 C02-41 303-081 4/28/2003 C02-20, CO2-55 24037 6/27/2003 7/28/2003 1278 371990.58 5973802.52 C02-23 303-080 4/28/2003 NA 0 1649 371013.17 5975070.46 C02-16 ----- --- --- ----- 219 372460.34 5974790.01 C02-38 303-082 4/28/2003 C02-40 9773 7/28/2003 8/17/2003 1502 372033.86 5973527.13 C02-44 ---- --- ---- ----- 839 372034.57 5974328.53 C02-29 NA 0 0 372652.44 5974896.02 C02-13 ---- --- ---- ----- 889 372658.78 5975785.31 C02-37 ----- --- ---- ----- 2293 371569.79 5972874.47 C02-28 NA 0 539 372139.80 5974728.95 C02-08 ---- --- --- ----- 798 372655.88 5975603.76 C02-36 NA 0 1581 371848.22 5973535.38 CO2-51 NA 0 1554 373114.02 5973411.81 C02-12 NA 0 1674 371071.29 5975445.60 CO2-58 NA 0 2305 372102.03 5972657.80 CO2-52 NA 0 1234 372637.61 5973661.63 C02-20 NA 0 1424 371366.14 5975507.11 CO2-55 NA 0 2291 371118.23 5973194.84 C02-40 NA 0 2246 370691.67 5973801.44 C02-30 NA 0 2536 370465.55 5973612.54 C02-18 NA 0 2248 370691.40 59,73797.38 * Lateral distance in feet, between surface casing shoes, in the X- Y plane ** C02-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annular disposal. ***C02-33 B was a delineation well with a window milled out of 9-518" casing at 3840' MO (3062' TVO), shoe depth shown indicates window **** As of 8/17/03 ') . ') f).. O";Á - f t.pß \\ bql WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7ili Avenue, Suite 100 Anchorage, Alaska 99501-3539 June 04,2003 RE: MWD Formation Evaluation Logs - CD2-29, AK-MW-22162 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20427-00. RECEIVED Note: This Data Replaces Any Previous Data For Well CD2-29. JUL 24 2003 ~_~n ) aOd-lL/r 11!P9/ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7t1t Avenue, Suite 100 Anchorage, Alaska 99501-3539 April 08, 2003 RE: MWD Formation Evaluation Logs - CD2-29, AK-MW-22162 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20427-00. -~ / RECE\\JED APR 1 7 ZOO3 þj k8 at. & GaS Cons. commil8lOn : as Ai"tt¡,M8lilc MAR 1 1 Casing Detail 9 518" Surface Casing _PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 62 Doyon 19 RKB to LOS FMC Gen V Hanger 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe 60 Jts Jts 1 to 2 2 Jts 9- 5/8" shoe @ TO 12 1/4" Surface Hole RUN TOTAL 36 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, and 60. 68 joints total in shed - 62 joints total to run Last 6 joints stay out, # 63 thru # 68. Use API Mod Best 0 Life Artic Grade Csg Compound. Remarks: Up Wt - 152K Ibs Dn Wt - 140K Ibs Block Wt 75K Ibs Supervisor: David Burley D dOd-~t L\.~ Well: CD2-29 Date: 9/26/2002 LENGTH 36.50 2.30 2545.60 1.60 84.40 1.72 DEPTH TOPS 36.50 38.80 2584.40 2586.00 2670.40 2672.12 2682.00 ) ) ConocoPhillips Alaska Cementil1gRepørt Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Report #: Start: Spud Date: 9/24/2002 1 Report Date: 9/27/2002 9/24/2002 End: 10/7/2002 Hole Size: TMD Set: Date Set: Csg Type: Csg Size: 12.250 (in) 2,672 (ft) 9/26/2002 Surface Casing 9.625 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Hole Size: sa TMD: (ft) sa Date: sa Type: Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Cmtd. Csg: Cementer: Jim Thompson Pipe Movement: Reciprocating Pipe Movement Rot Time Start:: Time End:: RPM: Rec Time Start: 08:00 Time End: 11 :30 SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 152 (Ibs) Max Torque: (ft-Ibf) Drag Down: 140 (Ibs) Type: Cement Casing Volume Excess %: 150.00 Meas. From: 82 Time Circ Prior To Cementing: 1.75 Mud Circ Rate: 336 (gpm) Mud Circ Press: 360 (psi) Stage No: 1 of 1 Start Mix Cmt: 10:17 Start Slurry Displ: 10:18 Start Displ: 11 :08 End Pumping: 11 :40 End Pump Date: 9/26/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 8.00 (bbl/min) 9.00 (bbl/min) Y 600 (psi) 1,000 (psi) 2 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 82.00 (bbl) Ann Flow After: N Mixing Method: recirculat Density Meas By: densometer Mud Data Type: Spud Mud Density: 9.6 (ppg) Vise: 60 (s/qt) Bottom Hole Circulating Temperature: 70 (OF) Displacement Fluid Type: Mud PV/yP: 10 (cp)/17 (lb/100ft2) Gels 10 see: 14 (lb/100ft2) Gels 10 min: 16 (lb/100ft2) Bottom Hole Static Temperature: 54 CF) Density: 9.6 (ppg) Volume: 200.20 (bbl) Slurry Data Fluid Type: Mud Push Slurry Interval: (ft) Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: CF) Stage No: 1 Slurry No: 1 Of 3 To: (ft) Description: 10.5 ppg mud push Class: Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: CF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 3/412003 4:46:39 PM ) ) Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Report #: Start: Spud Date: 9/24/2002 1 Report Date: 9/27/2002 9/24/2002 End: 10/7/2002 Slurry Data Fluid Type: LEAD Description: ASLite Class: G Slurry Interval: 36.40 (ft) To: 2,172.00 (ft) Cmt Vol: 275.0 (bbl) Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Water Source: lake Slurry Vol:348 (sk) Water Vol: 166.8 (bbl) Other Vol: 0 Purpose: ZONAL ISOLA Mix Water: 20.13 (gal) Foam Job: N Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: 30.0 (cc) Fluid Loss Pressure: 65 (OF) Temperature: 65 (OF) Temperature: 65 (OF) Temperature: 65 (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure 50 (psi) 250 (psi) Stage No: 1 Slurry No: 2 of 3 - Additives Trade Name Type Concentration CIG D-124 D-53 S1 D-46 D-79 D-44 FILLlTE GYPSUM ACCELERATOR DEFOAMER EXTENDER ACCELERATOR 50.00 %BWOC 30.00 %BWOC 1.50 %BWOC 0.60 %BWOC 1.50 %BWOC % 9.00 Stage No: 1 Slurry No: 30f3 Slurry Data Fluid Type: TAIL Description: CI G Slurry Interval: 2,672.00 (ft)To: 2,172.00 (ft) Cmt Vol: 45.0 (bbl) Water Source: lake Slurry Vol:231 (sk) Class: G Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Vol: 30.4 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Test Data Thickening Time: 2.50 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: 65 (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) CF) Stage No: 1 Slurry No: 30f3 - Additives Trade Name Type DEFOAMER DISPERSANT ACCELERATOR Concentration Units Liquid Cone. Units D-46 D-65 S1 0.20 %BWOC 0.30 %BWOC 2.00 %BWOC Printed: 3/412003 4:46:39 PM "') ) Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Report #: Start: Spud Date: 9/24/2002 1 Report Date: 9/27/2002 9/24/2002 End: 10/7/2002 Shoe Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 16.00 (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 . beg/Survey. E,valuatien CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N Printed: 3/412003 4:46:39 PM ) TMD 2,682.0 2,363.0 2.48 AUTH MD I DAILY TANG 12,545.0 0 DAILY INT WIO MUD 0 DATE OF LAST SAFETY MEETING DAILY TOTAL Drill 8 1/2" hole. 9/25/2002 313,001 I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE WCD.W3A.0009.01 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 9/25/2002 2,624.14 41.300 68.020 9.625 (in) @ 2,672.0 (ft) 7.000 (in) @ 9,545.0 (ft) DENSITY(ppg) I 9.40 I PP I I ECD 19.40 I MUD DATA I DAILY COST I 0 ICUIIIICÒS"T I FV PVNP GELS WL/HTHP FCIT.SOL OILIWAT %Sand/MBT Ph/pM Pf/Mf CI Ca H2S 34 7/4 1/1 10.81 1/0 / 0.1110.0 8.21 /1 1,400 40 WELL NAME SUPERVISOR David Burley CURRENT STATUS CD2-29 I RIG NAME & NO. Doyon 19 ODR I FIELD NAME I OCS NO. Alpine ACCIDENTS LAST 24 HRS.? Drilling 8 1/2" hole from 2740'. 24 HR FORECAST LITHOLOGY ~~AiNê~1 2 eH~ WT. BELOW JARS STRING WT. UP BHA tHOLE CONI!)ITIONS STRING WT. DN STRING WT. ROT ITEM DESCRIPTION NO JTS 1 1 1 1 1 1 1 3 3 1 8 1 Bit Mud Motor Drill Collar - Pony Stabilizer - NonMag MWD MWD Sub - Float Drill Collar - Non Mag Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt Crossover LENGTH 1.00 25.15 15.43 3.12 27.65 20.36 2.42 91.60 90.47 32.74 240.23 1.42 O.D. 8.500 7.050 6.650 6.500 6.750 6.640 6.750 6.650 6.250 5.000 6.500 BIT / RUN 1 I 21 BITS SIZE MANUF. TYPE SERIAL NO. JETS OR TFA 12.250 HUGHES-CHR MX-C1 6005642 16/16/18/10// 8.500 HUGHES-CHR HCM605 7101195 14/14/14/14/141 BIT 1 RUN 1 / GPM BIT.OPEAATIONS PRESS PBIT HRS 24HrDIST 24HrROP cUM.HRS CUMDEPTH CUMROP 2,568.0 2,568.0 WOB I RPM I 3 9/26/2002 I CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 597,953 AUTH. 3,314,075 LAST BOP PRES TEST 9/26/2002 0 LIME ES TORQUE / UNITS 2 BHA LENGTH 551.59 CONN SIZE CONN TYPE J.D. 2.250 4.250 2.813 2.750 1.920 1.920 2.813 2.875 2.250 3.000 2.500 DEPTH IN DATE IN 114.0 9/24/2002 0-0------ 2,682.0 9/26/20020-0-EC-A-D-I-NO-TD OPEAATIONS SUMMARY PHASE SURFAC LD bha and clean rig floor. SURFAC Rig up to run 95/8" casing, monitor well on trip tank. SURFAC Held safety and opts meeting with rig crew. SURFAC Ran 62 joints of 95/8",36#, J-55 BTM casing, MU hanger and landing joint. land casing with shoe @ 2672', FC @ 2584'. SURFAC LD fill-up tool and MU cement head. SURFAC Staged pumps up to 8 bpm, circ and cond mud. Lower yield point from 54 to 17, reciprocated pipe 25' strokes, added nutplug for marker to last 50 bbls pumped, full returns throughout. Final circ pressure 360 psi, PUW 152k SOW 140k. PJSM. FROM TO HOURS CODE TROUBLE SUB 00:00 01:30 1.50 DRILL P PULD 01:30 02:30 1.00 CASE P RURD 02:30 03:00 0.50 CASE P SFTY 03:00 07:30 4.50 CASE P RUNC 07:30 08:00 0.50 CEMENT P PULD 08:00 09:45 1.75 CEMENT P CIRC OESC~IPTION Printed: 3/412003 4:52:38 PM ') WELL NAME CD2-29 FROM TO HOURS CODE TROUBLE SUB 09:45 11:15 1.50 CEMENT P PUMP 11:15 12:00 0.75 CEMENT P DISP 12:00 12:30 0.50 CEMENT P PULD 12:30 13:00 0.50 CASE P RURD 13:00 14:00 1.00 DRILL P PULD 14:00 16:00 2.00 WELCTL f\ IeQIP NUND 16:00 18:00 2.00 WELCTL P NUND 18:00 21 :00 3.00 WELCTL P BOPE 21 :00 21 :30 0.50 DRILL P 21 :30 00:00 2.50 DRILL P PULD PULD OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC Test lines to 2500 psi, rig pumped 40 bbls of Biozan preflush wI nutplug marker. Drop bottom plug, Dowell pumped 50 bbls of 10.5 ppg Mud Push spacer, 340 sxs (275 bbls) lead cmt AS Lite 3 @ 10.7 ppg and 231 sxs (45 bbls) of 15.8 ppg tail cmt - G wI adds. SURFAC Dropped top plug with 20 bbls of FW from Dowell, switched to rig pumps and displaced with 180.2 bbls of 9.7 ppg mud @ 8-9 bpm - bumped plugs to 1000 psi - floats held - CIP @ 1140 hrs. Full returns throughout job with 82 bbls of 10.7 ppg cement returns to surface. SURFAC Flush riser, LD cement head and LJ. SURFAC RD Casing running equipment. SURFAC ND surface conducter / riser assembly. SURFAC Attemped to install Unibody wellhead onto mandrel hanger, unable to seat for proper M/M seal. Pulled wellhead off and changed out secondary seal. Changed saver sub to 4" XT-39. SURFAC Installed wellhead, no problems, tested M/M seal to 1000 psi for 10 min. NU 13 5/8" 5k BOPE. SURFAC Set test plug, test Pipe and Blind rams, choke and kill line valves, IBOP and floor safety valves to 250 I 5000 psi. Tested annular preventer to 2150 I 3500 psi. chuck Scheve (AOGCC) waived witnessing tests. Pull test plug and install wear bushing. SURFAC Hang drilling bails - RU 5" running tools. SURFAC MU BHA #2 - initialize LWD. Tested choke manifold valves 205/5000 psi while MU bha. 24 HR SUMMARY: LD bha, RU and run 62 jts 9 5/8" casing, landed with shoe @ 2672', FC @ 2584'. Cond mud and cement casing. ND riser, NU wellhead and BOPE. Test BOPE, MU bha #2. COMPÞiN¥ Phillips ARCA Doyon Dowell SERVICE ITEM USAGE 1 ,406 295 Fuel Water, Drilling UNITS gals bbls T¥PE CD2-26 NO. 2,302 CD2-29 PERS0NNEL<(DAmA N.C:>; FlOURSCoMPAN¥ 1 MI 5 DSR 24 Sperry-Sun 2 FMC 3 4 4 1 MATERIALS ¡CONSUMPTION ON HAND ITEM -3,750 Water, Potable -1,890 UNITS bbls USÞiGE 120 ON HAND -355 REMARKS SUPPORT CRAFT T¥PE REMARKS NO. RESERVOIR NAME CD2-26 CD2-29 RESERVOIR AND INTERVAL (DATA ZONE TOP BASE 2302 2 1100 COMMENTS Printed: 3/412003 4:52:38 PM PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 9/27/2002 I Volume Input Volume/Stroke Pump used: I #1 Mud Pump I... Strokes ... 0.1000 Bbls/Strk ... 'Y Pumping down annulus and DP. 'Y Well Name: Drilling Supervisor: CD2-29 I Rig: David Burley Type of Test: Casing Shoe Test LOT/FIT Hole Size: I USE PICK UST I.. Casing Shoe Depth RKB-CHF: 36.5 Ft 2,672 Ft-MD 2,355 Ft- TVD Casina Size and Description: 19-5/8" 36#/Ft J-55 BTC Casina Tes1 Mud Weight: 9.6 ppg Mud 10 min Gel 14.0 Lb/100 Ft2 Test Pressure 2,500 psi Rotating Weight 125,000 Lbs BlockslTop Drive Weight: 75,000 Lbs Estimates for Test: 1.8 bbls Hole Depth 2,702 Ft-MD 2,385 Ft-TVD I. Pressure Inteari!vTest Mud Weight: 9.5 ppg Mud 10 min Gel: 16.0 Lb/100 Ft2 Rotating Weight: 124,000 Lbs BlockslTop Drive Weight: 75,000 Lbs Desired PIT EMW: 16.0 ppg Estimates for Test: 796 psi 0.6 bbls I.. I.. EMW = Leak-off Pressure + Mud Weight = 800 + 9 5 0.052 x TVD 0.052 x 2355 . EMW at 2672 Ft-MD (2355 Ft-TVD) = 16.0 ppg PIT 15 Second Shut-in Pressure, psi 780 3000 . - Lost 35 psi during test, held = 98.6% of test pressure. .w1 iA.Ul - 2500 - ~- '18!. ... 2000 - w 0:: ~ ~ 1500- W 0:: a.. 1000. ~ 500 - 0 0 2 3 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point Barrels """'CASING TEST ---LEAK-OFF TEST Comments: L 30 Casing Tes1 Pumping Shut-in Strks psi Min psi 0 0 0 2550 2 150 1 2550 4 310 2 2550 6 505 3 2550 8 735 4 2545 10 975 5 2545 12 1195 6 2545 14 1395 7 2540 16 1610 8 2540 18 1820 9 2540 20 2030 10 2540 22 2250 15 2530 24 2460 20 2525 25 2560 25 2520 30 2515 Volume Volume Pumped Bled Back 2.~ tsbls -'tsbls Pump Rate: 7.0 Strk/min ... Pressure Intègrity Test Pumping Shut-in Strks psi Min psi 0 0 0 790 1 65 0.25 780 2 140 0.5 770 3 220 1 760 4 305 1.5 750 5 400 2 740~ 6 495 2.5 740 7 595 3 735 8 695 3.5 730 9 800 4 730 4.5 725 5 725 5.5 720 6 720 6.5 715 7 715 7.5 710 8 710 8.5 705 9 705 9.5 705 10 70 ..'-' Volume Bled Back _tsblS Phillips Alaska, Inc. ) Casing Detail 7" Intermediate Casing Jt Number Num of Jts Jts 3 to 229 Jts 1 to 2 Remarks: 227 Jts 2 Jts Up Wt =325 COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB to LOS FMC 11" X 7" Hanger 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Collar 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Shoe 1 straight blade centralizer per jt # 1 thru # 20 #'s 165, 166, 167 then every other jt fl # 169 to # 227. Total Centralizers: 53 ) 7" shoe @ 8-1/2" TO 240 joints in pipe shed - 229 total jts. to run 1 last 11 joints stay Ot Use Best-Q-Life 2000 pipe dope On Wt =175 Block Wt= 75K Well: CD2-29 Date: 10/1/2002 LENGTH 34.70 2.45 9432.81 1.47 83.50 1.40 Supervisor: David Burley DEPTH TOPS 34.70 37.15 9469.96 9471.43 9554.93 9556.33 9566.00 ) ') Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: 8.500 (in) 9,556 (ft) 10/2/2002 Intermediate Casing/Li 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Report #: Start: Spud Date: 9/24/2002 2 Report Date: 10/3/2002 9/24/2002 End: 10/7/2002 SqueezeOpen..Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Squeeze Casing Hole Size: TM D Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jim Thompson Pipe Movement Pipe Movement: Reciprocating Rot Time Start:: Time End:: RPM: RecTimeStart:14:30 Time End: 17:45 SPM: 1 Type: Cement Casing Volume Excess %: 40.00 Meas. From: 0 Time Circ Prior To Cementing: 4.00 Mud Circ Rate: 168 (gpm) Mud Circ Press: 620 (psi) Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 320 (Ibs) Max Torque: (ft-Ibf) Drag Down: 175 (Ibs) StageNø: 1 of 1 Start Mix Cmt: 16:34 Start Slurry Displ: 16:36 Start Displ: 16:45 End Pumping: 17:50 End Pump Date: 10/2/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.50 (bbl/min) 6.10 (bbl/min) Y 610 (psi) 1,000 (psi) 2 (min) Y Returns: 80 Total Mud Lost: 90.00 (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: densometer Mud Data Stage No: 1 SlUrry No: 1 of 3 Time Compressive Strength 1: Compressive Strength 2: Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 38 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PV/yP: 8 (cp)/14 (lb/100ft2) Gels 10 sec: 7 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Static Temperature: 159 CF) Density: 9.6 (ppg) Volume: 359.00 (bbl) To: (ft) Description: ARCo wash Class: Cmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: Flush Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: CF) Temperature: CF) Temp (OF) (OF) Pressure (psi) (psi) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Printed: 3/412003 4:47:20 PM ') ') Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Slurry Data Fluid Type: Spacer Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Report #: Start: Spud Date: 9/24/2002 2 Report Date: 10/3/2002 9/24/2002 End: 10/7/2002 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: CF) Temperature: (OF) (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Stage No.: 1 Slurry No: 3 of 3 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 9,556.00 (ft)To: 8,740.00 (ft) Cmt Vol: 34.0 (bbl) Water Source: lake water Slurry Vol:168 (sk) Test Data Thickening Time: 2.28 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Trade Name 0-46 0-65 0-800 D-167 Temperature: 130 (OF) Temperature: CF) Temperature: (OF) (OF) Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: 20.4 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Pressure (psi) (psi) Temp (OF) (OF) Stage No: 1 Slurry No: 3 of 3 - Additives Type DEFOAMER DISPERSANT RETARDR MID-T Fluid Loss CÖhcenfråtion 0.20 %BWOC 0.30 %BWOC 0.04 %BWOC 0.35 %BWOC Printed: 3/412003 4:47:20 PM ) Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Report #: Start: Spud Date: 9/24/2002 2 Report Date: 10/3/2002 9/24/2002 End: 10/7/2002 Shoe Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 12.10 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N log/SurveyEvaluation CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N Staged pumps up to 4 bpm as returns increased from 25% to 80%. Conditioned mud for cementing, maintained 9.6 ppg mud wt wI 5 ppb LCM additions, peak mud wt out= 10.4 ppg. PUW 320 SOW 175 - PJSM. Line up to cementers, pumped 5 bbls of Arco wash and test lines to 3500 psi. Pumped additional 15 bbls of Arco wash @ 4.1 bpm I 700 psi - 50 bbls of 12.5 ppg MudpushXL spacer @ 4.1 bpm 1625 psi - dropped bottom plug and pumped 34 bbls of (168 sxs) of 15.8 ppg G cmt w/adds @ 4.0 bpm 600 psi. Dropped top plug - pumped 20 bbls of FW from cementers - switch to rig pumps and displace with 339 bbls of 9.6 ppg LSND mud @ 6 bpm 1240-610 psi. slowed pumps to 5 bpm last 10 bbls 540 - 610 psi. Reciprocated pipe untilllast 20 bbls of displacement, bumped plugs to 1000 psi, floats held, CIP @ 1750 hrs. Flow check annulus static. Maintained 80% returns while cementing -lost 398 bbls of mud while circulating and cementing - total losses for day = 1003 bbls. Printed: 3/412003 4:47:20 PM TMD ODR 9,566.0 7,137.0 8.48 FIELD NAMEIOCS NO. AUTHMD DAILY TANG Alpine 12,545.0 0 ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD RIH with bha # 3. 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL RIH, test csg, drill out - 12.5 ppg FIT, drill 6 1/8" hole. 10/2/2002 299,301 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 15.96 WCD.W3A.0009.01 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 10/1/2002 9,486.26 85.450 146.040 7.000 (in) @ 9,556.0 (ft) 7.000 (in) @ 9,545.0 (ft) D~~SITY(ppg) I 9.65 I>pp I IECDI9.65IMUE»E>~mAIDÄIL¥~O$TI 0 IC~MØØSTI FV PVNP GELS WUHTHP FCIT.SOL OILIWAT %Sand/MBT Ph/pM Pf/Mf CI Ca H2S 38 8/14 7/9 6.61 11 I 0.1/12.5 7.61 11 300 40 äHANo....1 3 I BH~iPHOL.EOONÐI"'IONS BHAWT.BELOWJARS STRING WT. UP STRINGWT.DNSTRINGWT.ROT ) WELL NAME SUPERVISOR David Burley CURRENT STATUS CD2-29 I RIG NAME & NO. Doyon 19 ITEM DESCRIPTION NO JTS 1 1 1 1 1 1 1 1 1 1 1 1 1 3 1 2 Bit Mud Motor Drill Collar - Pony Stabilizer - NonMag Sub - Float MWD MWD MWD Sub - Hang Off Flex Joint Flex Joint Flex Joint Crossover Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt LENGTH 0.70 24.93 8.70 5.45 2.47 24.46 8.55 10.86 10.92 30.78 31.15 31.15 1.13 92.14 32.12 61.33 BIT /RUN 31 SIZE MANUF. 6.125 SMITH Burs TYPE SERIAL NO. JETSORTFA M20PX JS4128 15/15/15/15/1 81m OPERAmlONS RPM I GPM I PRESS I PBIT HRS I 24HrDIST I 24HrROP I CUMHRS CUMDEPTHICUMROP OPERATIONS...SUMM~RY PHASE INTRM 1 I NTRM 1 INTRM1 INTRM1 DESCRIPTION Run casing to 3980' (95 jts total) PUW 155k SOW 135k Circ and cond mud @ 6 bpm ICP= 510 psi I FCP=450. Run casing to 6029' (145 jts total) PUW 210k SOW 155k Stage pumps up to 6.0 bpm and cond mud ICP=620 psi FCP=520 psi. Maintain mud wt. in @ 9.6 ppg - peak mud wt. out 10.4 ppg - final 9.7 ppg. Run casing to 8084' (194 jts total) had good returns untill # 194 - no returns. MU jnt # 195. PUW 275k SOW 170k Attempt to circ @ 2.0 bpm - no returns, reciprocate pipe from 8125' - 8050'. 3 BIT 'RUN WOB FROM TO HOURS CODE TROUBLE SUB 00:00 00:30 0.50 CASE P RUNC 00:30 01:00 0.50 CASE P CIRC 01:00 03:00 2.00 CASE P RUNC 03:00 04:00 1.00 CASE P CIRC 04:00 06:30 2.50 CASE P RUNC INTRM1 06:30 08:45 2.25 CASE NP DH CIRC I NTRM 1 O.D. 6.125 4.750 4.780 4.750 4.720 4.730 4.750 4.680 4.750 4.680 4.750 4.000 4.750 4.000 ") 9 10/2/2002 CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 1,582,182 AUTH. 3,314,075 LAST BOP PRES TEST 10/2/2002 0 LIME I.D. 1.500 2.794 376.84 CONN SIZE CONN TYPE 2.250 1.250 1.250 1.250 1.250 2.310 2.310 2.310 2.310 2.563 2.000 2.563 DEPTH IN DATE IN 9,566.0 10/2/20020-0-EC-A-D-I-NO-TD Printed: 3/412003 4:50:53 PM ') ) WELL NAME CD2-29 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 06:30 08:45 2.25 CASE NP DH CIRC INTRM1 Continue to pump @ 2.0 - 2.5 bpm adding 5 ppb Mix II fine LCM to suction pit. Established partial returns- increased from slight to 30 % - no change in PO or SO wt's. Lost 260 bbls of mud. 08:45 14:00 5.25 CASE P RUNC INTRM1 Run casing to 9152' (220 jts total) PU & SO WT.'s stable @ 300k up and 175k down. Run casing from 9152'. SOW dropped 35-55k, pumped down last 9 jts with slight returns - SOW 150-120k. MU hanger and LJ, landed Casing with FS @ 9556', FC @ 9470'. Last 60' to bottom SOW improved 165k -140k with an increase in returns to 25%. Lost 345 bbls of mud. 14:00 14:30 0.50 CASE P RURD INTRM1 Ld fill-up tool, blow down TD, MU cement head. 14:30 16:15 1.75 CEMENT P CIRC INTRM1 Staged pumps up to 4 bpm as returns increased from 25% to 80%. Conditioned mud for cementing, maintained 9.6 ppg mud wt wI 5 ppb LCM additions, peak mud wt out= 10.4 ppg. PUW 320 SOW 175 - PJSM. 16:15 16:45 0.50 CEMENT P PUMP INTRM1 Line up to cementers, pumped 5 bbls of Arco wash and test lines to 3500 psi. Pumped additional 15 bbls of Arco wash @ 4.1 bpm 1700 psi - 50 bbls of 12.5 ppg MudpushXL spacer @ 4.1 bpm I 625 psi - dropped bottom plug and pumped 34 bbls of (168 sxs) of 15.8 ppg G cmt wladds @ 4.0 bpm 600 psi. 16:45 18:00 1.25 CEMENT P DISP INTRM1 Dropped top plug - pumped 20 bbls of FW from cementers - switch to rig pumps and displace with 339 bbls of 9.6 ppg LSND mud @ 6 bpm 1240-610 psi. slowed pumps to 5 bpm last 10 bbls 540 - 610 psi. Reciprocated pipe untill last 20 bbls of displacement, bumped plugs to 1000 psi, floats held, CIP @ 1750 hrs. Flow check annulus static. Maintained 80% returns while cementing - lost 398 bbls of mud while circulating and cementing - total losses for day = 1003 bbls. 18:00 18:30 0.50 CEMENT P PULD INTRM1 RD cement head and lines, lay down LJ. 18:30 19:30 1.00 CASE P PTCH INTRM1 Pull thin wall wear bushing, install and test 9 5/8" X 7" packoff to 5000 psi for 10 min. 19:30 20:30 1.00 CASE P NUND INTRM1 Change top pipe rams to 3 1/2" X 6" VBR, clear casing tools from rig floor. 20:30 23:30 3.00 CASE INTRM1 Install test plug and test BOPE 250/5000 psi, Annular preventor 250/3500 psi. Perform Accumulator test, Chuck Scheve (AOGCC) waived witnessing tests. Pull test plug and install wear bushing. 23:30 00:00 0.50 DRILL P PULD I NTRM 1 MU BHA #3. 24 HR SUMMARY: Run and cement 7" casing FS @ 9556', install and test packoff. Test BOPE. MU BHA #3. SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 DSR 5 Sperry-Sun 27 Epoch 2 FMC 3 SERVICE HOURS COMPANY Phillips ARCA Doyon Dowell MI NO. 4 4 2 1 ITEM UNITS gals bbls USAGE 1,075 405 MATERIALS I CONSUMPTION ON HAND ITEM -11,430 Water, Potable -6,108 UNITS bbls USAGE 115 ON HAND -1,055 Fuel Water, Drilling TYPE CD2-26 NO. REMARKS SUPPORT CRAFT TYPE NO. REMARKS CD2-29 Printed: 3/412003 4:50:53 PM ) ) WELL NAME CD2-29 RESERVOIR NAME CD2-26 CD2-29 RESERVOIR AND INTERVAL DATA ZONE TOP BASE 20 2 1380 COMMENTS Printed: 3/412003 4:50:53 PM PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 10/3/2002 I Volume Input Pump used: I Cement Unit I... Barrels ... Well Name: Drilling Supervisor: CD2-29 I Rig: David Burley Type of Test: Annulus Leak Off Test for Disposal Adequacy ... Pumping down annulus. .., Hole Size: 18-1/2" I... Casing Shoe Depth I Hole Depth RKB-CHF: 36.5 Ft 2,672 Ft-MD 2,355 Ft-TVD _Ft-MD _Ft-TVD Casina Size and Description: [7" 26#/Ft L-80 BTC-MOD I... .Chanaes for Annular Adequacy Tes Pressure IntearitvTest Enter outer casing shoe test results in comments Mud Weight: 9.6 ppg Casing Description references outel casing string Inner casing 00 7.0 In. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. Desired PIT EMW: Estimates for Test: I... EMW = Leak-off Pressure + Mud Weight = 697 + 9 6 0.052 x TVD 0.052 x 2355 . EMW at 2672 Ft-MD (2355 Ft-TVD) = 15.3 1000 - w Q:: :) ~ 500- W Q:: 0.. 0 0 8 10 2 4 6 Barrels 12 ---CASING TEST -8-LEAK-OFF TEST Comments: 9-5/8" shoe tested to 16.0 ppg EMV'\¡ 16.0 ppg 784 psi -0.3 bbls I... PIT 15 Second Shut-in Pressure, psi 661 "'" 14 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point Casing Tes1 Pumping Shut-in Bbls psi Min psi 30 ... Pump Rate: 0.5 Bbljmin ... Pressure Integrity Test Pumping Shut-in Bbls psi Min psi 0 5 0 697 0.5 15' 0.25 661 1 25 0.5 641 1.5 40 1 626 2 60 1.5 611 2.5 95 . 2 60~1 3 127 2.5 601 3.5 180 3 596 4 245 3.5 591 4.5 300 4 586 5 380 4.5 581 5.5 455 5 581 6 505 5.5 576 6.5 590 6 570 7 640 6.5 565 7.5 692 7 565 8 682' 7.5 560 8.5 712' 8 555 9 732 8.5 550 9.5 722 9 545 10 712 9.5 545 10.5 712' 10 5& 11 717 ~ 11.5 712 12 725 12.5 730 Volume Volume Volume Volume Pumped Bled Back Pumped Bled Back 0.0 ~bls _l::Sbls 12.~ I::Sbls _l::SblS 11/26/02 Schlumbepger NO. 2565 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine ~' Color Well Job# Log Description Date BL Sepia Prints CD CD2-38 jO a.-1 ' I 22491 SCMT 10/01/02 CD2-44 ll;} - 1.Þt? 22493 SCMT 10/04/02 CD2-29 ~~-ltJ~ 22492 SCMT 10/22/02 '-ø SIGN~WJoo~ DATE: RECE\\JEO NO \/ 2. 9 20Q2 ,,, eorom\ßS\On O. . ~..~ &. Gas \jO\1S. Aia5\C.a \\ AAthoœge Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ) ) ~ PHILLIPS Alaska, Inc. ~~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 November 7,2002 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-29 (202-148) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-29. If you have any questions regarding this matter, please contact me at 265-6120 or Vern Johnson at 265-6081. Sincerely, A .t:. CÞZ G. C. Alvord Alpine Drilling Team Leader P AI Drilling Re€EIVED NOV 1 2 2002 GCAlskad Alaska Oil & Gas Cons. Commission Anchorage ^) ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 0 '~."--"::=:I}:~. 2. Name of Operator j;tOOAt~, 3 ~d~~::I:::~~=~~:~~ge, AK 9951~0360 i~1 4. Location of well at surface ,.. ....~~}I:,!:".:""..3,:.."1ø 1855' FNL, 15?8' FEL, Sec. 2, T11N, R4E, UM (ASP: 371711, 5974503); . ~.~,:.~,.~;.~:,,> 1 At Top Producing Interval I~ IIJ .1J,~þ 2..1 341' FNL, 1728' FEL, Sec. 1, T11N, R4E, UM (ASP: 376815,5975931) .' .~Emr.:"'D '~ At Total Depth 1 - ~ 2198' FSL, 264' FEL, Sec. 1, T11N, R4E, UM (ASP: 378234, 5973167) ~ ,. ..,~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKS 37' feet ADL 380075 12. Date Spudded ,13. Date T.D. Reached 14. Date Comp., Susp. Or Ab~nd. September 24,2002 October 6,2002 October 7,2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 12560' MD 17127' TVD 12560' MD I 7127' TVD YES 0 No 0 22. Type Electric or Other Logs Run GR/Res 23. Classification of Service Well WAG Injector 7. Permit Number 202-148 I 8. API Number 50-103-20427 -00 9. Unit or Lease Name Colville River Unit 10. Well Number CD2-29 11. Field and Pool Colville River Field Alpine Oil Pool 15. Water Depth, if offshore NI A feet MSL 20. Depth where SSSV set 2240' Landing Nipple CASING SIZE CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2672' Surface 9556' WT. PER FT. 62.5# 36# 26# GRADE H-40 J-55 L-80 HOLE SIZE 16. No. of Completions 21. Thickness of Permafrost 1700' MD 42" CEMENTING RECORD 12 yds Portland Type III 348 sx AS III Lite, 231 sx Class G 168 sx Class G 16" 9.625" 12.25" 7" 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE AMOUNT PULLED 4.5" TUBING RECORD DEPTH SET (MD) 9026' PACKER SET (MD) 8906' open hole completion from 9556' to 12560' MD 26. N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. Date First Production Not applicable Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) WAG Injector Production for OIL-BBL GAS-MCF Test Period> Calculated W A TER-BBL N/A Flow Tubing Casing Pressure OIL-BBL GAS-MCF W A TER-BBL press. 28. psi 24-Hour Rate> CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A NOV I 8 2002 RBOMS BFl GY Form 10-407 Rev. 7-1-80 COf*f~N~ P~~'1(9f1Sf ~~D9 t.,;) 1; -\:.~ ~ l\,"". ~ ij \,,[ [!C\ L CHOKE SIZE GAS-OIL RATIO OIL GRAVITY - API (corr) RECEIVED NOV 1 2' 2002 Alaska Oil & Gas Oons. Commission Anchorage Submit in duplicate 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, a/l fluids recovered and gravity. GOR, and time of each phase. NAME CD2~29 Top Alpine D Top Alpine C Base Alpine 9283' 9449' 12560' 7105' 7126' 7127' RE€EIVED NOV 1 2 2002 Alaska Oil & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vem Johnson 265-6081 Signed ~L ()Jl Chip Alvord Title Alpine Drilling Team Leader Date k/~ l)L Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (Gl) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ) ') ConocoPhillips Alaska Operations Summary Report Page 1 of 6 Legal Well Name: CD2-29 Common Well Name: CD2-29 Spud Date: 9/24/2002 Event Name: ROT - DRILLING Start: 9/24/2002 End: 1 0/7/2002 Contractor Name: Doyon Rig Release: 10/7/2002 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours Code Sub Phase Description of Operations Code 9/24/2002 00:00 - 01 :30 1.50 MOVE DMOB MOVE Move out GIS, Pit/Motor Complex and skid rig floor to move position. 01 :30 - 03:30 2.00 MOVE MOVE MOVE Move subbase to well slot 29, center subbase over hole. 03:30 - 05:00 1.50 MOVE POSN MOVE Skid rig floor to drill position, spot Pit/Motor complex, pipe shed and GIS. Connect air, water and mud lines, highline power on @ 0430 hours. Rig accepted @ 0500 hrs. 05:00 - 07:30 2.50 MOVE RURD RIGUP NU Conductor assembly and rig up. 07:30 - 09:00 1 .50 MOVE RURD RIGUP Take on spud mud and move bha componets to rig floor. 09:00 - 09:30 0.50 MOVE SFTY RIGUP Held Pre-Sup meeting with Rig team. 09:30 - 12:00 2.50 MOVE RURD RIGUP PU three 8" DC's and stand back in derrick. MU BHA #1. 12:00 - 12:30 0.50 MOVE RURD RIGUP Fill Conductor, check for leaks, test mud lines to 3500 psi. 12:30 - 00:00 11.50 DRILL DRLG SURFAC Spud well @ 1230 hrs, drill 12 1/4" hole from 114'to 979' (973' tvd). .. ART=2.67 AST=5.02 PUW 125k SOW 125k ROT 125k Torque 5500 on 15000 off Ran gyro surveys @ 164',254',341' and 434'. 9/25/2002 00:00 - 13:45 13.75 DRILL DRLG SURFAC Drill from 979' to 2682' (2363 tvd) casing point. ART =7.4 AST =2.28 PUW 150k SOW 130k ROT 140k 630 gpm I 2500 psi / 60 rpm Torque 8500 on 6000 off 13:45 - 15:00 1.25 DRILL CIRC SURFAC Circ for wiper trip, 650 gpm I 2200 psi I 80 rpm shakers clean after 3 X bu. Flow check well, static. 15:00 - 20:15 5.25 DRILL WIPR SURFAC Wipe hole to 1960' 10-25k drag, 1960' to 1900' drag increased to 40-50k. MU TD and back ream from 1930' to 1833' 610 gpm I 1875 psi I 80 rpm circ 1.5 X bu, heavy cuttings back through first BU. Continue to wipe hole, pulling 40k over @ 1800'. MU Td Backream from 1833' to 1739'. Pulled from 1739', 50k drag @ 1660'. Backream from 1739' to 1548', 550 gpm I 1600 psi 180 rpm circ untill shakers clean 1.5 X BU, flow check well, static. Attempted to pull pipe continued to drag 40-50k from 1500'. Backream from 1548' to 1263', circ untill shakers clean, 2 x BU heavy cuttings trough first BU, mostly clay. Flow check well, static. Pulled pipe from 1263' to 1168', 10-25k drag. Continued to wipe hole to 890', 5-10k drag. Flow check well, static. RIH, worked past tight spot @ 1253', no other problems. Precautionary wash and ream last stand to bottom. 20:15-21:30 1.25 DRILL CIRC SURFAC Circ hole clean, 660 gpm 12300 psi 185 rpm 3 X BU, shakers clean. Flow check well, static. 21 :30 - 00:00 2.50 DRILL SURFAC POH to BHA, 5-15k drag, flow check well, static. POH wI bha, worked through tight spots @ 571' & 535' 30k over, stand back hwdp and 8" dc's. 9/26/2002 00:00 - 01 :30 1.50 DRILL PULD SURFAC LD bha and clean rig floor. 01 :30 - 02:30 1.00 CASE RURD SURFAC Rig up to run 9 5/8" casing, monitor well on trip tank. 02:30 - 03:00 0.50 CASE SFTY SURFAC Held safety and opts meeting with rig crew. 03:00 - 07:30 4.50 CASE RUNC SURFAC Ran 62 joints of 9 5/8",36#, J-55 BTM casing, MU hanger and landing joint, land casing with shoe @ 2672', FC @ 2584'. 07:30 - 08:00 0.50 CEMENT PULD SURFAC LD fill-up tool and MU cement head. 08:00 - 09:45 1.75 CEMENTCIRC SURFAC Staged pumps up to 8 bpm, circ and cond mud. Lower yield point from 54 to 17, reciprocated pipe 25' strokes, added nutplug for marker to last 50 bbls pumped, full returns throughout. Final circ pressure 360 psi, PUW 152k SOW 140k. PJSM. 09:45 - 11 :15 1.50 CEMENT PUMP SURFAC Test lines to 2500 psi, rig pumped 40 bbls of Biozan preflush wI nutplug marker. Drop bottom plug, Dowell pumped 50 bbls of 10.5 ppg Mud Printed: 10/23/2002 4:23: 12 PM ) ) Page 2 of 6 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-29 CD2-29 ROT - DRILLING Doyon Doyon 19 Date From - To Hours Code Sub Phase Code 9/26/2002 09:45 - 11 :15 1.50 CEMENT PUMP SURFAC 11:15 -12:00 0.75 CEMENT DISP SURFAC 12:00 - 12:30 12:30 - 13:00 13:00 - 14:00 14:00 - 16:00 0.50 CEMENT PULD SURFAC 0.50 CASE RURD SURFAC 1.00 DRILL PULD SURFAC 2.00 WELCTL NUND SURFAC 16:00 - 18:00 2.00 WELCTL NUND SURFAC 18:00 - 21 :00 3.00 WELCTL BOPE SURFAC 21 :00 - 21 :30 0.50 DRILL PULD SURFAC 21 :30 - 00:00 2.50 DRILL PULD SURFAC 9/27/2002 00:00 - 01 :30 1.50 DRILL TRIP SURFAC 01 :30 - 02:00 0.50 DRILL CIRC SURFAC 02:00 - 03:00 1.00 CASE DEQT SURFAC 03:00 - 04:30 1.50 CEMENT DSHO SURFAC 04:30 - 05:00 0.50 CEMENT FIT SURFAC 05:00 - 05:30 0.50 CEMENT FIT SURFAC 05:30 - 00:00 18.50 DRILL DRLG INTRM1 9/28/2002 00:00 - 02:30 2.50 DRILL DRLG INTRM1 02:30 - 03:30 1.00 DRILL CIRC INTRM1 03:30 - 05:30 2.00 DRILL WIPR INTRM1 05:30 - 07:00 1.50 RIGMNT RSRV INTRM1 07:00 - 08:30 1.50 DRILL TRIP INTRM1 08:30 - 09:00 0.50 DRILL CIRC INTRM1 09:00 - 16:45 7.75 DRILL DRLG INTRM1 Spud Date: 9/24/2002 End: 100/2002 Group: Start: 9/24/2002 Rig Release: 100/2002 Rig Number: 19 Description of Operations Push spacer, 340 sxs (275 bbls) lead cmt AS Lite 3 @ 10.7 ppg and 231 sxs (45 bbls) of 15.8 ppg tail cmt - G wI adds. Dropped top plug with 20 bbls of FW from Dowell, switched to rig pumps and displaced with 180.2 bbls of 9.7 ppg mud @ 8-9 bpm - bumped plugs to 1000 psi - floats held - CIP @ 1140 hrs. Full returns throughout job with 82 bbls of 10.7 ppg cement returns to surface. Flush riser, LD cement head and LJ. RD Casing running equipment. ND surface conducter I riser assembly. Attemped to install Unibody wellhead onto mandrel hanger, unable to seat for proper M/M seal. Pulled wellhead off and changed out secondary seal. Changed saver sub to 4" XT-39. Installed wellhead, no problems, tested M/M seal to 1000 psi for 10 min. NU 13 5/8" 5k BOPE. Set test plug, test Pipe and Blind rams, choke and kill line valves, IBOP and floor safety valves to 250 I 5000 psi. Tested annular preventer to 2150 I 3500 psi. chuck Scheve (AOGCC) waived witnessing tests. Pull test plug and install wear bushing. Hang drilling bails - RU 5" running tools. MU BHA #2 - initialize LWD. Tested choke manifold valves 205 I 5000 psi while MU bha. Change out drilling jars, run hwdp, change running tools to 4". RIH, tag cement @ 2570'. MU TD, fill pipe and circ. RU and test casing to 2550 psi ble off to 2515 psi in 30 min. RD I blow down lines. Drill out cmt - wiper plugs - FC @ 2584' - cmt to shoe - drill out of shoe @ 2672' - clean out rathole to 2782' and drill 20' of new hole to 2702'. Circ hole clean for FIT 504 gpm I 1820 psi. RU and perform FIT to 16.0 psi, AWM=9.5 ppg - applied 800 psi surface pressure. Drill from 2702' to 4842' (3981' tvd). ART =9.58 AST =0.43 PUW 160k SOW 130k ROT 145k Torque= 9000/on 7500/off @ 100 rpm 646 gpm I 3050 psi Changed over to 9.4 ppg LSND mud while drilling ahead from 2702'. Pumped 35 bbls 180 tv sweeps every 300-400', 2x cuttings increase with sweeps back. Drill from 4842' to 5225' (4207 tvd) ART =1.9 AST =0 PUW 165k SOW 130k ROT 145k 646 gpm I 2850 psi I 100 rpm Pumped (2) 40 bbl 250 fv sweeps circ hole clean - 646 gpm I 100 rpm. Flow check well, static. Wipe hole to shoe (5-1 Ok) drag, proper hole fill, no problems. Slip and cut drilling line, service TD and drawworks -adjust brake bands. RIH to 5130', no problems. Precautionary ream last stand down, circ hole clean, 650 gpm I 100 rpm - heavy volume of cuttings thru first BU, initial ECD=11.1 ppg, final ECD=10.3 ppg. Drill from 5225' to 6178'. PUW 188K SOW 140K ROT 160K Printed: 10/23/2002 4:23:12 PM ) ) ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-29 CD2-29 ROT - DRILLING Doyon Doyon 19 Date From - To Hours Code Sub Phase Code 9/28/2002 09:00 - 16:45 7.75 DRILL DRLG INTRM1 16:45 - 17:30 0.75 RIGMNT RSRV INTRM1 17:30 - 00:00 6.50 DRILL DRLG INTRM1 9/29/2002 00:00 - 13:00 13.00 DRILL DRLG INTRM1 13:00 - 14:00 1.00 DRILL CIRC INTRM1 14:00 - 18:00 4.00 DRILL WIPR INTRM1 18:00 - 18:30 0.50 DRILL CIRC INTRM1 18:30 - 00:00 5.50 DRILL DRLG INTRM1 9/30/2002 00:00 - 00:00 24.00 DRILL DRLG INTRM1 10/1/2002 00:00 - 04:15 4.25 DRILL DRLG INTRM1 04:15 - 05:30 1.25 DRILL CIRC INTRM1 05:30 - 08:30 3.00 DRILL WIPR INTRM1 08:30 - 10:30 2.00 DRILL CIRC INTRM1 10:30 - 16:30 6.00 DRILL TRIP INTRM1 16:30 - 17:30 1.00 DRILL PULD INTRM1 17:30 - 19:15 1.75 CASE OTHR INTRM1 19:15 - 20:15 1.00 CASE RURD INTRM1 20: 15 - 20:30 0.25 CASE SFTY INTRM1 20:30 - 00:00 3.50 CASE RUNC INTRM1 10/2/2002 00:00 - 00:30 0.50 CASE RUNC INTRM1 Page 3 of 6 Spud Date: 9/24/2002 End: 10/7/2002 Group: Start: 9/24/2002 Rig Release: 1 on /2002 Rig Number: 19 Description of Operations 646 GPM 12680 PSI / 100 RPM TD swivel packing / wash pipe leaking, set back one stand. Change out wash pipe and packing, circ and check for leaks. Drill from 6178' to 6846' (5491' tvd) ART=7.22 AST=1.48 (5225'- 6846') PUW 200k SOW 145k ROT 165k 646 gpm / 2850 psi I 100 rpm Torque 11000 on I 10000 off Drill from 6846' to 7993' (6345' tvd) ART = 5.1 AST =3.57 PUW 225 SOW 150 ROT 175 575 gpm I 2600 psi / 70 rpm Torque 12500 on I 10500 off Backream each stand one time, pupmed 40 bbl sweeps every 400-500' with slight increase in cuttings with sweeps back. Pumped 40 bbls 180 fv sweep and circ hole clean 650 gpm 13350 psi I 100 rpm. Wipe hole to 5129', worked thru tight spots from 7500' - 7050' 20-45k over and from 5275' to 5225' 20-40k over. RIH to 7897', no problems. Precautionary wash and ream from 7897' to 7993', circ to clean hole. Drill from 7993' to 8244' (6538' tvd) ART =0.53 AST =2.36 PUW 220 SOW 155 ROT 180 546 gpm I 2580 psi I 70 rpm Begin 6 / 100 build and turn @ 8089'. Drill from 8244' to 8695' (7107' tvd) ART=1.47 AST=13.97 PUW 210k SOW 165k ROT 188k 546 gpm /2850 psi Torque 11000 on / 9000 off Difficult to hold toolface on course from 8244' to 8406' (Albian-96) ROP 25-45 fph. ROP below 8406' - 60-100 fph Back ream each stand one time. Drill from 9305' to 9566' (7137' tvd) csg. pt. ART =1.0 AST =0.8 PUW 21 Ok SOW 165k ROT 185k 546 gpm / 2680 psi I 60 rpm Torque 11000 on I 9500 off Pump 40 bbls 300 tv sweep and circ hole clean - 600 gpm I 2800 psi I 100 rpm. Flow check well, static. Wipe hole to 7868' 5-15k drag - worked through tight spot @ 8013' 20-40k over. Flow check well, static. RIH - work pipe one time to pass 8891', no other problems. Precautionary ream last stand, pumped 40 bbls 300 fv sweep and circ hole clean 600 gpm I 2800 psi I 100 rpm. Flow check well, static. Pump out 3 stands and POH to 6900' 5-15k drag. Flow check well, static - pump dry job. POH to 2500' 5-10k drag, flow check well, static. POH - flow check at BHA, static. Stand back hwdp and NMCSDC's. Lay down remainder of BHA. Change pipe rams to 7", LD drilling bails, MU fill up tool- pull wear bushing. Set test plug and Jnt - test top pipe rams to 250/5000 psi. Pull test plug and install thin wall wear bushing. Hang long bails, RU slips, elevators and casing tongs. Held Pre-job safety and opts meeting with crew. MU shoe track and BakerLok first 4 joints - fill pipe, check floats. Run 7' casing, 3520' (85 joints ran) @ midnight. Run casing to 3980' (95 jts total) PUW 155k SOW 135k Printed: 10/23/2002 4:23:12 PM ) ) ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 10/2/2002 00:30 - 01 :00 0.50 CASE CIRC INTRM1 01 :00 - 03:00 2.00 CASE RUNC INTRM1 03:00 - 04:00 1.00 CASE CIRC INTRM1 04:00 - 06:30 2.50 CASE RUNC INTRM1 06:30 - 08:45 2.25 CASE CIRC INTRM1 08:45 - 14:00 5.25 CASE RUNC INTRM1 14:00 - 14:30 14:30 - 16:15 0.50 CASE RURD INTRM1 1.75 CEMENTCIRC INTRM1 16:15 - 16:45 0.50 CEMENT PUMP INTRM1 16:45 - 18:00 1.25 CEMENTDISP INTRM1 18:00 - 18:30 0.50 CEMENT PULD INTRM1 18:30 - 19:30 1.00 CASE PTCH INTRM1 19:30 - 20:30 1.00 CASE NUND INTRM1 20:30 - 23:30 3.00 CASE INTRM1 23:30 - 00:00 0.50 DRILL PULD INTRM1 10/3/2002 00:00 - 02:30 2.50 DRILL PULD INTRM1 02:30 - 06:45 4.25 DRILL TRIP INTRM1 06:45 - 07:45 1.00 RIGMNT RSRV INTRM1 07:45 - 08:45 1.00 DRILL TRIP INTRM1 08:45 - 10:00 1.25 CASE DEQT INTRM1 10:00 - 14:45 4.75 CEMENT DSHO INTRM1 Page 40f 6 Spud Date: 9/24/2002 End: 10/7/2002 Group: Start: 9/24/2002 Rig Release: 10/7/2002 Rig Number: 19 Description of Operations Circ and cond mud @ 6 bpm ICP= 510 psi I FCP=450. Run casing to 6029' (145 jts total) PUW 210k SOW 155k Stage pumps up to 6.0 bpm and cond mud ICP=620 psi FCP=520 psi. Maintain mud wt. in @ 9.6 ppg - peak mud wt. out 10.4 ppg - final 9.7 ppg. Run casing to 8084' (194 jts total) had good returns untill # 194 - no returns. MU jnt # 195. PUW 275k SOW 170k Attempt to circ @ 2.0 bpm - no returns, reciprocate pipe from 8125' - 8050'. Continue to pump @ 2.0 - 2.5 bpm adding 5 ppb Mix II fine LCM to suction pit. Established partial returns- increased from slight to 30 % - no change in PO or SO wt's. Lost 260 bbls of mud. Run casing to 9152' (220 jts total) PU & SO WT.'s stable @ 300k up and 175k down. Run casing from 9152'- SOW dropped 35-55k, pumped down last 9 jts with slight returns - SOW 150-120k. MU hanger and LJ, landed Casing with FS @ 9556', FC @ 9470'. Last 60' to bottom SOW improved 165k - 140k with an increase in returns to 25%. Lost 345 bbls of mud. Ld fill-up tool, blow down TD, MU cement head. Staged pumps up to 4 bpm as returns increased from 25% to 80%. Conditioned mud for cementing, maintained 9.6 ppg mud wt wI 5 ppb LCM additions, peak mud wt out= 10.4 ppg. PUW 320 SOW 175- PJSM. Line up to cementers, pumped 5 bbls of Arco wash and test lines to 3500 psi. Pumped additional 15 bbls of Arco wash @ 4.1 bpm / 700 psi - 50 bbls of 12.5 ppg MudpushXL spacer @ 4.1 bpm I 625 psi - dropped bottom plug and pumped 34 bbls of (168 sxs) of 15.8 ppg G cmt wladds @ 4.0 bpm 600 psi. Dropped top plug - pumped 20 bbls of FW from cementers - switch to rig pumps and displace with 339 bbls of 9.6 ppg LSND mud @ 6 bpm / 240-610 psi. slowed pumps to 5 bpm last 10 bbls 540 - 610 psi. Reciprocated pipe untilllast 20 bbls of displacement, bumped plugs to 1000 psi, floats held, CIP @ 1750 hrs. Flow check annulus static. Maintained 80% returns while cementing -lost 398 bbls of mud while circulating and cementing - total losses for day = 1003 bbls. RD cement head and lines, lay down LJ. Pull thin wall wear bushing, install and test 9 5/8" X 7" packoff to 5000 psi for 10 min. Change top pipe rams to 31/2" X 6" VBR, clear casing tools from rig floor. Install test plug and test BOPE 250/5000 psi, Annular preventor 250/3500 psi. Perform Accumulator test, Chuck Scheve (AOGCC) waived witnessing tests. Pull test plug and install wear bushing. MU BHA #3. MU BHA #3 - scribe tools - initialize LWD. PU 3 NMCSDC's, hwdp and jars. Shallow test tools. RIH picking up 4" DP to 3427' (96 jts), continue to RIH to 8008', fill pipe every 20 stds. Slip and cut 60' of drilling line - service top drive. RIH - tagged cement @ 9340' - establish circ. RU and test casing to 3500 psi for 30 min. RD & blow down lines. Clean out cement stringers from 9340', firm @ 9390' - drill out cement wiper plugs and FC @ 9470'. drill out cement to shoe @ 9556'. Clean Printed: 10/23/2002 4:23: 12 PM ) } ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD2-29 Common Well Name: CD2-29 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 10/3/2002 10:00 - 14:45 4.75 CEMENT DSHO INTRM1 14:45 - 16:00 1.25 CEMENT LOT INTRM1 16:00 - 18:15 2.25 CEMENT LOT INTRM1 18:15 - 20:00 1.75 DRILL CIRC PROD 20:00 - 00:00 4.00 DRILL DRLH PROD 10/4/2002 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 1 0/5/2002 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 1 0/6/2002 00:00 - 04:00 4.00 DRILL DRLH PROD 04:00 - 07:00 3.00 DRILL CIRC PROD 07:00 - 09:30 2.50 DRILL CIRC PROD 09:30 - 12:30 3.00 DRILL TRIP PROD 12:30 - 17:30 5.00 DRILL TRIP PROD 17:30 - 18:30 1.00 DRILL PULD PROD 18:30 - 19:30 1.00 CMPL TN RURD CMPL TN Page 5 of 6 Spud Date: 9/24/2002 End: 10/7/2002 Group: Start: 9/24/2002 Rig Release: 10n/2002 Rig Number: 19 Description of Operations out rathole and drill 20' of new hole to 9586'. Circ hole clean for LOT - 200 gpm I 950 psi I 80 rpm Flow check well, static. RU and perform LOT - discuss data with Drilling Engineer. Rerun LOT to confirm data - consult Drilling Engineer determined Leak off > 11.5 ppg proposed to drill ahead. PJSM. Pumped 40 bbls high vis pill followed by FloPro drill in fluid. Change well over to 8.8 ppg FloPro pumping 210 gpm I 1010 psi I 100 rpm. Flow check well, static. Drill 6 1/8" hole from 9586' to 9746' (7137" tvd) ART=2.3 AST=0.7 PUW 205k SOW 162k ROT 183 210gpm/1300psi/110rpm ECD=10.1 ppg Torque 10000 on I 8500 off Drill from 9746' to 10299' (7147' tvd) ART=5.9 AST=3 PUW 200k SOW 155k ROT 175k 210 gpm 1 1380 psi 1 110 rpm ECD= 10.1-10.2 ppg Torque 1000010n 900010ff Maintaining whole mud dillution schedule of 200 bbls 1 500' new hole Drill from 10299' to 10910' (7140.5' tvd) ART=5.4 AST= 2.1 PUW 200k SOW 155k ROT 175k 210 gpm 1 1520 psi I 110 rpm ECD=1 0.1-1 0.2 ppg Tourque 1050010n 900010ff Drilled from 10910' to 11539' (7137' tvd) ART =8.7 AST =2.2 PUW 205k SOW 155k ROT 175k 210 gpm I 1550 psi 1 100 rpm ECD= 10.1-10.3 ppg Torque 10500 on I 9500 off 5-10k WOB Continue 200 bbls whole mud dilutions 1 500' of new hole Drill from 11539' to 12250' (7143' tvd) ART=7.8 AST=1.3 PUW 205K SOW 150k ROT 180k 197 gpm 1 1500 psi I 80 rpm ECD= 10.3-106 ppg Torque 10500 on I 9500 off Encounterd 80-100 bph losses @ 11658', added 2 ppb MIX" fine & MI Seal (fine) to suction pit. Losses slowed to 45 bph shortly after LCM around bit. Observed slight breathing during connections - % flow indicator to zero in 3.5 min. Continued 2 ppb LCM additions - losses < 15 bph from 12015' to 12250', well static @ connections. Total losses to hole = 226 bbls. Drill from 12250' to 12560' (7127' tvd) ART =3.3 AST =0.5 PUW 205k SOW 150k ROT 175k ECD= 10.2-10.4 ppg 197 gpm I 1550 psi 1100 rpm Torque 10500 I on 9500 I off Full returns - well static @ connections Circ hole clean - pumped 40 bbls 180 fv sweep I 300 bbls of mud I 30 bbls 8.8 ppg brine I 50 bbls 180 fv sweep - circ low/high sweeps around - 210 gpm I 1600 psi 1 100 rpm. PJSM. Changed well over to brine - Pumped 40 bbl push pill followed by 8.8 ppg kcl brine - staged 40 bbl high vis pill into change over. Displaced pill into open hole. Monitor well- initial losses 10-15 bph. POH to 9122' (225-250k PUW) monitor well- static losses @ 12 bph. POH to 4349' - LD 125 joints of 4" drill pipe - stand back hwdp. Losses @ 8 bph. LD remainder of BHA. Pull wear bushing - RU to run 41/2" tubing. Printed: 10/23/2002 4:23:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10/6/2002 1 0/7/2002 ) ) Page 6 of 6 ConocoPhillips Alaska Operations Summary Report CD2-29 CD2-29 ROT - DRILLING Doyon Doyon 19 Date From - To Hours Code Sub Phase Code 19:30 - 19:45 19:45 - 00:00 00:00 - 03:00 03:00 - 03:30 03:30 - 05:30 05:30 - 06:00 06:00 - 08:30 08:30 - 10:30 10:30 - 12:00 0.25 CMPL TN SFTY CMPL TN 4.25 CMPL TN RUNT CMPL TN 3.00 CMPL TN RUNT CMPL TN 0.50 CMPL TN SEQT CMPL TN 2.00 CMPL TN NUND CMPL TN 0.50 CMPL TN NUND CMPL TN 2.50 CMPL TN FRZP CMPL TN 2.00 CMPL TN PCKR CMPL TN 1.50 CMPL TN RURD CMPL TN Spud Date: 9/24/2002 End: 10/7/2002 Group: Start: 9/24/2002 Rig Release: 10/7/2002 Rig Number: 19 Description of Operations Held safety and operations meeting with crews. Run 41/2" Completion: WLEG -10' pup - XN nipple wI RHC plug installed - 2 jts 41/2" tubing - Baker S-3 packer assy wI MO ext. - 2 jts tbg - Camco KGB-2 GLM assy wI dummy - 137 jts tubing (6214' @ midnight). All tubing ran: 41/2",12.6 ppf, L-80, IBTM BakerLok all couplings below packer. Staic loss rate = 6 bph Toal brine losses = 104 bbls Continue running Completion: 17 jts tbg- Camco DB nipple - 51 jts tbg - FMC hanger wI M/M seals- PU LJa - land tbg in wellhead with WLEG @ 9026', XN nipple @ 9014', Pkr @ 8906', GLM @ 8796' and DB nipple @ 2240'. RILDS - LD LJa. Lost 15 bbls of brine. Set TWC- PU LJb - test hanger M/M seals to 5000 psi - LD LJb. ND BOPE - NU adapter flange and tree - test tree to 5000 psi - changed TD saver sub to 4112 IF. Pull TWC- RU circ manifold and hardlines to tubing and annulus on wellhead. PJSM. Test lines to 3800 psi - pumped 125 bbls of 9.2 ppg kcl brine @ 3 bpm 160 psi - switch to Dowell and pumped 180 bbls of diesel @ 2.5 bpm I 450-850 psi. RU lubricator and drop setting ball & rod. Retest lines to 3800 psi. Pressure up to 3500 psi - set pkr and test tubing - bled to 3240 psi in 30 min. Bled off tubing to 775 psi - test 4 1/2" x 7' annulus to 3510 psi, bled off to 3425 psi in 30 min. Blow down lines, RD hard pipe and circ manifold. RU FMC lubricator and install BPV. SITP=625 psi. Secure wellhead - released rig @ 1200 hrs. Printed: 10/23/2002 4:23:12 PM ) " ) Phillips Alaska, Inc. CD2-29 (Final Surveys) MD Inc Azim. SSTVD TVD N/S E/W V X DLS v.s. Comment 72.00 0.05 44.00 19.45 72.00 0.02 N 0.02 E 5974502.65 N 371711.28 E 0.07 -0.01 164.00 0.30 14.00 111 .45 164.00 0.29 N 0.11 E 5974502.91 N 371711.37E 0.28 -0.20 254.00 0.25 324.00 201.45 254.00 0.67 N 0.05 E 5974503.30 N 371711.32 E 0.26 -0.57 341.00 0.50 56.00 288.45 341.00 1.04 N 0.25 E 5974503.66 N 371711.53 E 0.65 -0.80 382.55 1.04 79.95 329.99 382.54 1.21 N 0.77 E 5974503.82 N 371712.06 E 1.49 -0.70 472.05 2.57 73.51 419.45 472.00 1.92 N 3.50 E 5974504.49 N 371714.79 E 1.72 -0.04 563.46 4.17 70.78 510.70 563.25 3.59 N 8.60 E 5974506.08 N 371719.92 E 1.76 0.89 652.38 6.19 74.93 599.25 651.80 5.90 N 16.29 E 5974508.25 N 371727.64 E 2.31 2.48 741.78 6.54 74.42 688.10 740.65 8.52 N 25.84 E 5974510.71 N 371737.25 E 0.40 4.68 832.89 9.19 75.15 778.34 830.89 11.78 N 37.88 E 5974513.76 N 371749.33 E 2.91 7.48 922.74 11.09 73.25 866.79 919.34 16.11 N 53.09 E 5974517.83 N 371764.62 E 2.15 10.84 1017.02 15.06 64.39 958.61 1011.16 24.02 N 72.83 E 5974525.41 N 371784.49 E 4.71 13.18 1111.78 21.02 62.05 1048.67 1101.22 37.32 N 98.96 E 5974538.26 N 371810.85 E 6.34 13.78 1205.90 25.47 65.98 1135.14 1187.69 53.48 N 132.38 E 5974553.84 N 371844.53 E 5.01 15.30 1300.90 26.09 67.97 1220.68 1273.23 69.63 N 170.40 E 5974569.34 N 371882.83 E 1.12 19.00 1395.75 28.05 67.52 1305.14 1357.69 85.99 N 210.35 E 5974585.00 N 371923.05 E 2.08 23.42 1488.62 31.62 66.45 1385.69 1438.24 104.07 N 252.85 E 5974602.36 N 371965.86 E 3.89 27.53 1587.10 35.14 65.80 1467.91 1520.46 126.01 N 302.39 E 5974623.44 N 372015.76 E 3.59 31.56 1680.54 35.90 65.21 1543.96 1596.51 148.52 N 351.79 E 5974645.11 N 372065.53 E 0.89 35.02 1776.89 37.56 64.74 1621.18 1673.73 172.89 N 403.99 E 5974668.59 N 372118.15 E 1.75 38.15 1872.23 39.71 64.51 1695.65 1748.20 198.41 N 457.77 E 5974693.17 N 372172.36 E 2.26 41.03 1966.44 40.15 65.49 1767.89 1820.44 223.96 N 512.58 E 5974717.79 N 372227.59 E 0.82 44.36 2062.78 40.51 65.19 1841.33 1893.88 249.97 N 569.24 E 5974742.83 N 372284.69 E 0.43 48.15 2156.63 40.47 64.59 1912.71 1965.26 275.83 N 624.42 E 5974767.74 N 372340.30 E 0.42 51.38 2251.81 40.40 64.57 1985.16 2037.71 302.33 N 680.17 E 5974793.28 N 372396.51 E 0.08 54.32 2345.05 40.84 66.00 2055.93 2108.48 327.71 N 735.31 E 5974817.71 N 372452.07 E 1.10 57.96 2443.61 41.42 66.93 2130.17 2182.72 353.59 N 794.75 E 5974842.57 N 372511.94 E 0.86 63.18 2538.55 40.78 69.08 2201.71 2254.26 376.97 N 852.61 E 5974864.96 N 372570.19 E 1.63 69.87 2624.14 41.30 68.02 2266.27 2318.82 397.52 N 904.91 E 5974884.61 N 372622.84 E 1.02 76.42 2761.46 41.48 67.85 2369.29 2421.84 431.63 N 989.05 E 5974917.27 N 372707.55 E 0.16 86.04 2857.11 42.63 66.73 2440.31 2492.86 456.37 N 1048.15 E 5974941.00 N 372767 ~07 E 1.44 92.11 2952.75 41.05 64.97 2511.57 2564.12 482.45 N 1106.36 E 5974966.08 N 372825.72 E 2.06 96.58 3048.13 41.00 64.20 2583.52 2636.07 509.32 N 1162.91 E 5974991.98 N 372882.71 E 0.53 99.56 3143.79 40.86 63.42 2655.80 2708.35 536.98 N 1219.15 E 5975018.67 N 372939.42 E 0.55 101.71 3238.75 40.91 63.55 2727.59 2780.14 564.73 N 1274.76 E 5975045.47 N 372995.50 E 0.10 103.48 3334.02 41.46 63.54 2799.29 2851.84 592.68 N 1330.93 E 5975072.45 N 373052.13 E 0.58 105.34 3429.38 41.29 62.93 2870.84 2923.39 621.06 N 1387.21 E 5975099.87 N 373108.89 E 0.46 106.86 3524.94 41.42 63.13 2942.57 2995.12 649.69 N 1443.48 E 5975127.53 N 373165.64 E 0.19 108.16 3619.94 41.55 62.35 3013.74 3066.29 678.52 N 1499.42 E 5975155.40 N 373222.07 E 0.56 109.14 3715.10 41.38 61.81 3085.05 3137.60 708.02 N 1555.10 E 5975183.94 N 373278.24 E 0.42 109.39 3810.23 41.88 63.71 3156.16 3208.71 736.94 N 1611.28 E 5975211.90 N 373334.91 E 1.43 110.40 3905.92 42.19 64.62 3227.23 3279.78 764.86 N 1668.95 E 5975238.83 N 373393.05 E 0.71 112.99 4002.61 41.99 63.64 3298.99 3351.54 793.14 N 1727.26 E 5975266.10 N 373451.84 E 0.71 115.57 4097.99 42.02 63.04 3369.86 3422.41 821.78 N 1784.30 E 5975293.76 N 373509.36 E 0.42 117.23 4193.10 42.11 63.08 3440.47 3493.02 850.65 N 1841.11 E 5975321.65 N 373566.66 E 0.10 118.57 4288.45 41.55 65.60 3511.52 3564.07 878.19 N 1898.42 E 5975348.21 N 373624.42 E 1.86 121.33 4383.98 41.28 66.19 3583.16 3635.71 903.99 N 1956.10 E 5975373.03 N 373682.54 E 0.50 125.79 4479.85 41.20 65.94 3655.25 3707.80 929.63 N 2013.86 E 5975397.67 N 373740.73 E 0.19 130.43 4575.23 41.00 65.67 3727.13 3779.68 955.33 N 2071.06 E 5975422.39 N 373798.36 E 0.28 134.76 4670.11 40.97 65.82 3798.75 3851.30 980.89 N 2127.79 E 5975446.98 N 373855.52 E 0.11 138.98 4765.94 41.48 65.80 3870.83 3923.38 1006.77 N 2185.40 E 5975471.87 N 373913.56 E 0.53 143.34 4860.54 41.46 64.53 3941.71 3994.26 1033.08 N 2242.25 E 5975497.20 N 373970.86 E 0.89 146.97 4956.04 41.48 64.92 4013.27 4065.82 1060.09 N 2299.44 E 5975523.22 N 374028.50 E 0.27 150.14 5052.12 41.58 65.12 4085.20 4137.75 1086.99 N 2357.18 E 5975549.13 N 374086.69 E 0.17 153.66 5145.03 41.42 64.50 4154.78 4207.33 1113.19 N 2412.89 E 5975574.37 N 374142.84 E 0.48 156.84 5241.81 41.44 64.31 4227.35 4279.90 1140.86 N 2470.65 E 5975601.05 N 374201.06 E 0.13 159.70 5336.77 41.60 64.14 4298.45 4351.00 1168.23 N 2527.33 E 5975627.45 N 374258.21 E 0.21 162.30 5433.58 41.51 63.23 4370.89 4423.44 1196.69 N 2584.89 E 5975654.92 N 374316.25 E 0.63 164.36 5529.10 41.20 63.21 4442.59 4495.14 1225.13 N 2641.24 E 5975682.39 N 374373.07 E 0.33 165.87 5624.76 41.07 62.06 4514.64 4567.19 1254.05 N 2697.12 E 5975710.36 N 374429.44 E 0.80 166.73 5720.00 42.22 65.05 4585.82 4638.37 1282.21 N 2753.78 E 5975737.54 N 374486.57 E 2.41 168.63 CD2-29 (Final Surveys) Page 1 of 3 ) Phillips Alaska, Inc. CD2-29 (Final Surveys) MD Inc Azim. SSTVD TVD N/S E/W Y X DLS v.s. Comment 5910.86 41.98 65.31 4726.96 4779.51 1335.69 N 2870.59 E 5975789.02 N 374604.29 E 0.61 176.59 6006.57 41.61 64.75 4798.32 4850.87 1362.62 N 2928.42 E 5975814.95 N 374662.56 E 0.55 180.13 6101.59 41.25 63.82 4869.56 4922.11 1389.90 N 2985.07 E 5975841.26 N 374719.67 E 0.75 182.80 6197.40 41.12 65.51 4941.67 4994.22 1416.90 N 3042.08 E 5975867.27 N 374777.14 E 1.17 185.90 6292.50 40.47 64.74 5013.66 5066.21 1443.03 N 3098.45 E 5975892.44 N 374833.95 E 0.86 189.45 6388.03 39.98 65.19 5086.60 5139.15 1469.14 N 3154.35 E 5975917.58 N 374890.28 E 0.60 192.80 6483.24 40.64 65.53 5159.20 5211.75 1494.81 N 3210.33 E 5975942.30 N 374946.70 E 0.73 196.58 6578.86 40.30 65.76 5231.95 5284.50 1520.41 N 3266.87 E 5975966.92 N 375003.67 E 0.39 200.68 6674.49 39.68 64.64 5305.21 5357.76 1546.18 N 3322.66 E 5975991.74 N 375059.89 E 0.99 204.28 6769.67 40.45 64.14 5378.06 5430.61 1572.66 N 3377.90 E 5976017.27 N 375115.58 E 0.88 206.99 6865.32 41.45 63.74 5450.30 5502.85 1600.21 N 3434.22 E 5976043.85 N 375172.35 E 1.08 209.28 6960.99 41.82 63.64 5521.80 5574.35 1628.38 N 3491.20 E 5976071.04 N 375229.80 E 0.39 211.32 7056.39 40.77 63.26 5593.48 5646.03 1656.52 N 3547.51 E 5976098.21 N 375286.60 E 1.13 213.08 7152.04 41.29 63.19 5665.63 5718.18 1684.80 N 3603.57 E 5976125.53 N 375343.13 E 0.55 214.58 7247.27 41.04 63.82 5737.32 5789.87 1712.77 N 3659.67 E 5976152.53 N 375399.70 E 0.51 216.39 7342.94 42.98 66.76 5808.41 5860.96 1739.50 N 3717.83 E 5976178.26 N 375458.31 E 2.89 220.26 7438.53 42.12 66.75 5878.83 5931.38 1765.01 N 3777 .23 E 5976202.76 N 375518.13 E 0.90 225.79 7534.36 41.59 65.94 5950.21 6002.76 1790.66 N 3835.80 E 5976227.40 N 375577.13 E 0.79 230.80 7629.82 42.01 64.68 6021.37 6073.92 1817.24 N 3893.60 E 5976252.99 N 375635.38 E 0.98 234.64 7725.39 41.13 64.62 6092.87 6145.42 1844.39 N 3950.91 E 5976279.15 N 375693.15 E 0.92 237.74 7820.85 41.20 65.07 6164.74 6217.29 1871.10 N 4007.78 E 5976304.89 N 375750.47 E 0.32 241.02 7915.29 41.93 65.83 6235.40 6287.95 1897.13 N 4064.78 E 5976329.94 N 375807.90 E 0.94 244.96 8010.19 42.25 66.01 6305.82 6358.37 1923.08 N 4122.85 E 5976354.89 N 375866.41 E 0.36 249.48 8105.45 41.33 65.70 6376.85 6429.40 1949.05 N 4180.78 E 5976379.86 N 375924.78 E 0.99 253.91 8135.13 41.27 65.94 6399.14 6451.69 1957.07 N 4198.65 E 5976387.58 N 375942.78 E 0.57 255.27 8165.93 41.26 69.14 6422.30 6474.85 1964.83 N 4217.42 E 5976395.02 N 375961.68 E 6.85 257.28 8200.21 41.39 71.13 6448.04 6500.59 1972.52 N 4238.71 E 5976402.34 N 375983.09 E 3.85 260.54 8230.51 41.78 73.16 6470.71 6523.26 1978.68 N 4257.85 E 5976408.18 N 376002.34 E 4.63 264.14 8261.45 42.83 75.57 6493.59 6546.14 1984.29 N 4277.90 E 5976413.44 N 376022.48 E 6.25 268.65 8294.58 43.42 77.53 6517.77 6570.32 1989.56 N 4299.92 E 5976418.33 N 376044.59 E 4.42 274.40 8330.98 44.05 79.41 6544.07 6596.62 1994.58 N 4324.58 E 5976422.93 N 376069.33 E 3.97 281.60 8362.42 44.70 81.67 6566.55 6619.10 1998.20 N 4346.26 E 5976426.17 N 376091.07 E 5.44 288.65 8392.10 44.71 82.73 6587.64 6640.19 2001.03 N 4366.95 E 5976428.65 N 376111 .81 E 2.51 295.91 8425.93 44.34 86.11 6611.76 6664.31 2003.34 N 4390.55 E 5976430.56 N 376135.44 E 7.09 305.01 8457.57 44.16 90.06 6634.43 6686.98 2004.08 N 4412.61 E 5976430.92 N 376157.51 E 8.73 314.76 8487.31 44.70 93.53 6655.67 6708.22 2003.42 N 4433.41 E 5976429.91 N 376178.30 E 8.37 325.15 8521.58 45.89 96.98 6679.78 6732.33 2001.18 N 4457.66 E 5976427.25 N 376202.50 E 7.95 338.57 8553.10 46.37 100.18 6701.63 6754.18 1997.79 N 4480.12 E 5976423.48 N 376224.90 E 7.48 352.15 8583.22 47.11 102.64 6722.27 6774.82 1993.45 N 4501.62 E 5976418.77 N 376246.32 E 6.44 366.12 8616.21 46.71 106.38 6744.81 6797.36 1987.42 N 4524.93 E 5976412.34 N 376269.53 E 8.37 382.44 8647.39 47.17 108.37 6766.10 6818.65 1980.61 N 4546.67 E 5976405.17 N 376291.15 E 4.89 398.70 8678.80 48.50 110.58 6787.19 6839.74 1972.85 N 4568.62 E 5976397.03 N 376312.96 E 6.72 415.90 8774.09 52.27 116.02 6847.97 6900.52 1943.75 N 4635.94 E 5976366.78 N 376379.78 E 5.91 473.32 8869.27 56.92 120.46 6903.11 6955.66 1906.99 N 4704.20 E 5976328.86 N 376447.40 E 6.19 537.93 8964.34 62.91 126.16 6950.78 7003.33 1861.76 N 4772.80 E 5976282.46 N 376515.22 E 8.16 610.18 9059.77 67.46 132.00 6990.85 7043.40 1807.14 N 4839.94 E 5976226.70 N 376581.40 E 7.32 690.01 9155.01 73.22 134.17 7022.88 7075.43 1745.88 N 4905.38 E 5976164.33 N 376645.80 E 6.42 774.90 9251.01 78.25 140.97 7046.55 7099.10 1677.24 N 4968.05 E 5976094.62 N 376707.28 E 8.63 864.99 9346.77 82.86 147.19 7062.28 7114.83 1600.78 N 5023.40 E 5976017.23 N 376761.31 E 8.01 958.52 9440.93 84.10 147.12 7072.97 7125.52 1522.18 N 5074.13 E 5975937.78 N 376810.69 E 1.32 1051.75 9486.26 85.45 146.04 7077.10 7129.65 1484.51 N 5099.00 E 5975899.68 N 376834.91 E 3.81 1096.70 9560.57 87.35 146.16 7081.76 7134.31 1422.95 N 5140.36 E 5975837.43 N 376875.21 E 2.56 1170.49 9655.55 88.95 146.04 7084.83 7137.38 1344.16 N 5193.30 E 5975757.74 N 376926.80 E 1.69 1264.94 9750.76 88.40 147.09 7087.03 7139.58 1264.73 N 5245.75 E 5975677.43 N 376977.88 E 1.25 1359.71 9846.54 87.91 148.66 7090.11 7142.66 1183.66 N 5296.65 E 5975595.50 N 377027.39 E 1.72 1455.21 9942.15 88.28 150.23 7093.29 7145.84 1101.38 N 5345.23 E 5975512.39 N 377074.55 E 1.69 1550.68 10035.26 89.38 151.01 7095.19 7147.74 1020.26 N 5390.90 E 5975430.51 N 377118.83 E 1.45 1643.75 10132.99 90.25 152.72 7095.51 7148.06 934.08 N 5436.98 E 5975343.56 N 377163.43 E 1.96 1741.47 10228.55 90.98 153.18 7094.48 7147.03 848.98 N 5480.44 E 5975257.72 N 377205.42 E 0.90 1837.01 10320.67 90.98 152.68 7092.91 7145.46 766.97 N 5522.35 E 5975175.00 N 377245.92 E 0.54 1929.10 10419.26 89.20 153.40 7092.75 7145.30 679.09 N 5567.05 E 5975086.38 N 377289.11 E 1.95 2027.66 10514.73 89.88 153.40 7093.52 7146.07 593.73 N 5609.79 E 5975000.30 N 377330.39 E 0.71 2123.09 CD2-29 (Final Surveys) Page 2 of 3 ) ) 10706.01 90.55 154.02 7091.62 7144.17 421.84 N 5693.68 E 5974827.00 N 377411.32 E 0.46 2314.23 10801.23 90.98 153.30 7090.35 7142.90 336.52 N 5735.92 E 5974740.96 N 377452.10 E 0.88 2409.39 10892.43 91.97 152.98 7088.00 7140.55 255.19 N 5777.12 E 5974658.94 N 377491.90 E 1.14 2500.54 10991.34 90.43 153.88 7085.93 7138.48 166.74 N 5821.35 E 5974569.75 N 377534.61 E 1.80 2599.38 11084.60 90.55 152.70 7085.13 7137.68 83.44 N 5863.26 E 5974485.74 N 377575.09 E 1.27 2692.61 11181.38 88.03 152.95 7086.33 7138.88 2.64 S 5907.45 E 5974398.92 N 377617.81 E 2.62 2789.36 11271.89 89.08 152.35 7088.61 7141.16 83.01 S 5949.02 E 5974317.85 N 377657.99 E 1.34 2879.83 11366.61 90.18 152.81 7089.23 7141.78 167.09 S 5992.64 E 5974233.04 N 377700.17 E 1.26 2974.54 11465.49 91.54 153.74 7087.74 7140.29 255.39 S 6037.10 E 5974143.99 N 377743.11 E 1.67 3073.37 11564.62 87.23 151.86 7088.81 7141.36 343.53 S 6082.40 E 5974055.09 N 377786.89 E 4.74 3172.46 11660.06 87.54 153.13 7093.16 7145.71 428.09 S 6126.43 E 5973969.79 N 377829.47 E 1.37 3267.79 11755.44 88.09 152.77 7096.80 7149.35 512.97 S 6169.77 E 5973884.17 N 377871.35 E 0.69 3363.08 11850.84 88.95 152.42 7099.26 7151.81 597.64 S 6213.67 E 5973798.77 N 377913.79 E 0.97 3458.44 11946.37 90.12 152.79 7100.04 7152.59 682.45 S 6257.62 E 5973713.22 N 377956.29 E 1.29 3553.96 12041.52 90.98 151.90 7099.12 7151.67 766.73 S 6301.78 E 5973628.20 N 377999.00 E 1.30 3649.10 12136.72 92.09 152.72 7096.57 7149.12 850.99 S 6346.00 E 5973543.19 N 378041.77 E 1.45 3744.26 12232.22 92.83 152.60 7092.47 7145.02 935.74 S 6389.82 E 5973457.70 N 378084.14 E 0.79 3839.66 12322.77 91.72 151.21 7088.88 7141.43 1015.56 S 6432.43 E 5973377.17 N 378125.37 E 1.96 3930.13 12422.74 93.26 151.58 7084.54 7137.09 1103.24 S 6480.25 E 5973288.68 N 378171.68 E 1.58 4030.00 12487.69 94.31 152.00 7080.25 7132.80 1160.35 S 6510.88 E 5973231.06 N 378201.34 E 1.74 4094.81 CD2-29 (Final Surveys) Page 3 of 3 a Da-/'-/r 11-0ct-02 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-29 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00 I MD 0.00' M D (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEíVE,D OCT 15 2002 AJaøka O~i & Gas Can~. CVrnzrd_n Anchoœge \X) ~ ¡.... ) ---16 . ~. Sperry-Sun Drilling Services ,,-..., Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-29 Gyro Job No. AKF022162, Surveyed: 6 October, 2002 Survey Report 10 October, 2002 ,~- Your Ref: API 501032042700 Surface Coordinates: 5974502.63 N, 371711.26 E (70° 20' 18.8603" N, 151002'27.5748" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974502.63 N, 128288.74 W (Grid) Surface Coordinates relative to Structure: 59.60 N, 7.25 W(True) Kelly Bushing: 52. 55ft above Mean Sea Level Elevation relative to Project V Reference: 52. 55ft Elevation relative to Structure: 52. 55ft 5p1i!r-'r'Y-SU" DFULLING' s(èAVIc:eS A Halliburton Company DEL"¡;~ '1. I' VE Survey Ref: svy9982 Alaska North Slope Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 0.00 0.000 0.000 -52.55 0.00 72.00 0.050 44.000 19.45 72.00 164.00 0.300 14.000 111.45 164.00 254.00 0.250 324.000 201.45 254.00 /,~ 341.00 0.500 56.000 288.45 341.00 Sperry-Sun Drilling Services Survey Report for AlpIne CD..2 - CD2-29 Gyro Your Ref: API 501032042700 Job No. AKF022162, Surveyed: 6 October, 2002 North Slope, Alaska Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Dogleg Rate (0/100ft) Vertical Section Comment O.OON O.OOE 5974502.63 N 371711.26E 0.00 Tolerable Gyro 0.02 N 0.02E 5974502.65 N 371711.28 E 0.069 -0.01 0.29N 0.11 E 5974502.91 N 371711.37E 0.280 -0.20 0.67N 0.05E 5974503.30 N 371711.32E 0.263 -0.57 1.04 N 0.25E 5974503.66 N 371711.53 E 0.651 -0.80 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.0' MSL. Northings and Eastings are relative to 1855' FNL, 1528 FEL Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1855' FNL, 1528 FEL and calculated along an Azimuth of 151.850° (True). Magnetic Declination at Surface is 24.827°(24-Sep-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 341.00ft., The Bottom Hole Displacement Is 1.07ft., In the Direction of 13.677° (True). Survey tool program for CD2-29 Gvro /~ From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 341.00 341.00 Tolerable Gyro 0.00 10 October, 2002 - 16:19 ---'----'--.--'-'. --~------------ Page 20f2 Dri/lQlIest 3.03.02.002 00 ~ "" , . ~ ro~ Sperry-Sun Drilling Services ~ Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-29 Gyro Job No. AKF022162, Surveyed: 6 October, 2002 Survey Report 10 October, 2002 ~ Your Ref: API 501032042700 Surface Coordinates: 5974502.63 N, 371711.26 E (70° 20' 18.8603- N, 151002' 27.5748" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974502.63 N, 128288.74 W (Grid) Surface Coordinates relative to Structure: 59.60 N, 7.25 W(True} Kelly Bushing: 52. 55ft above Mean Sea Level Elevation relative to Project V Reference: 52. 55ft Elevation relative to Structure: 52. 55ft IlpIIr'I'Y-IIUf1 DR'LLiNG seÀv.ç:es A Halliburton Company )E~~l~ ~ì I. VE Survey Ref: svy9982 Alaska North Slope Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 0.00 0.000 0.000 -52.55 0.00 72.00 0.050 44.000 19.45 72.00 164.00 0.300 14.000 111.45 164.00 254.00 0.250 324.000 201.45 254.00 341.00 0.500 56.000 288.45 341.00 ('~--- Sperry-Sun Drilling Services Survey Report for Alpine CD..2 - CD2-29 Gyro Your Ref: API 501032042700 Job No. AKF022162, Surveyed: 6 October, 2002 Local Coordinates Northings Eastings (ft) (ft) O.OON 0.02N 0.29N 0.67N 1.04 N O.OOE 0.02E 0.11 E 0.05E 0.25E Global Coordinates Northings Eastings (ft) (ft) 5974502.63 N 5974502.65 N 5974502.91 N 5974503.30 N 5974503.66 N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.0' MSL. Northings and Eastings are relative to 1855' FNL, 1528 FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1855' FNL, 1528 FEL and calculated along an Azimuth of 151.850° (True). Magnetic Declination at Surface is 24.827°(24-Sep-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 341.00ft., The Bottom Hole Displacement is 1.07ft., in the Direction of 13.677° (True). Survey tool lJroøram for CD2-29 Gvro <,,-. From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 Survey Tool Description 341.00 341.00 Tolerable Gyro 10 October, 2002 - 16:19 Page 20f2 371711.26 E 371711.28 E 371711.37 E 371711.32 E 371711.53 E Dogleg Rate (0/100ft) 0.069 0.280 0.263 0.651 North Slope, Alaska Vertical Section Comment 0.00 Tolerable Gyro -0.01 -0.20 -0.57 -0.80 ---.--~_._--------_._-----_.~---- Drif/QlIest 3.03.02.002 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-29 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 0.00 I MD (if applicable) 12,560.00' MD ') aoa-/q?j 11-0ct-02 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECEIVED OCT 1 5 AÏaaKm Oii & Gf,'Ç\ {'"'fY' ''>.. . I;!\i Wi ..,," u:¡mml!8ftm Ancnomg(; ~ ~ ""'" é- C(5. Sperry-Sun Drilling Services .~ Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-29 Job No. AKMW22162, Surveyed: 6 October, 2002 Survey Report 10 October, 2002 Your Ref: API 501032042100 Surface Coordinates: 5974502.63 N, 371111.26 E (10020' 18.8603" N, 151002' 27.5748" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project HReference: 914502.63 N, 128288.74 W (Grid) Surface Coordinates relative to Structure: 59.60 N, 7.25 W(True) Kelly Bushing: 52. 55ft above Mean Sea Level Elevation relative to Project V Reference: 52.55ft Elevation relative to Structure: 52.55ft SPP"""Y-IILJrl a f=nL &.. t N G sua Ava c:ìa s A Halliburton Company DEF \J -VE Survey Ref: svy9990 Sperry-Sun Drilling Services Survey Report for Alplhè CD-2 - CD2-29 Your Ref: API 501032042700 Job No. AKMW22162, Surveyed: 6 October, 2002 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 341.00 0.500 56.000 288.45 341.00 1.04 N 0.25E 5974503.66 N 371711.53 E -0.80 MWD Magnetic 382.55 1.040 79.950 329.99 382.54 1.21 N 0.77E 5974503.82 N 371712.05 E 1.486 -0.70 472.05 2.570 73.510 419.45 472.00 1.92 N 3.50E 5974504.49 N 371714.79 E 1.722 -0.04 563.46 4.170 70.780 510.70 563.25 3.59N 8.60E 5974506.08 N 371719.92 E 1.759 0.89 652.38 6.190 74.930 599.25 651.80 5.90N 16.28 E 5974508.25 N 371727.64 E 2.309 2.48 o~ 741.78 6.540 74.420 688.10 740.65 8.52N 25.84 E 5974510.71 N 371737.24 E 0.397 4.68 832.89 9.190 75.150 778.34 830.89 11.78 N 37.88 E 5974513.76 N 371749.33 E 2.911 7.48 922.74 11.090 73.250 866.78 919.33 16.11 N 53.09 E 5974517.83 N 371764.61 E 2.147 10.84 1017.02 15.060 64.390 958.61 1011.16 24.02 N 72.82 E 5974525.40 N 371784.48 E 4.705 13.17 1111 .78 21.020 62.050 1048.67 1101.22 37.32 N 98.96 E 5974538.25 N 371810.85 E 6.335 13.78 1205.90 25.4 70 65.980 1135.14 1187.69 53.48 N 132.38 E 5974553.84 N 371844.53 E 5.005 15.30 1300.90 26.090 67.970 1220.68 1273.23 69.63 N 170.40 E 5974569.34 N 371882.83 E 1.121 19.00 1395.75 28.050 67.520 1305.14 1357.69 85.98 N 210.35 E 5974585.00 N 371923.05 E 2.078 23.42 1488.62 31.620 66.450 1385.69 1438.24 104.07 N 252.85 E 5974602.36 N 371965.86 E 3.886 27.53 1587.10 35.140 65.800 1467.91 1520.46 126.01 N 302.39 E 5974623.44 N 372015.76 E 3.593 31.56 1680.54 35.900 65.210 1543.96 1596.51 148.52 N 351.78 E 5974645.11 N 372065.53 E 0.892 35.02 1776.89 37.560 64.740 1621.18 1673.73 172.89 N 403.99 E 5974668.59 N 372118.15 E 1.747 38.15 1872.23 39.710 64.510 1695.65 1748.20 198.40 N 457.77 E 5974693.17 N 372172.36 E 2.260 41.03 1966.44 40.150 65.490 1767.89 1820.44 223.96 N 512.57 E 5974717.78 N 372227.59 E 0.815 44.36 2062.78 40.510 65.190 1841.33 1893.88 249.97 N 569.24 E 5974742.83 N 372284.69 E 0.425 48.15 2156.63 40.470 64.590 1912.71 1965.26 275.83 N 624.42 E 5974767.74 N 372340.30 E 0.417 51.38 2251.81 40.400 64.570 1985.15 2037.70 302.33 N 680.17 E 5974793.28 N 372396.51 E 0.075 54.32 .~. 2345.05 40.840 66.000 2055.93 2108.48 327.71 N 735.31 E 5974817.71 N 372452.07 E 1.104 57.96 2443.61 41.420 66.930 2130.17 2182.72 353.59 N 794.75 E 5974842.57 N 372511.94 E 0.855 63.18 2538.55 40.780 69.080 2201.71 2254.26 376.97 N 852.61 E 5974864.96 N 372570.19 E 1.634 69.87 2624.14 41 .300 68.020 2266.27 2318.82 397.52 N 904.91 E 5974884.61 N 372622.84 E 1.015 76.42 2761 .46 41.480 67.850 2369.29 2421.84 431.63 N 989.05 E 5974917.27 N 372707.55 E 0.155 86.04 2857.11 42.630 66.730 2440.31 2492.86 456.37 N 1048.15 E 5974941.00 N 372767.07 E 1 .435 92.11 2952.75 41.050 64.970 2511.57 2564.12 482.45 N 1106.36 E 5974966.08 N 372825.72 E 2.058 96.58 3048.13 41 .000 64.200 2583.52 2636.07 509.32 N 1162.91 E 5974991.98 N 372882.71 E 0.532 99.56 3143.79 40.860 63.420 2655.80 2708.35 536.98 N 1219.15 E 5975018.67 N 372939.41 E 0.554 101.71 3238.75 40.910 63.550 2727.59 2780.14 564.73 N 1274.76 E 5975045.47 N 372995.50 E 0.104 103.48 3334.02 41.460 63.540 2799.29 2851.84 592.68 N 1330.93 E 5975072.45 N 373052.13 E 0.577 105.34 3429.38 41.290 62.930 2870.84 2923.39 621.06 N 1387.21 E 5975099.87 N 373108.89 E 0.459 106.86 3!)24.94 41.420 63.130 2942.57 2995.12 649.69 N 1443.48 E 5975127.53 N 373165.64 E 0.194 108.16 ----.-.-----.----.------. ,,---- -.'.m.__.._-.-- ..._--- ~-_._._-_. 10 October, 2002 - 16:25 Page 2 0'6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for A/pi"'. CD-2 . CD2-29 Your Ref: AP/501032042700 Job No. AKMW22162, Surveyed: 6 October, 2002 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3619.94 41.550 62.350 3013.74 3066.29 678.52 N 1499.42 E 5975155.40 N 373222.07 E 0.561 109.14 3715.10 41.380 61.810 3085.05 3137.60 708.02 N 1555.10 E 5975183.94 N 373278.24 E 0.416 109.39 3810.23 41.880 63.710 3156.16 3208.71 736.94 N 1611.28 E 5975211.90 N 373334.91 E 1.427 110.40 3905.92 42.190 64.620 3227.23 3279.78 764.86 N 1668.95 E 5975238.82 N 373393.05 E 0.714 112.99 ~. 4002.61 41.990 63.640 3298.99 3351.54 793.14 N 1727.26 E 5975266.10 N 373451.84 E 0.710 115.57 4097.99 42.020 63.040 3369.86 3422.41 821.78 N 1784.30 E 5975293.76 N 373509.36 E 0.422 117.23 4193.10 42.110 63.080 3440.47 3493.02 850.65 N 1841.11 E 5975321.65 N 373566.65 E 0.099 118.57 4288.45 41.550 65.600 3511.52 3564.07 878.18 N 1898.42 E 5975348.21 N 373624.42 E 1.858 121.33 4383.98 41 .280 66.190 3583.16 3635.71 903.99 N 1956.10 E 5975373.03 N 373682.54 E 0.497 125.79 4479.85 41.200 65.940 3655.25 3707.80 929.63 N 2013.86 E 5975397.67 N 373740.73 E 0.191 130.43 4575.23 41.000 65.670 3727.13 3779.68 955.33 N 2071.06 E 5975422.39 N 373798.36 E 0.280 134.76 4670.11 40.970 65.820 3798.75 3851.30 980.89 N 2127.79 E 5975446.98 N 373855.52 E 0.108 138.98 4765.94 41.480 65.800 3870.83 3923.38 1006.77 N 2185.40 E 5975471.87 N 373913.56 E 0.532 143.34 4860.54 41 .460 64.530 3941.71 3994.26 1033.08 N 2242.25 E 5915497.20 N 373970.86 E 0.889 146.97 4956.04 41 .480 64.920 4013.27 4065.82 1060.09 N 2299.44 E 5975523.22 N 374028.50 E 0.271 150.14 5052.12 41.580 65.120 4085.20 4137.75 1086.99 N 2357.18 E 5975549.13 N 374086.69 E 0.173 153.66 5145.03 41.420 64.500 4154.78 4207.33 1113.19 N 2412.89 E 5975574.37 N 374142.84 E 0.475 156.84 5241.81 41 .440 64.310 4227.35 4279.90 1140.85 N 2470.65 E 5975601.05 N 374201.06 E 0.132 159.70 5336.77 41 .600 64.140 4298.45 4351.00 1168.23 N 2527.33 E 5975627.45 N 374258.21 E 0.206 162.30 5433.58 41.510 63.230 4370.89 4423.44 1196.69 N 2584.89 E 5975654.92 N 374316.25 E 0.630 164.36 5529.10 41 .200 63.210 4442.59 4495.14 1225.13 N 2641.23 E 5975682.39 N 374373.07 E 0.325 165.87 .~ 5624.76 41.070 62.060 4514.64 4567.19 1254.05 N 2697.12 E 5975710.36 N 374429.44 E 0.802 166.73 5720.00 42.220 65.050 4585.82 4638.37 1282.21 N 2753.78 E 5975737.54 N 374486.57 E 2.410 168.63 5815.24 42.520 65.620 4656.18 4708.73 1309.00 N 2812.11 E 5975763.32 N 374545.35 E 0.512 172.54 5910.86 41.980 65.310 4726.96 4779.51 1335.69 N 2870.59 E 5975789.02 N 374604.29 E 0.605 176.59 6006.57 41.610 64.750 4798.32 4850.87 1362.62 N 2928.42 E 5975814.95 N 374662.56 E 0.549 180. 1 3 6101.59 41.250 63.820 4869.56 4922.11 1389.90 N 2985.07 E 5975841.25 N 374719.67 E 0.750 182.80 6197.40 41 .120 65.510 4941.67 4994.22 1416.90 N 3042.08 E 5975867.27 N 374777.14 E 1.169 185.90 6:292.50 40.470 64.740 5013.66 5066.21 1443.03 N 3098.45 E 5975892.44 N 374833.95 E 0.864 189.45 6:388.03 39.980 65.190 5086.60 5139.15 1469.14 N 3154.35 E 5975917.58 N 374890.28 E 0.596 192.80 6483.24 40.640 65.530 5159.20 5211.75 1494.81 N 3210.33 E 5975942.30 N 374946.70 E 0.731 196.58 6578.86 40.300 65.760 5231.95 5284.50 1520.41 N 3266.87 E 5975966.92 N 375003.67 E 0.388 200.68 6674.49 39.680 64.640 5305.21 5357.76 1546.18 N 3322.66 E 5975991.74 N 375059.89 E 0.993 204.28 6'769.67 40.450 64.140 5378.06 5430.61 1572.66 N 3377.90 E 5976017.27 N 375115.58 E 0.877 206.99 6865.32 41.450 63.740 5450.30 5502.85 1600.20 N 3434.22 E 5976043.85 N 375172.35 E 1.081 209.28 - ---_._---~_.-.-.-- .-.. -"-~"._--'._-~.'_..~-----_._-- 10 October, 2002 - 16:25 Page 3 of6 DrillQllest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for AlpIne CD-2 - CD2-29 Your Ref: API 501032042700 Job No. AKMW22162, SUlVéyed: 6 October, 2002 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6960.99 41.820 63.640 5521.80 5574.35 1628.38 N 3491.20 E 5976071.04 N 375229.80 E 0.393 211.32 7056.39 40.770 63.260 5593.48 5646.03 1656.52 N 3547.51 E 5976098.21 N 375286.60 E 1.132 213.08 7152.04 41 .290 63.190 5665.63 5718.18 1684.80 N 3603.57 E 5976125.53 N 375343.13 E 0.546 214.58 7247.27 41.040 63.820 5737.32 5789.87 1712.77 N 3659.67 E 5976152.53 N 375399.70 E 0.508 216.39 ~ 7342.94 42.980 66.760 5808.41 5860.96 1739.50 N 3717.83 E 5976178.26 N 375458.31 E 2.888 220.26 7438.53 42.120 66.750 5878.83 5931.38 1765.01 N 3777.23 E 5976202.76 N 375518.13 E 0.900 225.79 7534.36 41.590 65.940 5950.21 6002.76 1790.66 N 3835.79 E 5976227.40 N 375577.13 E 0.790 230.80 7629.82 42.010 64.680 6021.37 6073.92 1817.24 N 3893.60 E 5976252.99 N 375635.38 E 0.984 234.64 7725.39 41 .130 64.620 6092.87 6145.42 1844.39 N 3950.91 E 5976279.15 N 375693.15 E 0.922 237.74 7820.85 41.200 65.070 6164.74 6217.29 1871.10 N 4007.78 E 5976304.89 N 375750.47 E 0.319 241.02 7915.29 41.930 65.830 6235.40 6287.95 1897.13 N 4064.78 E 5976329.94 N 375807.90 E 0.939 244.96 8010.19 42.250 66.010 6305.82 6358.37 1923.08 N 4122.85 E 5976354.89 N 375866.41 E 0.360 249.47 8105.45 41.330 65.700 6376.85 6429.40 1949.05 N 4180.78 E 5976379.86 N 375924.77 E 0.990 253.91 8135.13 41 .270 65.940 6399.14 6451.69 1957.07 N 4198.65 E 5976387.58 N 375942.78 E 0.571 255.27 8165.93 41.260 69.140 6422.30 6474.85 1964.83 N 4217.42 E 5976395.02 N 375961.68 E 6.852 257.28 8200.21 41.390 71.130 6448.04 6500.59 1972.52 N 4238.71 E 5976402.34 N 375983.09 E 3.852 260.54 8230.51 41.780 73.160 6470.71 6523.26 1978.68 N 4257.85 E 5976408.18 N 376002.34 E 4.629 264.14 8261.45 42.830 75.570 6493.59 6546.14 1984.29 N 4277.90 E 5976413.44 N 376022.48 E 6.245 268.65 8294.58 43.420 77.530 6517.77 6570.32 1989.56 N 4299.92 E 5976418.33 N 376044.59 E 4.419 274.40 8330.98 44.050 79.410 6544.07 6596.62 1994.58 N 4324.58 E 5976422.93 N 376069.33 E 3.968 281.60 8362.42 44.700 81.670 6566.55 6619.10 1998.19 N 4346.26 E 5976426.17 N 376091.07 E 5.435 288.65 8392.10 44.710 82.730 6587.64 6640.19 2001.03 N 4366.95 E 5976428.65 N 376111.80 E 2.513 295.91 8425.93 44.340 86.110 6611.76 6664.31 2003.34 N 4390.55 E 5976430.56 N 376135.44 E 7.090 305.01 8457.57 44.160 90.060 6634.43 6686.98 2004.08 N 4412.61 E 5976430.92 N 376157.51 E 8.729 314.76 8487.31 44.700 93.530 6655.67 6708.22 2003.42 N 4433.41 E 5976429.91 N 376178.30 E 8.367 325.15 8521.58 45.890 96.980 6679.78 6732.33 2001.18 N 4457.66 E 5976427.25 N 376202.50 E 7.952 338.57 8553.10 46.370 100.180 6701.63 6754.18 1997.79 N 4480.12 E 5976423.48 N 376224.90 E 7.475 352.15 8583.22 47.110 102.640 6722.27 6774.82 1993.45 N 4501.62 E 5976418.77 N 376246.32 E 6.435 366.12 8616.21 46.710 106.380 6744.81 6797.36 1987.42 N 4524.93 E 5976412.34 N 376269.53 E 8.367 382.44 81347.39 47.170 108.370 6766.10 6818.65 1980.61 N 4546.67 E 5976405.17 N 376291.15E 4.891 398.70 81378.80 48.500 110.580 6787.19 6839.74 1972.85 N 4568.62 E 5976397.03 N 376312.96 E 6.717 415.90 8'174.09 52.270 116.020 6847.96 6900.51 1943.75 N 4635.94 E 5976366.78 N 376379.78 E 5.913 473.32 8869.27 56.920 120.460 6903.11 6955.66 1906.99 N 4704.20 E 5976328.86 N 376447.40 E 6.189 537.93 8964.34 62.910 126.160 6950.78 7003.33 1861.76 N 4772.80 E 5976282.46 N 376515.22 E 8.158 610.18 9059.77 67.460 132.000 6990.84 7043.39 1807.14 N 4839.93 E 5976226.70 N 376581.40 E 7.318 690.01 -------'--"---'-----"---'------- - - ---....--.---.--.------ 10 October, 2002 - 16:25 Page 4 of6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for AlpIne CIJ-2 - CD2-29 Your Ref: API 501032042700 Job No. AKMW22162, Surveyed: 6 October, 2002 North Slope, Alaska Alaska North Slope Measured Sub..sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9155.01 73.220 134.170 7022.88 7075.43 1745.88 N 4905.38 E 5976164.33 N 376645.80 E 6.417 774.90 9251.01 78.250 140.970 7046.55 7099.10 1677.24 N 4968.05 E 5976094.62 N 376707.28 E 8.634 864.99 9346.77 82.860 147.190 7062.28 7114.83 1600.78 N 5023.40 E 5976017.23 N 376761.31 E 8.013 958.51 9440.93 84.100 147.120 7072.97 7125.52 1522.18 N 5074.13 E 5975937.78 N 376810.69 E 1.319 1051.75 9486.26 85.450 146.040 7077.10 7129.65 1484.51 N 5099.00 E 5975899.68 N 376834.91 E 3.808 1096.70 .~ 9560.57 87.350 146.160 7081.76 7134.31 1422.95 N 5140.36 E 5975837.43 N 376875.21 E 2.562 1170.49 9655.55 88.950 146.040 7084.83 7137.38 1344.16 N 5193.30 E 5975757.74 N 376926.80 E 1.689 1264.94 9750.76 88.400 147.090 7087.03 7139.58 1264.73 N 5245.75 E 5975677.43 N 376977.88 E 1.245 1359.71 9846.54 87.910 14R660 7090.11 7142.66 1183.66 N 5296.65 E 5975595.50 N 377027.39 E 1.716 1455.21 9942.15 88.280 150.230 7093.29 7145.84 1101.38 N 5345.23 E 5975512.39 N 377074.55 E 1.686 1550.68 10035.26 89.380 151.010 7095.19 7147.74 1020.26 N 5390.90 E 5975430.51 N 377118.82 E 1.448 1643.75 10132.99 90.250 152.720 7095.51 7148.06 934.08 N 5436.98 E 5975343.55 N 377163.43 E 1.963 1741.47 10228.55 90.980 153.180 7094.48 7147.03 848.98 N 5480.44 E 5975257.72 N 377205.42 E 0.903 1837.01 10320.67 90.980 152.680 7092.91 7145.46 766.96 N 5522.35 E 5975175.00 N 377245.92 E 0.543 1929.10 10419.26 89.200 153.400 7092.75 7145.30 679.09 N 5567.05 E 5975086.38 N 377289.11 E 1.948 2027.66 10514.73 89.880 153.400 7093.52 7146.07 593.73 N 5609.79 E 5975000.30 N 377330.39 E 0.712 2123.09 10609.70 90.920 154.260 7092.86 7145.41 508.50 N 5651.68 E 5974914.36 N 317370.81 E 1.421 2218.00 10706.01 90.550 154.020 7091.62 7144.17 421.84 N 5693.68 E 5974827.00 N 377411.32 E 0.458 2314.23 10801.23 90.980 153.300 7090.35 7142.90 336.52 N 5735.92 E 5974740.96 N 377452.10 E 0.881 2409.39 10892.43 91.970 152.980 7088.00 7140.55 255.18 N 5777.12 E 5974658.94 N 377491.90 E 1.141 2500.54 10991.34 90.430 153.880 7085.93 7138.48 166.74 N 5821.35 E 5974569.75 N 377534.61 E 1.803 2599.38 11084.60 90.550 152.700 7085.13 7137.68 83.44 N 5863.26 E 5974485.74 N 377575.09 E 1 .272 2692.61 11181.38 88.030 152.950 7086.33 7138.88 2.648 5907.45 E 5974398.92 N 377617.80 E 2.617 2789.36 11271.89 89.080 152.350 7088.61 7141.16 83.01 8 5949.02 E 5974317.85 N 377657.99 E 1.336 2879.83 11366.61 90.180 152.810 7089.23 7141.78 167.088 5992.64 E 5974233.04 N 377700.17 E 1.259 2974.54 11465.49 91.540 153.740 7087.74 7140.29 255.39 8 6037.10 E 5974143.99 N 377743.11 E 1.666 3073.37 11564.62 87.230 151.860 7088.81 7141.36 343.53 8 6082.40 E 5974055.09 N 377786.89 E 4.743 3172.46 11660.06 87.540 153.130 7093.16 7145.71 428.09 8 6126.43 E 5973969.79 N 377829.47 E 1.368 3267.79 11755.44 88.090 152.770 7096.80 7149.35 512.978 6169.77 E 5973884.17 N 377871.35 E 0.689 3363.08 11850.84 88.950 152.420 7099.26 7151.81 597.648 6213.67 E 5973798.77 N 377913.79 E 0.973 3458.44 11946.37 90.120 152.790 7100.04 7152.59 682.45 8 6257.62 E 5973713.22 N 377956.29 E 1.285 3553.96 12041.52 90.980 151.900 7099.12 7151.67 766.73 8 6301.78 E 5973628.20 N 377999.00 E 1.301 3649.10 12136.72 92.090 152.720 7096.57 7149.12 850.99 8 6346.00 E 5973543.19 N 378041.77 E 1.449 3744.26 12232.22 92.830 152.600 7092.47 7145.02 935.748 6389.82 E 5973457.70 N 378084.14 E 0.785 3839.66 12322.77 91.720 151.210 7088.88 7141.43 1015.56 S 6432.43 E 5973377.17 N 378125.37 E 1.963 3930.13 --_._.._-~------_-._._h_..____.-.._..- -.,,-._.."-- -- .._._~------- 10 October, 2002 ~ 16:25 Page 50'6 DrmQlIest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Alpine CD-2- CD2..29 Your Ref: API 501032042100 Job No. AKMW22162, Surveyed: 6 October, 2002 Alaska North Slope Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 12422.74 93.260 151.580 7084.54 7137.09 12487.69 94.310 152.000 7080.25 7132.80 12560.00 94.310 152.000 7074.81 7127.36 Local Coordinates Northings Eastings (ft) (ft) 1103.24 S 1160.35 S 1224.01 S 6480.25 E 6510.88 E 6544.73 E Global Coordinates Northings Eastings (ft) (ft) 5973288.68 N 5973231.06 N 5973166.82 N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. ,~ Vertical depths are relative to RKB = 52.0' MSL. Northings and Eastings are relative to 1855' FNL, 1528 FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1855' FNL, 1528 FEL and calculated along an Azimuth of 151.850° (True). Magnetic Declination at Surface is 24.826°(24-Sep-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 12560.00f1., The Bottom Hole Displacement is 6658.21ft., in the Direction of 100.593° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12560.00 7127.36 1224.01 S 6544.73 E Projected Survey Survey too/proaram for CD2-29 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 341.00 0.00 341.00 341.00 12560.00 341.00 Tolerable Gyro(CD2-29 Gyro) 7127.36 MWD Magnetic(CD2-29) 10 October, 2002 - 16:25 Page 60f6 378171.68 E 378201.34 E 378234.09 E North Slope, Alaska Vertical Section Dogleg Rate (0/100ft) 1.584 4030.00 1.741 4094.81 0.000 4166.92 Projected Survey Comment ----------~_..._._--_._->~---- DrillQlIest 3.03.02.002 ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation. Commission TO: Mike Bill Commissioner ¡J n.,' Ohf1,. SUBJECT:.:........,M.:.... .'" e...........C..........h... apIcal. Integrity Tests THRU: Tom Maunder ?J1/:1 I r" Phillips P.I. Supervisor \\( .'Û').......CÐ2 C5 CRU FROM: Chuck Scheve Alpine Petroleum Inspector NON. CONFIDENTIAL ,.,..,f/t) DATE: November 6, 2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well CD2-16 Type Inj. S T.V.D. 6929 Tubing 255 255 255 255 Interval I P.TD. 202-144 Type test P Test psi 1732 Casing 1200 2125 2100 ..2100 P/F f Notes: Well CD2-29 Type Inj. S T.V.D. 6974 Tubing 520 520 520 520 Interval I P.TD. 202-148 Type test P Test psi 1744 Casing 1450 2200 2050 2050 P/F f Notes: Well CD2-38 . Type Inj. S TV.D. Tubing 255 255 255 255 Interval I P.TD. 202-171 Type test P Test'psi Casing 1150 1775 1750 1750 P/F f Notes: Well CD2-44 Type Inj. S T.V.D. Tubing 120 120 120 120 Interval I P.TD. 202-165 Type test P Test psi Casing 125 1950 1925 1925 P/F f Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi. Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F= FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year CYCle s = SALTWATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test duringWorkover D= Differential Temperature Test 0= Other (describe in notes) Test's Details I traveled to Phillips CD210cation in the Alpine Field and witnessed the initial MIT on wells CD2-16, CD2-29, CD2-38 and CD2-44. The pretest tubing aiidcasingpressUteswereobserved and found to be stable. The standard annulus pressure testwas then performed with all 4 wells demonstrating good mechanical integrity. M.I.T.'s performed: ~ Attachments: Number of Failures: Q Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. MIT CRU CÐ2 11-6-02 CS.xls 11/15/2002 Request to connnence injection into CD2-29 ~z.-ILI9 Subject: Request to commence injection into CD2-29 Date: Wed, 23 Oct 2002 11 :25 :22 -0800 From: "Clifford L Crabtree" <ccrabtr@ppco.com> To: winton_aubert@admin.state.ak.us, Tom Maunder <tom_maunder@admin.state.ak.us> CC: "Chris R Pierson" <crpiers@ppco.com>, "NSK Problem Well Supv" <nI617@ppco.com> ConocoPhillips requests approval to begin injection operations in CD2-29. The attached bond log for CD2-29 provides evidence of cement integrity. The attached PDF provides proximity information compared to surrounding wells. Other pertinent details follow: API Number: 50-103-20427-00 Packer: Baker S-3 Tubing tail Bottom of logged interval Top of Alpine C sand 711 Casing Shoe PBTD 8,906' MD (6,923' TVD ss) 9,026' MD (6,977' SS) @ 65 deg 9,168' MD (7,027' TVD 9,445' MD (7,073' TVD ss) 9,556' MD (7,082' TVD ss) 12,560' MD (7,075' TVD ss) ss) @ 75 deg 80% of full returns were reported during the cement job. Bond appears to be excellent across the logged interval. Tubing and Casing were pressure tested to 3500 psi on 10/07/02 during completion operations. We antcipate this well will be available to begin injection by Saturday, 10/26. I would appreciate email receipt of injection approval to Chris Pierson and myself by close of your business on 10/25. Regards Cliff Crabtree Phillips Alaska Inc.- Alpine Subsurface Development Office: (907) 265-6842; Cell: (907) 240-5357 Email: ccrabtr@ppco.com; Fax:: (907) 265-1515 (See attached file: CD2-29 Cmt. summary.doc) (See attached file: CD2-29 (1320 Plot) .pdf) (See attached file: CD2-29 CBL.zip) L~'~^~M"_~'~_^,_^^^M_'~~_'":";-'~~~_~~'M'~;'~;"""M'_-_m'_~~__^~^,,-^-,~~'^~:'-,^_:::"':::~:::::':::"::::':=-;='^_':"":'._,_:.,"~~~^,~-~^="=:::':::-=':=;:;'::'--_^~N^"';"~ I ..~ --..." ..---.. ". .. --~." . , '. . . ... _--.~m...~ Name: CD2-29 Cmt. summary. doc I CD2-29 Cmt. summary. doc Type: WINWORD File (application/msword) Encodi!~,:~~«~~.:~~«-@""."-",,,,,,..","*,,,,,~,,,wm,x«.>x<,.....,,,.,.,.,,<~,w.,«., ~.. .. -----""-..__.....-._._.....-................__.... Name: CD2-29 (1320 Plot).pdf . --------.-...........-m.._...\ I CD2-29 (1320 Plot).pdf Type: Portable Document Format (application/pdf)~ , Encoding: base64 »---,.">=>=~»=-=".,"."--_ø».~--"",=,">-"--="J r---_.__..--._.._-_.._..._m-----"---!"h-'''---N~me: CD2-29 CBL.zip -___"__m_. _...--_.._-_.. ! ~CD2-29 CBL.ziP! Type: Zip Compressed Data (application/x-zip-compressed)~ !"u"_"^,"M~""W'"_^'"^h,_......J~~_~?~~~1J~':~~~^~~~"""Mw_h.._m_=_~'W^W'W'MWM",_,.,,",.,.,,",-,_.^-_J MI Òk-d;c.-1LJ ~ c...d- ~I. ~ ~ L l~f~Þ;:þ;-..-- E I.uM wi L L.eX L 'iP- ML: I e-I ~ ~ ....'\L l .:' j ) .J",-~ I ~~--þè,,--- ~rtc\le J \JJ 6 A-. ~~/U{lð¿~ ) I /.. L, '."'.> """(1 e ';", "'. r'\ø ~.,,~'"'~. r.... .. J /. . \ì. -L-"- 1.. C1 1",",,- . \ CD2-29 7" Casing Cement Summary Run casing to 9152' (220 jts total) PU & SO WT.'s stable @ 300k up and 175k down. Run casing from 9152'- SOW dropped 35-55k, pumped down last 9 jts with slight returns - SOW 150-120k. MUhanger and LJ, landed Casing with FS @ 9556', FC @ 9470'. Last 60' to bottom SOW improved 165k - 140k with an increase in returns to 25%. Lost 345 bbls of mud. Ld fill-up tool, blow down TD, MU cement head. Staged pumps up to 4 bpm as returns increased from 25% to 80%. Conditioned mud for cementing, maintained 9.6 ppg mud wt wI 5 ppb LcM additions, peak mud wt out= 10.4 ppg. PUW 320 SOW 175. Held pre-job safety meeting. Line up to cementers, pumped 5 bbls of Arco wash and test lines to 3500 psi. Pumped additional 15 bbls of Arco wash @ 4.1 bpm I 700 psi - 50 bbls of 12.5 ppg MudpushXL spacer @ 4.1 bpm I 625 psi - dropped bottom plug and pumped 34 bbls of (168 sxs) of 15.8 ppg G cmt wladds @ 4.0 bpm 600 psi. Dropped top plug - pumped 20 bbls of FW from cementers - switch to rig pumps and displace with 339 bbls of 9.6 ppg LSND mud @ 6 bpm 1240-610 psi. slowed pumps to 5 bpm last 10 bbls 540 - 610 psi. Reciprocated pipe untilllast 20 bbls of displacement, bumped plugs to 1000 psi, floats held, CIP @ 1750 hrs. Flow check annulus - static. Maintained 80% returns while cementing - lost 398 bbls of mud while circulating and cementing - total losses for day = 1003 bbls. RD cement head and lines, laydown LJ. ') WELL DETAILS 2847----- ~ CD2-16 (CD2-16 (Rig Surveys)) I ~ Name +N/-S "E/-W Northing Easting Latitude Longitude Slot CD2-2<)'138.764 17.398 5974502.63 371711.26 70'20'18.860N 151'02'27.575W N/A '''''''-'''''i",."."".."".,:.."..."~"L,."...""..",,,..,, . : - -, ,;:,.,~ ::',", "",' ,,'.' , :":,'-:":;,;.[J ,~, "CD~..2":';";~C c :..."._,..:.....'.::...:....~:.~:....."'."'...'.m:~..;_;..~.""-'~ 1898-""'" c __ID~\rf# iõ & ... ~ 94<}---- §: +' :ë= 1:: 0 ~ :ë= :s 0 r:/) (}---. - 94 <}---- -1898----- ! CD2-44 (CD2-44 (Rig Surveys)) ¡ ¡ I I I I I I I . I I , , , , , , 3797 4746 6644 7593 West(-)Æast(+) [ft] ) ) ~1ffÆu TONY KNOWLES, GOVERNOR A.IfA.~1iA. OIL AND GAS CONSERVATION COMMISSION Chip Alvord Drilling Team Leader Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Unit CD2-29 BP Exploration (Alaska), Inc. Permit No: 202-148 Surface Location: 1855' FNL, 1528' FEL, Sec.2, TIIN, R4E, UM Bottomhole Location: 2202' FSL, 246' FEL, Sec. 1, TIIN, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. The blowout prevention equipment (BOPE) must be tested in accordance with 20 MC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20MC 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. Sincerely, ( HJThMW'{ ~~ Gt~~; ~echsli Taylor Chair BY ORDER OF THE COMMISSION DATED this~ay of July, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ) ) Type of Work STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b Type of Well Exploratory Service X Development Gas 5. Datum Elevation (OF or KB) DF 52' 6. Property Designation ADL 380075 7. Unit or property Name (JJ6A 7/1-&/02- ~ 1(1C?(ð-L 1a. Drill X Re-Entry Name of Operator Phillips Alaska, Inc. Address P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface Stratigraphic Test Development Oil Single Zone X Multiple Zone 10. Field and Pool Colville River Field Alpine Oil Pool Redrill Deepen 2. feet 3. 4. 1855' FNL, 1528' FEL, Sec. 2, T11 N, R4E, UM At target (=7" casing point) Colville River Unit 8. Well number CD2-29 I 9. Approximate sPldate 8/18/2002 14. Number of acres in property 432' FNL, 1660' FEL, Sec. 1, T11 N, R4E, UM At total depth 11. Type Bond (see 20 MC 25.025) Statewide Number #59-52-180 Amount 2202' FSL, 246' FEL, Sec. 1, T11 N, R4E, UM 12. Distance to nearest 13. Distance to nearest well Property line CD2-47 246' FEL 380075 feet 9.9' at 300' MD 16. To be completed for deviated wells $200,000 15. Proposed depth (MD and TVD) 12545' MD 2560 7143' TVD 17. Anticipated pressure (see 20 MC 25.035(e)(2)) Title Drilling Team Leader Date "7 (tt(ð,l- Commission Use Only Permit N~mber. I API number I Approval date /'1~'1. /11 ~ I See cove. r letter for z...D"l... - t q-l 50- I 0:5 - 2.£)1./-1.. ¡" Ilff' C,!V if\, Othe~e~irements Conditions of approval Samples required Yes ŒiJ Mud log r quire Yes ~ Hydrogen sulfide measures Yes ~ Directional survey required 6> No Required working pressure for BOPE 2M 3M 5M 10M 15M Other: Þ\IT I ÛAA t ~ tul;. ~lo~ ~.'h '.". tM ~ d J T €;S+- Bo P. E ~ 5000 '(J S t' , P t.¥ '1-0 A-¡{.c.. l ~ ,0 ~ cs") d£l{f ~ itv ~ U.(,~ Hu.~ W tU. V ~-"J . on rm Idneo by U by order of Approved by Cammy Oochsli Tay/o! Commissioner the commission Form 10-401 Rev. 7-24-89 . Feet Kickoff depth feet Maximum hole angle Maximum surface 2518 350 89.93° 18. Casing program Setting Depth size Specifications Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' 12.25" 9.625" 36# J-55 BTC 2685' 37' 37' 2722' 2390' 8.5" N/A 7" 4.5" 26# L -80 12.6# L-80 BTC-M 9508' I BT mod 8980' 37' 32' 37' 32' 9545' 9012' 7137' 7002' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Size Cemented Structural Conductor Surface Intermediate Production Liner RECEIVED JUL <1 5 2002 ~~~a Oil & G~s Gens. Commission BO e c AnchofàUffer Sketch Refraction analysis Seabed report Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot 21 . I hereby certify that the foregoing is true and correct to the best of my knowledge Signed þ" ~ feet psig At total depth (TVD) 3209 at psig 7091' TVD.SS Quantity of cement (include stage data) Pre-installed 535 Sx Arcticset .111 L & 230 Sx Class G 149 Sx Class G Tubing Measured depth True Vertical depth Drilling program X 20 AAC 25.050 requirements X Date ~ (ø.¿f¿p?;;. L ) ) CD2-29 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) .12-1/411 Hole /9-5/8" Casina Interval Event Risk Level Conductor Broach Low Well Collision medium Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVO Lost Circulation Low Low .8-1/2" Hole /7" Casina Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVO Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low Mitigation Strategy Monitor cellar continuously during interval. Gyro single shots, traveling cylinder diagrams Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem peratu res Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries Mitigation Strategy BOPE drills, Keep mud weight above 10.4 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers .6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation moderate Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 9.0 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers 0 tu ,",iI h 1- ) ) Alpine: CD2-29 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 16. 17. 18. 19. 20. 21. 22. Procedure Move on Doyon 19. Drill 12- Y4" hole to the surface casing point as per the directional plan. Run and cement 9-5/8" surface casing. I Install and test BOPE to 5000 psi. / Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8-%11 hole to intermediate casing point in the Alpine Sands. (LWD Program: GR/RES/PWD) Run and cement 7" casing as per program. Top of cement> 500 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/811 x 711 casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 5000 psi. / Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6-1/8" horizontal section to well TO (LWD Program: GR/RES/PWD). Displace well to brine and pull out of hole. ( Run 4-%,12.6#, L-80 tubing with DB injection nipple, gas lift mandrel and packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Circulate tubing to diesel and install freeze protection in the annulus. ~ Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi 1 30 mins. Set BPV and secure well. Move rig off. JRiGiN L ) ) Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-26PB1 will be the closest well to CD2-29, 24' at 500' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 8.5' at 5001 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 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 Pumpina Operations: Incidental fluids developed from drilling operations on well CD2-29 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The CD2-29 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 CD2-29 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the below the base of the Schrader Bluff Formation (C-40). These 300-400. thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2390') + 1,500 psi = 2,990 psi = 1,081 psi Pore Pressure Therefore Differential = 2991 - 1081 = 1910 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 850/0 of OD (ppf) Grade Range Type Collapse Collapse Burst Bu rst 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 0 [;, 0F',~ rli (;i Ii L ') ) CD2-29 DRilLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 Y2" Section - 6 1 18" point - 12 1;4" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 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 I 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 -10.0 9.0 -9.5 KCL 6% Surface Hole: A standard high viscosity fresh water I gel spud mud is recommended for the surface interval. Keep flowline viscosity at :t 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel I polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining 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 :t 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. )RIG L ) " Colville River Field CD2-29 Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco OS Nipple (3.812') at 2000' TVD = 2200' MD 9-5/8" 36 ppf J-55 STC Surface Casing @ 2722' MD / 2390' TVD cemented to surface 4-1/2" 12.6 ppf L-80 1ST M tubing run with Jet Lube Run'n'Seal pipe dope Cameo KBG-2 GLM (3.909" DRIFT ID) wI dummy Updated 07/10/02 Packer Fluid mix: 9.6 ppg KCI Srine with 2000' TVD diesel cap Tubing suspended with diesel Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco DS6 nipple 2200' 2000' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco KSG2- GLM (3.909" 10) 8800' 6896' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) Baker 53 Packer wI millout extension 8900' 6949' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) HES "XN" (3.725")-63.42 inc 9000' 6996' 4-1/2", 12.6#/ft, 1ST-Mod 10' pup joint WEG 9012' 7002' Baker S3 Packer at +/- 8900' <20~'~om top of Alpine ~ .~ ~ -:4 I';:!¡ Scr Tv~ ,\ i TOC @ +/- 8682' MD (>654' MD above top Alpine) '!::. ~ ~,.~.~~~~- - '~, ~ .- '<..~~-~ Top Alpine at 9336' MD I 7109' TVD Well TD at 125451 MD I 71431 TVD 7" 26 ppf L-80 STC Mod Production Casing @ 9545' MD / 7137' TVD @+/- 872 Oq~¿'~¡¡~'jJL ~ : it' ¡ ~ Jf! J,.} \g<..i! /Ij,.~,.< L ~ ~ ~¡~..~ ) ') CD2-29 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well : Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MDfTVD(ft) (Ibs. I gal) (psi) (psi) 16 114/114 10.9 52 53 95/8 2722 I 2390 14.5 1081 1566 7" 9545 I 7137 16.0 3229 2563 N/A 12545 I 7143 16.0 3232 N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point 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) = 1081 - (0.1 x 2390') = 842 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 2390 = 1563 psi OR ASP = FPP - (0.1 x D) = 3229 - (0.1 x 7137') = 2516 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3232 - (0.1 x 7143') = 2518 psi OR""':'- , :f '- ) ) Alpine, CD2-29 Well Cementina ReQuirements 95/8" Surface Casin2 run to 2722' MD /2390' TVD. Cement from 2722' MD to 2222' (500' offill) with Class G + Adds @ 15.8 PPG, and from 2222' to surface with Arctic Set Lite 3. Assume 300 % excess annular volume in permafrost and 50 % excess below the permafrost (1700' MD). Lead slurry: System: Tail slurry: System: (2222'-1700') X 0.3132 ft3/ft X 1.5 (50% excess) = 245.2 ft3 below permafrost 1700' X 0.3132 ft3/ft X 4 (300% excess) = 1950.6 ft3 above permafrost Total volume = 245.2 + 2129.8 = 2375.0 ft3 => 535 Sx @ 4.44 ft3/sk / 535 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% SOOI accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 fë annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk / 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % SOOI accelerator @ 15.8 PPG yielding 1.17 fë /sk 7" Intermediate Casin2 run to 9545' MD /7137' TVD Cement from 9545'MD to +/- 8682' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (9545' - 8682') X 0.1268 ft3/ft X 1.4 (40% excess) = 153.2 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 fë shoe joint volume Tot/volume = 153.2 + 17.2 = 170.4 ft3 => 149 Sx @ 1.15 ft3/sk 149 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk 1 By Weight Of mix Water, all other additives are BWOCement OR¡~ a ~ "-æa:"", '" - {;"' Q¡Æ';l. = ~:;~ '. -'~.~~:. KU"'?Ùff"~~ì7'tJnit ~t!orlfff"ope; Alaska I!!(il'i!e CD-2, Slot CD2-29 :A~~~ft~~:~f)D2-29 - CD2-29 (wp01) ;_.~!:t'C .t1; ~. " Revised: 4 July, 2002 .~ .c:;¡--~~,,- PROPOSAL REPORT 4 July, 2002 ~" Surface Coordinates: 5974502.63 NJ 371711.26 E (70" 20' 18.8603" NJ 151" 02' 27.5748" W) Surface Coordinates relative to Project H Reference: 974502.63 N, 128288.74 W (Grid) Surface Coordinates relative to Structure: 59.60 NJ 7.25 W (True) Kelly Bushing: 52.00ft above Mean Sea Level ~:~,..". J#, t'i'#~~~~tt Proposal Ref: pro9920 Sperry-Sun Drilling Services Proposal Report for Plan: CD2-29 - CD2-29 (wp01) Revised: 4 July, 2002 .....;:!t,-':'i;~ Kuparuk River Unit .- ~.~ . ;.:c"'- ~ ".', ;¡..::--;: --"'-- Measured Sub-Sea Vertical Local Coordinates Depth lnel. Azim. Depth Depth Northings Eastings Comment (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -52.00 0.00 O.OON O.OOE SHL (1855' FNL & 1528' FEL, SEC 2 - T11N - R4E) 100.00 0.000 0.000 48.00 100.00 O.OON 0.000 0.00 200.00 0.000 0.000 148.00 200.00 O.OON 0.000 0.00 300.00 0.000 0.000 248.00 300.00 O.OON 0.000 0.00 350.00 0.000 0.000 298.00 350.00 O.OON 0.000 0.00 Begin Dir @ 2.00/100ft (in 12..) Hole): 350.00ft MD, 350.00ftTV"-,,, 400.00 1.000 75.000 348.00 371711.68 E 2.000 0.10 500.00 3.000 75.000 447.93 371715.07 E 2.000 0.89 600.00 5.000 75.000 547.68 371721.84 E 2.000 2.48 700.00 7.000 75.000 647.13 371731.98 E 2.000 4.86 750.00 8.000 75.000 696.70 371738.31 E 2.000 6.34 Increase in Dir Rate @ 3.0°/1 OOft : 750.00ft MD, 748.70ftTVD 800.00 9.471 73.066 9.31 N 34.23 E 5974511.36 N 371745.64 E 3.000 7.93 900.00 12.434 70.567 15.29 N 52.25 E 5974517.03 N 371763.77 E 3.000 11.17 1000.00 15.411 69.019 23.64 N 74.82 E 5974524.98 N 371786.47 E 3.000 14.46 1100.00 18.395 67.964 34.32 N 101.86 E 5974535.20 N 371813.69 E 3.000 17.80 1200.00 21.384 ~~~!'~~::> 47.31 N 133.30 E 5974547.65 N 371845.35 E 3.000 21.18 j~~:i'~;ij~?~j'~ 1275.16 62.57 N 169.05 E 5974562.30 N 371881.35 E 3.000 24.59 1365.12 80.06 N 209.02 E 5974579.11 N 371921.62 E 3.000 28.02 1452.69 99.74 N 253.09 E 5974598.03 N 371966.02 E 3.000 31.46 1537.61 121.55 N 301.16 E 5974619.01 N 372014.45 E 3.000 34.91 1619.66 145.43 N 353.07 E 5974642.00 N 372066.77 E 3.000 38.34 C 1800.0 39.351 64.933 1646.61 1698.61 171.32 N 408.70 E 5974666.93 N 372122.83 E 3.000 41.76 ~.. =0 1873.09 41.541 64.779 1702.23 1754.23 191.47 N 451.62 E 5974686.34 N 372166.09 E 3.000 44.25 End Dir, Start Sail @ 41.54° : 1873.09ft MD, 1754.23ft TVD ---- 1900.00 41.541 64.779 1722.37 1774.37 199.07 N 467.77 E 5974693.67 N 372182.36 E 0.000 45.16 ~ 2000.00 41.541 64.779 1797.22 1849.22 227.33 N 527.76 E 5974720.89 N 372242.83 E 0.000 48.55 ---- 2100.00 41.541 64.779 1872.07 1924.07 255.58 N 587.75 E 5974748.12 N 372303.30 E 0.000 51.94 ~> 2200.00 41.541 64.779 1946.92 1998.92 283.84 N 647.75 E 5974775.35 N 372363.77 E 0.000 55.33 ...."'~ ~~~ 2256.23 41.541 64.779 1989.00 2041.00 299.73 N 681.48 E 5974790.66 N 372397.77 E 0.000 57.23 C-40 ~.---- 2300.00 41.541 64.779 2021.76 2073.76 312.10 N 707.74 E 5974802.58 N 372424.24 E 0.000 58.72 2400.00 41 .541 64.779 2096.61 2148.61 340.36 N 767.74 E 5974829.80 N 372484.71 E 0.000 62.11 2500.00 41.541 64.779 2171.46 2223.46 368.62 N 827.73 E 5974857.03 N 372545.18 E 0.000 65.49 4 July, 2002 -12:36 Page2of9 Drí/lQuest 2.00.09.006 0 =0 '.....,'''''~'"c'''' ~~~.'--'';"Y--~:J3 Sperry-Sun Drilling Services Proposal Report for Plan: CD2-29 - CD2-29 (wp01) Revised: 4 July. 2002 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 2600.00 41.541 64.779 2246.31 2298.31 2700.00 41.541 64.779 2321.16 2373.16 2722.51 41.541 64.779 2338.00 2390.00 2743.88 41.541 64.779 2800.00 41.541 64.779 2900.00 41.541 64.779 3000.00 41.541 64.779 3100.00 41.541 64.779 3200.00 41.541 64.779 3246.23 41.541 64.779 3300.00 41.541 64.779 3400.00 41.541 64.779 3500.00 41.541 64.779 3600.00 41.541 64.779 3700.00 41 .541 64.779 2354.00 2396.00 2406.00 2448.00 Local Coordinates Northings Eastings (ft) (ft) 396.87 N 425.13 N 431.49 N 'F:ff.!.~~Ct,<... orth Slope, Alaska Alpine CD-2 .,-_:- .' Global Coordinates Northings EasU (ft) '~~:.ß-:~;ri')~~=C:~ ';j~;<r '1~ft) Comment 887.72 E "tß:~ 68.88 947.72 E 72.27 961.22 E 0.000 73.03 9-5/8" Csg Pt ... Drill out 8-1/2" Hole 2722.51 ftM D,2390.00ftTVD 9-5/8" Casing 9!~.05 J;? 372692.65 E 0.000 73.76 C-30 :100131 \~c~:-.-:-:- - 372726.58 E 0.000 75.66 ''-'" '*j~¿'i~ 5974965.94 N 372787.05 E 0.000 79.05 5974993.17 N 372847.52 E 0.000 82.44 5975020.39 N 372907.99 E 0.000 85.83 5975047.62 N 372968.46 E 0.000 89.21 5975060.21 N 372996.41 E 0.000 90.78 C-20 1307.68 E 5975074.85 N 373028.93 E 0.000 92.60 1367.68 E 5975102.08 N 373089.39 E 0.000 95.99 1427.67 E 5975129.30 N 373149.86 E 0.000 99.38 1487.67 E 5975156.53 N 373210.33 E 0.000 102.77 1547.66 E 5975183.76 N 373270.80 E 0.000 106.16 1607.65 E 5975210.99 N 373331.27 E 0.000 109.55 1667.65 E 5975238.21 N 373391.74 E 0.000 112.94 1727.64 E 5975265.44 N 373452.21 E 0.000 116.32 1787.64 E 5975292.67 N 373512.68 E 0.000 119.71 1847.63 E 5975319.90 N 373573.15 E 0.000 123.10 1907.62 E 5975347.12 N 373633.61 E 0.000 126.49 1967.62 E 5975374.35 N 373694.08 E 0.000 129.88 ~/j 2027.61 E 5975401.58 N 373754.55 E 0.000 133.27 2087.61 E 5975428.80 N 373815.02 E 0.000 136.66 2128.27 E 5975447.26 N 373856.01 E 0.000 138.95 K-3 2147.60 E 5975456.03 N 373875.49 E 0.000 140.04 2207.59 E 5975483.26 N 373935.96 E 0.000 143.43 2267.59 E 5975510.49 N 373996.43 E 0.000 146.82 2297.40 E 5975524.02 N 374026.47 E 0.000 148.51 K-2 2327.58 E 5975537.71 N 374056.90 E 0.000 150.21 2470.85 2545.70 2620.55 2695.39 2730.00 ~~~~:~ è~~'j~:~~:ftD~:/~; 3800.00 41.541 .~,~D~= 3900.00 41.54 to:'}.-', 64~j'79'Ü:- :::~~~~~~~(;~:~3' 4400.0. 41.541 64.779 4500.00 41.541 64.779 4600.00 41.541 64.779 4667.79 41.541 64.779 4700.00 41.541 4800.00 41.541 4900.00 41.541 4949.69 41.541 5000.00 41.541 64.779 64.779 64.779 64.779 64.779 4 July, 2002 - 12:36 2522.85 2597.70 2672.55 2747.39 2782.00 4.48 3196.48 735.97 N 19.33 3271.33 764.23 N 3294.18 3346.18 792.48 N 3369.02 3421.02 820.74 N 3443.87 3495.87 849.00 N 3518.72 3570.72 877.26 N 3593.57 3645.57 905.52 N 3668.42 3720.42 933.77 N 3743.26 3795.26 962.03 N 3794.00 3846.00 981.19N 3818.11 3870.11 990.29 N 3892.96 3944.96 1018.55 N 3967.81 4019.81 1046.81 N 4005.00 4057.00 1060.85 N 4042.66 4094.66 1075.06 N Page 30f9 Dril/Quest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: CD2-29 - CD2-29 (wp01) Revised: 4 July, 2002 orth Slope, Alaska Alpine CD-2 ';f";¿Nif4:,. Kuparuk River Unit :.- ~.~ -=-.--:,.~- -. " -c-~.~&::; '1'ertical j,~Seetion Global Coordinates Northings EastÎi (ft) Vertical Depth (ft) Local Coordinates Northings Eastings (ft) (It) Sub-Sea Depth (ft) Measured Depth (ft) Comment Azim. Inel. 1103.32 N 1131.58 N 1159.84 N 1188.10N 1216.35 N 4169.50 4244.35 4319.20 4394.05 4468.89 153.60 156.99 160.38 163.77 167.15 64.779 64.779 64.779 64.779 64.779 4117.50 4192.35 4267.20 4342.05 4416.89 5100.00 41.541 5200.00 41.541 5300.00 41.541 5400.00 41.541 5500.00 41.541 374419.71 E 374480.18 E 374540.65 E 374601.11 E 374661.58 E 0.000 0.000 0.000 0.000 0.000 170.54 173.93 177.32 180.71 184.10 64.779 64.779 64.779 64.779 64.779 4491.74 4566.59 4641.44 4716.29 4791.13 4543.74 4618.59 4693.44 4768.29 4843.13 5600.00 41.541 5700.00 41.541 5800.00 41.541 5900.00 41.541 6000.00 41.541 ~ 2987.52 E 3047.51 E 3107.51 E 3167.50 E 3227.49 E 5975837.21 N 5975864.44 N 5975891.67 N 5975918.90 N 5975946.12 N 374722.05 E 374782.52 E 374842.99 E 374903.46 E 374963.93 E 0.000 0.000 0.000 0.000 0.000 187.49 190.87 194.26 197.65 201.04 64.779 64.779 64.779 64.779 64.779 4865.98 4940.83 5015.68 5090.52 5165.~C~\;, 6100.00 41.541 6200.00 41.541 6300.00 41.541 6400.00 41.541 6500.00 41.541 -:i~;&~2~~tf;~ ~;~~:~~ 9.92 5441.92 64.76 5516.76 5539.61 5591.61 3287.49 E 3347.48 E 3407.48 E 3467.47 E 3527.47 E 5975973.35 N 5976000.58 N 5976027.81 N 5976055.03 N 5976082.26 N 375024.40 E 375084.87 E 375145.33 E 375205.80 E 375266.27 E 1527.19 N 1555.45 N 1583.71 N 1611.96 N 1640.22 N 0.000 0.000 0.000 0.000 0.000 204.43 207.82 211.21 214.60 217.98 41.541 64.779 41.541 64l;r:9-j, . :::iCi~~¡~i}\ 64.779 64.779 64.779 64.779 6600.00 6700.00 6800.00 6900.00 7000.0 3550.22 E 3587.46 E 3647.45 E 3707.45 E 3767.44 E 5976092.59 N 5976109.49 N 5976136.72 N 5976163.94 N 5976191.17 N 375289.21 E 375326.74 E 375387.21 E 375447.68 E 375508.15 E 1650.94 N 1668.48 N 1696.74 N 1725.00 N 1753.25 N 0.000 0.000 0.000 0.000 0.000 219.27 Albian-97 221.37 224.76 228.15 231.54 5620.00 5666.46 5741.31 5816.16 5891.00 5568.00 5614.46 5689.31 5764.16 5839.00 7037. 7100. 7200.0 7300.0 7400.00 ~ 0 ::t:J 375568.62 E 375629.08 E 375689.55 E 375738.39 E 375750.02 E 3827.44 E 3887.43 E 3947.42 E 3995.88 E 4007.42 E 5976218.40 N 5976245.63 N 5976272.85 N 5976294.84 N 5976300.08 N 1781.51 N 1809.77 N 1838.03 N 1860.85 N 1866.29 N 0.000 0.000 0.000 0.000 0.000 234.93 238.32 241.70 244.44 Albian-96 245.09 5913.85 5988.70 6063.55 6124.00 6138.39 5965.85 6040.70 6115.55 6176.00 6190.39 64.779 64.779 64.779 64.779 64.779 7500.00 41.541 7600.00 41.541 7700.00 41.541 7780.77 41.541 7800.00 41.541 l~a'aí1i;;~.4jt.~ Dril/Quest 2.00.09.006 4 July, 2002 - 12:36 Page 4 019 a ~:-T ~B~' c """', ~"- Kuparuk River Unit Measured Depth Incl. Azim. (ft) 7900.00 41.541 64.779 8000.00 41.541 64.779 8100.00 41.541 64.779 8115.09 41.541 64.779 8200.00 41.814 72.433 8300.00 42.774 81.240 8400.00 44.379 89.632 8453.33 45.476 93.889 8500.00 46.561 97.477 8600.00 49.240 104.717 8700.00 52.333 111.356 8800.00 55.769 117.436 8842.65 57.321 119.875 8900.00 59.480 123.022 9000.00 63.411 128.184 Sub-Sea Vertical Depth Depth (ft) (ft) 6213.24 6265.24 6288.09 6340.09 6362.94 6414.94 6374.23 6426.23 6437.69 6489.69 6511.73 6563.73 6584.23 6636.23 6622.00 6674.00 6654.41 6706.41 6721.50 6773.50 Sperry-Sun Drilling Services Proposal Repotf for Plan: CD2-29 - CD2-29 (wp01) Revised: 4 JUlyf 2002 orth Slope, Alaska Alpine CD-2 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates rtieal NO:ngS Easllng . .'.;~;,!o.~~)'b;c".$eclion Comment 1894.54 N 1922.80 N 1951.06 N 1955.32 N 4067.41 E 4127.41 E 4187.40 E 4196.45 E 1975.88 N ,42~;~~4 ~']~~~., ~~:~~ ~i,:~:~;-'~~';~::t:~t'¥N'~;:~~:~~:: ~ 1 .35 N '\<>:'4420.56'Ê 5976422.06 N 1 N ' 4453.97 E 5976418.16 N N 4526.66 E 5976402.56 N -i>iá-?l1i-$~~' - ?l~i:;.:~~ i903:¿~ ~ ,,' '1877.56 N 1826.40 N 9046.51 65.301 130~-¡" 7017.00 1799.82 N 9100.00 67.516 132.997', ' 7038.41 1767.19 N 9200.00 71.755 " J37;527 7073.22 1700.60 N 9208'1;1., 72 141 : 1.37.923 7076.00 1694.28 N 9264. ",ï2:~j'¡..74.5~ 140.344 7092.00 1653.83 N " 9300.0Ô '" ,:,16~096' . 141.840 7048.91 7100.91 1627.35 N 9335.63 '," 77.661 '143.334 7057.00 7109.00 1599.79 N 9400.0<l',w1 80.509 145.992 7069.19 7121.19 1548.23 N 9500.00 84.970 150.037 7081.83 7133.83 1464.12 N 9545.28 87.000 151.848 7085.00 7137.00 1424.64 N 4 July, 2002 -12:36 4600.22 E 5976377.24 N 4673.84 E 5976342.50 N 4705.05 E 5976324.90 N 4746.71 E 5976298.70 N 4818.03 E 5976246.33 N 4850.46 E 5976219.21 N 4887.03 E 5976185.95 N 4952.94 E 5976118.24 N 4958.69 E 5976111.83 N 4993.68 E 5976070.78 N 5015.05 E 5976043.94 N 5036.13 E 5976016.02 N 5072.68 E 5975963.85 N 5125.18 E 5975878.85 N 5147.12 E 5975839.00 N Page50f9 .000 248.48 .000 251.87 0.000 255.26 0.000 255.77 Begin Dir @ 6.00/100ft: 8115.09ft MD, 6426.23ftTVD 375993.39 E 6.000 262.41 .~ 376059.04 E 6.000 279.82 376127.71 E 6.000 307.42 376165.31 E 6.000 326.21 HRZ 376198.66 E 6.000 344.90 376271.09 E 6.000 391.86 376344.23 E 6.000 447.77 376417.26 E 6.000 512.04 376448.18 E 6.000 541.81 K-1 376489.39 E 6.000 583.94 376559.83 E 6.000 662.70 376591.80 E 6.000 701.42 LCU 376627.81 E 6.000 747.45 376692.57 E 6.000 837.26 376698.21 E 6.000 845.54 Miluveach A 376732.50 E 6.000 897.72 Alpine D 376753.42 E 6.000 931.15 376774.02 E 6.000 965.40 Alpine 376809.68 E 6.000 1028.09 -" 376860.74 E 6.000 1127.03 376882.00 E 6.000 1172.19 7" Csg Pt; Begin Dir @ 3.00/1OOft (it 6-1/8" Hole) : 9545.28ft MO, 7137.ooftTVD 7" Casing Target - CD2-29 (Heel), Current Target DrHlQuest 2.00.09.006 0 :x:J ~ ---- 72:2:: r-- Kuparuk River Unit Measured Depth (ft) Incl. Azim. 9600.00 88.641 151.848 9643.06 89.933 151.848 9700.00 89.933 151.848 9800.00 89.933 151.848 9900.00 89.933 151.848 10000.00 89.933 151.848 10100.00 89.933 151.848 10200.00 89.933 151.848 10300.00 89.933 151.848 10400.00 89.933 151.848 10500.00 89.933 10600.00 89.933 10700.00 89.933 10800.00 89.933 10900.00 89.933 11000.00 89.933 11100.00 89.933 11200.00 89.933 11300.00 89:~ 11400.00 ;::. 89.933. . - J". .:. . ..0: ".~. 11500.üQ,: ,:,.89:933" 11600.00. ,,' 89.933 11700.oó1» 89.933 11800.00 89.933 11900.00 89.933 Sub-Sea Depth (It) 7087.08 7087.62 7087.68 7087.80 7087.92 7088.03 7088.15 7088.27 7088.38 7088.50 Vertical Depth (ft) 7139.08 7139.62 7139.68 7139.80 7139.92 7140.03 7140.15 7140.27 7140.38 7140.50 Sperry-Sun Drilling Services Proposal Report for Plan: CD2-29 - CD2-29 (wp01) Revised: 4 July~ 2002 Local Coordinates Northings Eastings (It) (It) 1376.43 N 1338.47 N Global Coordinates Northings Easti (ft) 5172.92 E 5193.23 E 5975790.36 N 5975752.06 N 1288.27 N 1200.10 N 1111.93N 1~;~~ ~;:[¡~::~,~W;, ~7.42 N~~\.~t;'5456.06E 5 N . 5503.18 E N 5550.36 E 4%-~~~4 mE ~æ:~ "'é~¡¡¡!'~t;~~;~ 406:~i ~ 151.848 70~ii~>c" 318.40 N ::::t~3~~Ji::41.20 :::: 15t84-8;. .31 7141.31 53.89N JS1:848 , 89.43 7141.43 34.288 1-5fS43' .' 7089.55 7141.55 122.45 S 151.848 7089.66 7141.66 210.62 S 151.848 151.848 151.848 151.848 151.848 12000.00 89.933 151.848 12100.00 89.933 151.848 12200.00 89.933 151.848 12300.00 89.933 151.848 12400.00 89.933 151.848 4 July, 2002 - 12:36 7089.78 7089.90 7090.01 7090.13 7090.25 7090.36 7090.48 7090.60 7090.71 7090.83 7141.78 7141.90 7142.01 7142.13 7142.25 7142.36 7142.48 7142.60 7142.71 7142.83 298.79 8 386.96 S 475.138 563.30 S 651.47 S 739.64 S 827.81 S 915.98 S 1004.15 S 1092.32 S 5597.54 E 5644.72 E 5691.90 E 5739.08 E 5786.26 E 5833.45 E 5880.63 E 5927.81 E 5974.99 E 6022.17 E 6069.35 E 6116.53 E 6163.71 E 6210.89 E 6258.07 E 6305.25 E 6352.43 E 6399.62 E 6446.80 E 6493.98 E Page 6 of9 5434.51 N 5975345.54 N 5975256.58 N 5975167.61 N 5975078.65 N 5974989.68 N 5974900.72 N 5974811.76 N 5974722.79 N 5974633.83 N 5974544.86 N 5974455.90 N 5974366.93 N 5974277.97 N 5974189.01 N 5974100.04 N 5974011.08 N 5973922.11 N 5973833.15N 5973744.18 N 5973655.22 N 5973566.25 N 5973477.29 N 5973388.33 N 5973299.36 N 377089.63 E 377135.29 E 377180.96 E 377226.62 E 377272.29 E 377317.95 E 377363.62 E 377409.29 E 377454.95 E 377500.62 E 377546.28 E 377591.95 E 377637.61 E 377683.28 E 377728.94 E 377774.61 E 377820.27 E 377865.94 E 377911.61 E 377957.27 E 378002.94 E 378048.60 E 378094.27 E 378139.93 E 378185.60 E ~~~~#.h- orth Slope, Alaska Alpine CD-2 , -- .-- .,~~/}i~';'~~i1;~:C:~ '::êt.,r~~ft) .000 1226.86 .000 1269.92 End Dir, Start Sail @ 89.93<> : 9643.06ft MD, 7139.62ft TVD Comment 0.000 1326.86 0.000 1426.86 0.000 1526.86 ._~ 0.000 1626.86 0.000 1726.86 0.000 1826.86 0.000 1926.86 0.000 2026.86 0.000 2126.86 0.000 2226.86 0.000 2326.86 0.000 2426.86 0.000 2526.86 0.000 2626.86 0.000 2726.86 0.000 2826.86 0.000 2926.86 0.000 3026.86 0.000 3126.86 0.000 3226.86 0.000 3326.86 0.000 3426.86 0.000 3526.86 -.-/ 0.000 3626.86 0.000 3726.86 0.000 3826.86 0.000 3926.86 0.000 4026.86 Drí/JQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Repod for Plan: CD2-29 - CD2-29 (wp01) Revised: 4 July§ 2002 Kuparuk River Unit Measured Sub-Sea Vertical local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Easti (ft) (ft) (ft) (ft) (ft) (ft) 12500.00 89.933 151.848 7090.95 7142.95 1180.49 S 6541.16 E 5973210.40 N, 12545.41 89.933 151.848 7091.00 7143.00 1220.53 S 6562.58 E 5973170.00 N 4126.86 4172.27 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative;~,..tli~oith)L Vertical depths are relative to Well. Northings and Eastings are relative to Well. "<, ~."" " ....,,:dp~"þ. Magnetic Declination at Surface is 25.008° (01-Jul-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth -,- '-:..~. . Based upon Minimum Curvature type calculations, at æ~ The Bottom Hole Displacement is 6675.12ft., in ~iÓf 12545.41 ft., 100.536° (True). Comments ~~~~J~,. .:1.:,.::;- -;..",'-r- '. -""$ta tt~ n'>t 0 0 r din ate s "::~~?::"Northings Eastings (ft) (ft) O.OON O.OOE O.OON O.OOE 7.22N 26.93 E 191.46 N 451.62 E 431.49 N 961.22 E <:) :JO 8115.09 6426.23 1955.32 N 4196.45 E 9545.28 7137.00 1424.64 N 5147.12 E ---- 9643.06 7139.62 1338.47 N 5193.23 E 12545.41 7143.00 1220.53 S 6562.58 E ~.~ ,j 4 July, 2002 - 12:36 Comment SHL (1855' FNL & 1528' FEL, SEC. 2 - T11 N - R4E) Begin Dir @ 2.00/100ft (in 12-1/4" Hole): 350.00ft MD, 350.00ft TVD Increase in Dir Rate @ 3.00/100ft: 750.00ft MD, 748.70ft TVD End Dir, Start Sail @ 41.54° : 1873.09ft MD, 1754.23ftTVD 9-5/8" Csg Pt ... Drill out 8-112" Hole: 2722.51ftMD,2390.00ftTVD Begin Dir @ 6.00/100ft: 8115.09ft MD, 6426.23ftTVD 7" Csg Pt; Begin Dir @ 3.00/100ft (in 6-1/8" Hole): 9545.28ft MD, 7137.00ftTVD End Dir, Start Sail @ 89.93° : 9643.06ft MD, 7139.62ftTVD Total Depth: 12545.411t MD, 7143.00ft TVD Page 70'9 orth Slope, Alaska Alpine CD-2 Comment Total Depth: 12545.41ft MD, 7143.00ftTVD 4-1/2" Uner Target - CD2-29 (Toe), Current Target ~ -.' DrillQuest 2.00.09.006 ) ) --- SHL (1855' FNL & 1528' FEL, SEC. 2 - T11N - A4E) 0 - - ------ 1600 - 800 - Begin Dir @ 2,0"/10011 (in 12.114" Hole): / 35O',00ft MD, 35O'.00ft TVD .'~~ 6H,~~ I ,'.1.T!m,'" ,,:,', ',',"',', ,:,',......,.,11 .~.. ,,,,",, " ,:'~',., '. ~ Increase in Oil' Rate @ 3.0"/1 00ft : 75MO'It MD. 748.7011 TVD , II , "GrS>' I I ~ "Ø' i8 1/ End Dír, Start Sail @ 41.54" : 1873,09ft MD, 1754,23ft TVD Phillips Alaska, Inc. Coleville River Unit CD2 Pad CD2-29 (wp01: --."",,,,,,,, ¡ : "'ó>~- - ~ - ---- - , 9.5/8' Casing ; 2722.611 MD C.}O 1J.it'\rS>~ 2390.OftTVD 2400 ---:;:ro¡;I'IT'JTrr~- -.- .----.- ¡ 9-518" Csg Pt ... Drill out 8-1/2" Hole: 2722.51ftMD ,2390.0OOTVD ::J 3200 - C/) :E ë\J L() II CO ~ ~ :5 5r 4000 - (:) ~ t ~ 4800 - ~ II ] 5600 j¡i ~ (/) ¡ I ""7íJ7'; 07( ¡,êi> I -.. ~-- ~- I I II i .# Reference is True North ...&:>~ ~'.rr . Current Well Properties ~- _.~--...- -. Well: Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure: Ref. Geographical Coordinates : Plan: CD2-29 5974502.63 N, 371711.26 E 59.60 N. 7.25 W 7CY' 20' 18.8603' N, 151Q 02' 27.5748' W 1855' FNL & 1528' FEL, SEC. 2. T11N . R4E 52.OOIt above Mean Sea Level 52.00ft above Structure True North Feet (US) , . \) -- ---..- ._. 'b"I$>' .,. '-~'-"""'",.,.~" ....'-- RKB Elevation: North Reference : Units: rS>~ .4 Approved Plat) (wp01) #')) .'" rS>)) .é1' .¡..Jb:I' ~'~-~JI1: fC.-."irj¡c'''.c'':;r'''.'fNi.~'~~=-~:ÄV''"~~''Ç-1ï ." ,...B"~~~,.~.".,,,,-"IIì'! '., "J!it'!l.l',,,,~....... ~JJ;:,,,,.,..,, ,A, HtWÞUr1:!j;íft C:~ffÏ~ny ,0, -- -........---,- ~-, #~ .'\ ,=--. _. -,~-..-- - Begin Dir @ 6.0"/1000: 8115.0911 MD, 8426,23ft TVD I~ 6400 - ¡ 7" Csg Pt; Beg" Dir @ 3.0"'/100ft (in 6-1/8" Hole) : 9545.200 MD, 7137.0'00 TVD 7200--,m"T~~l-= ~;~~~~~~@~~~=~~~Ç]M , ~ --- /- 7" Casing " /' 12545.411 MD --- .,../' ..... 9545,3ft MD "'-" . / 7143,011 TVD i.,../' 7137.OftTVD CD2-29 (He.el) CD1.]9 (foe) .......-r"'" ..... 71J7Jj(j TH), 1424.64 N. SU7.12 ¡:; 714J.()(j lTD, 1220,S3 S. 6S6],58 E ~ ¡ I 4321' FNL & 1660' FEL SE~.., J. T11.N. R4E I 22f11' FS~. & 246' FEL,8EC 1 - TlIN . R4E 0 ~ 1~ ~ ~ ~ DrillQuest 2.00.09.006 Scale: 1 inch = 800ft UHIG L c Approved Plan (tlflp01) (i¡~~:'~; "":..':"""""',:-m,.,':','"....."':"'"",......'.,...'",.".::'"",:,.1.'",:.: .-':" .~<. '4{ .< ,., .~ ". .,' ~ Phillips Alaska, Inc. Coleville River Unit CD2 Pad CD2-29 (wp01) Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure: Ref. Geographical Coordinates : RKB Elevation : North Reference : Units : 0 I 2000 I 3000 I 4000 I 1000 I 2000- Begin Dir @ 6.00/1ooft: 8115.09ft MD, 6426.23ftTVD ~. ';) Reference is True North ø g> 1000 - :ë t: 0 Z -1000 - 0- - -- š ~ \I .c 0 .!: <D ãi 0 (j) -2000 - 0 1 1000 I 2000 1 4000 Eastings I 3000 Scale: 1 inch = 1000ff DrìllQuest 2.00,09.006 taU~'-~\..I.~," !t.tb~!~~':~~~~ ,~.~~~ttCt1m~ Plan: CD2-29 5974502.63 N, 371711.26 E 59.60 N. 7.25 W 70" 20' 18.8603" N, 151002' 27.5748" W 1855' FNL & 1528' FEL. SEC. 2 - T11N - R4E 52.000 above Mean Sea Level 52.000 above Structure True North Feet (US) 5000 I 6000 I 7000 I " \ \ \ \) ~~...., (1}1-29 (HeeD. .' '." . .. \\ }~ ¡§>"i> ft:tf,J 7137JifJ JVÐ, HUM N~ 5147.11 E ^ ;. \\ 9-5!8'Casil19 c,'Ø 432' PSI, & J6tjfì' PEL SEC 1- TUN - ¡UE ~ \ \ g¡¡:~o .- .' .. \\ ~ - ~. - ---.JJ:5!8" esg PL. Drin~t 8-1122 Hole; 2722.51~D,2390JJOf!TVD - ~ - ~ - ~ y ~ \. - ~ - ~ - - 0 End Dir, Start Sail @ 41.54°: 1873.09ftMD,1754.23ftTVD \ ~\ , \ Increase in Dir Rate @ 3.0o/1ooft: 75O.00ft MD, 748.70ftTVD \ \ ~ \ \~ þ~in Dir@2.0"/1ooft(in12-1/4"HOle):350.00ftMD,350.00ftTVD\\ '.\ 4-1i2"Uner Total Depth: 12545.41ft MD, 7143.ooftTVD \ ~ i~~Öf~~~g - -1000 SHL (1855' ~NL & 1528' FEL, SEe. 2 - T11 N - R4E) " I / / 7" Csg Pt; Begin Dir @ 3.00/100ft (in 6-1/8" Hole) : 9545.28ftMD,7137.00ftTVD ~ f~' - 2000 End Dir, Start Sail @ 89.93° : 9643.06ftMD,7139.62ftTVD - 1000 CD1.].9 (f<.l('j 7141.00 JTD, 122(1.5.1 S. 6561.58 E 21(12' Fst & Uf¡' FEL. SEC.1- TlIN. R4E - -2000 I 5000 I 6000 I 7000 ø 0> C :ë 1::: 0 Z ~' ð 0 ~ \I -£ .s à) 1; (j) ) Sperry-SuD Anticollision Report eonipsfI)': . PhilJ.iPß AiasIG:!. Inc. . 1<'ield: , Co\éville River Unit , Rtter~nçe Site: . AlPine CO2 " Refer~ltçe Well: Plan: 002.29 R~fçtenceW.cUpatb:, CQ2-2~ . GLOBAL SCAN APPLIED: All \\'cUpaths wiOlin 200'+ 100/1000 of reference Interpolation Method: MO Interval: 50.000 ft Uepth Range: 36.950 to 12546.593 ft Maximum Radius: 1450.964 ft Survey Program for Uefinith'e \\'eUpalb Date: 6/27/2002 V~alldated: No Planned From To Sune~' .J)',tfe: ,7/4/2002 (~~-ôrdinat~Ê) Refere~e: . Vertical (T\'lJ) Referen~e: Version: T onlcode 2 thur:12:47:39. ) Well: Plan: CD2~29, True NOrth CD2..29 52.8 . Pagè,: I Reference: Error Modcl: Scan Method: :Error Surface: Db: ' Oracle. Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tom Name 36.950 1000.000 1000.000 12546.593 Casing Points 1\(1) . ft, 2722.488 9546.000 12546.500 Planned: C02-29 (wp01) V1 Planned: CD2-29 (wp01) V1 U1> « 2390.000 7137.805 7143.980 .Dia~1J~ter . in . 9.625 7.000 5.500 ßolr Size , in Name' 12.250 8.500 6.000 95/8" 7" 5 1/2" " $~JlJ:J,Itn' , - . <.~~--'.~~--.-.~~~_._"~~t\\;enp~~~~~--~-~~--~-_._--~> " Site 'WeD 'WeUpath Alpine CO2 ¡II; 'Alpii1éÖD¿ .', Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CO2 Alpine CD2 Alpine CO2 Alpine CO2 Alpine CO2 C02-14 ?jli!ii ¡! '<QP~..~~ . "CD2~25 '. .. C 02-26 C02-26 C02-26 C02-32 C02-32 C 02-33 C02-33 C02-33 C02-3-t C02-34 C02-35 C02.39 C 02-39 C 02-41 C02-42 C 02-42 C02-45 C02-46 C02-47 C 02-49 CO2-50 CO2-50 Plan; C02.28 Plan: C02-28 Plan: C02-16 Plan: C02-23 Plan: C02-23 Plan: C02-44 C02-14 V1 C02-15 V1 C02-15PB1 V1 C02~15PB2 Vl . C02.17 VO C02-19 V3 C02-20 VO C02-22 VI C02-24 YO C02-24PBl V1 C02-25 VI C 02.26 V3 C02-26PB1 V2 C02-26PB2 V2 C 02-32 PB 1 VO C02-32 VO C 02.33 V2 C02-33A V1 C02.348 Vl C02-34 V3 C02.34P81 V2 C02-35 VO C02-39 V1 C02-39PB1 VO C02-41 V2 Plan: C02-41 C 02-42 VO C02-42PB1 VO C02-45 V1 C02-46 V2 C02-47 V2 C02-49 V1 C02.50 V2 C02.50PB1 V2 Plan: C02-28 PB1 V1 PI Plan' C02.28 VO Plan. Plan: C02-16 V4 Plan: Plan: C02-23 VO Plan: Plan: CD2-23PB 1 V7 Pia Plan: C02-44 VO Plan: CB-GYRO-SS MWO Camera based gyro single shot MW 0 - Standard Reference Offset MD MD ft ft 702.331 700.000 550.483 550.000 550.483 550.000 '550:483' 550;000 1048.654 1050.000 1050.256 1050.000 36.950 32.850 748.828 . . ..' 750;OOCr ...:..',..',55'" ooo"""'..:o...,:...,;......øO:...060".,'..t)"'.."'..""'." 5.00;000. ".'~ÖÔ)ØÖO . 59951'7 PMtröoo 950 630 950 000 499.266 500.000 490.240 490.950 449.779 450.000 449.779 450.000 449.715 450000 449 715 450.000 449.715 450.000 449.564 450000 449.564 450.000 399.825 400.000 249.990 250000 249.990 250.000 449.445 450.000 498.799 500.000 498.799 500.000 349.966 350.000 399.557 400.000 349.956 350.000 249.995 250.000 448.804 450.000 448.804 450.000 349.955 350.000 349.955 350.000 1867.546 1850.000 400.005 400.000 400.005 400.000 349.955 350.000 Or-Ctr No-(;() Distance Area ft ft 151.032 11.766 141.332 141.332 10.015 131.325 . 141;3$g. '. .".. '..1f~Þ()5< 'Jta1:d ,""iQ1j~à7 .' . 84 06111./126>6(j:66Ö . .,.'.:....,~55".'.'.':o4....'.'.....'......~...O.41..1'.'..'..'...80':~M..'........43.'.."'.'."........'......,.....1."2a' .'~...O4. na.1....7.:..' ..'.. 52 529 .: =:1':= '40:0Sf::~~g ".30.127 36.813 24.043 8.513 15.550 23.249 30.694 30.694 41 .402 41 .402 41 0402 44.211 44.211 61.906 100.923 100.923 118.068 131 .881 131.881 159.170 171.065 181 015 200.779 209 821 209.821 11.237 11.315 62.650 61.265 61 265 150.916 7749 ï 749 7380 7.380 7.380 8.339 8.339 6.875 4.343 4.343 8.325 8.250 8.250 6.186 6.684 6.232 4.356 8.319 8.319 7.305 7.300 44.703 7.801 8.020 6.435 Alllt\'l'able Dc,'iation WavninK ft 139.267 22 949 22.949 34.051 34.051 34 051 35 877 35 877 55 033 96.582 96.582 109.744 123.650 123.650 152.985 164.382 174.ì85 196.423 201.501 201.501 3.933 4.017 21.401 53.466 53.247 144.485 Pass: Major Risk No Offset Errors Pass: Major Risk ...'. ~~~~r~~~r~~..'.. .' Pass. Major Risle No Offset Stations Pass: Major Risk Pass: Major Risk . Pass: Major Risk ". PasS: Major Risk No Offset Errors Pass: Major Risk No Orrset Errors Pass: Major Risk Pass' Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass. Major Risk Pass: Major Risk Pass' Major Risk Pass: Major Risk Pass. Major Risk Pass: Major Risk Pass Major Risk Pass. Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass' Major Risk Pass: Major Risk Pass' Major Risk Pass~ Major Risk Pass: Major Risk Pass: Major Risk Pass' Major Risk Pass: Major Risk O~f. ~ .,.,.;p, I ! I ì <:::)1 ~-' ---- ""'-'",,-- I [--I .rune. '1m: CDl-29 -13&.764 -65 -(¡() -40 "'-:20 -0 -20 -40 -00 -65 -+N/-S WEILDIITAIlS .FJ. W NortIiDg Eas1ing LaÛlId<. LoogÍluk Sbt 17.398 59745(12.63 37111116 7(f"JJJ 18.86(N 151'(YZ2751SlV N'A A.NTI-COLLlSION SETIINGS InkIpolatiQn Methvd:MD Interva1: 50,000 Depth Range From: 36.950 To: 12546.593 Maximum Range: 1450.964 Reference: Plan: CD2-29 (wp01) (J 1-1{j' Travelling Cylinder Azimuth (1FO+AZI) [deg] vs Centre to ('..entre Separation [20ft/in] COMPANYÐEf,4JtS P'-~~~,;"'" 7;:~. Ce.b<iÎitfii:aMet..~ Mm'!mmOrA..~ :-:= ~V~~~q!1J¡ w~~=~ ~~?mg From 0 200 400 600 800 1000 1500 2000 2500 3500 4500 5500 6500 7500 8500 9500 10500 11500 12500 Colour T..' \ID 1ilt) 41)(1 601' ~.I1I III{'I) ~Ijl) ]lIUI) ~~(H) .;';(11) ~~,-,,) '=:.5(11) f.~, ji) "75f~') ¡'';(J'} '~.1'1) !li)¡)Q II)I)Q l':~c)O 1-1I.h)O 90 WB.IJ>A'IHDBTA!I$ CD2-29 Ri¡ç P.e.f [€(~ Doym19 CŒ-Z9 -5i..g$ft v~~ 2 :;~ ~'f,,1) O,f,)O O.OCIt) LE '.;E ',[¡ -.~..--; CDZ-J-ttCD:' IJI MJ"r R.J~.~ ,,'D: IS .l1.: 151 \h¡..r 1<...- - CD] JS,c[>~ j:;Pr.!;. ~hl"r........r' ([I~ i5;li'2 I'¡'R> \1...1'" R...I ~ l'l)] I; it l'~ 1", '11101"1 KA. C[)~ pi 'Cl<~ 1iJ.I. M~I~lr RL-Io. - ([.:-~() ,("Ú~.~lJl \1tLl~"'E Rl;;'~. - I'['~ ~2{cn:..'> \J..,,;rR..;J. -.-.. CI)~ 2.J t{-'V~ :-11 .\III"~ R1_..;~: - I:D~ ~~ lID: 2-1PÐI. \hl'" R1;.1. - CfJ~ ~(C[)2-~:,1 \td~,'TRcj.. - 1_'l}':::-~f'\IC[J:;: ~f.1 \LI\.IJ" RL...t - C[I.' ~",CF! 2':ñ'SI, M.,." R1:;k C[(!.26 \~'L'2 ~"r¡;:, \\.1,.., ¡;i'i. - "[J:' ;2ICV2_:2PBI.. \1.!..,RJ.'~- - CL'? -': ,cú" .'"". M.,!ÜI f{¡"f. - CD::hl.'[¡2 \.;, M..¡",Rc" - CP2 ;~.C[12 ~".\, I\b<',rR."k - CD: 1_' ll'[;2 .qB. M"", R..,!.. -- '..'[J:-.~1 (C[J~-.~.1 '. ~lJ1"1 R1.~k - CD:'- .1-1 I CD.:' -~-1Pp. J .': ~~h.r Pu.¡J.. cD2 :.:. ".-D':: -~~'- \tl1'õí R.1.-L. ~ CD~ ;" ~~-"1J.: .~Ii,- ~t31~IT r':.j~t , D>'" .,'ú2 ~\'.PD I) M"lp, Rr,l. _. .00 ..- [J:-~ I ICD;: -111 '1.1.""1 R.I':' cv~-~:: ¡C[J; -:I:" \4J-,"'1 JtL-k I [)~--1:!\nI2"'¡21'F;l '. M..,,,, R, I. C['~-1-i ,,'[~ -1<,' \hr" k,"~ --..-. c[,~ -V..'("ÚZ-¡r" \-h,." kJ3~. . '¡¡:.r IClI2-17,. '",,'.r IbA - lD:'...jl',CD2--1", \1.'1'" rill!; l',2 c;¡;.( .¡¡Z :;(1) M"I,',II:1_.'. - CDl-C;hC[,~ '-uPBII. \IJ"" [I".], - Pl.s11 cr1~;~ \PTdn C[-,~ ;?:L-. pr;ll. - f'L.n l [1: 2"". PI.,,, l,['2 2>1 '. "'1.11' - Pl.1n L'D~ II-"P!Jr' Cú: IfJ' \t.,., ~ PI,,¡n t 1J2 2~ . Pl.d! elf?-:'_" . - PL." C[r.. 2_11Phn CD? :<: - PI..u C[J:-W(PL" C[;:~'- .. ~. ~,..L'2 Z'J CD2-29 (wpOl) Approved Plan (lìf~VD ) \fame. 'Ian:CDl.29 .13&764 <.:) ~.J -...- Ç~) -ffl ---""" i~ --65 -60 -40 -20 -0 -20 -40 -65 WElLDEfAILS ANTI-COLLISION SE'ITINGS ~N:.S ~Fj. W NonIiog 17.398 5974502.63 Loogih.k Sbt EaS1ing LalÌtm ~~h~~;W~:~50 ~~rval: 1~<:593 Mari:mwn Range: 1450.964 Reference: Plan: CD2-29 (wp01) 371711.26 ï(f'2(/18.00i:N 151'0l27.51SW NfA Travelling Cylinder Azimuth (1FO+.AZI) [degJ vs Centre to C..entre Separation [20ft/in] COMPA!'¡YŒIML$ ITS"'" ~~uMelhM; Nmmm01i"A~ &':or s- ISC~'&>. s..~~>d; TRVC~N~ w.==~~~ Fr..ffi Colour (¡ 21M JI Jlf (i}(, ~()() I.. 'ID ~Ot' ~Ù(J (iUI ~:j)1 liJl[) I ~Ij¡") ~tllJi] ~~¡¡ii _~';;Ci) 4~I!O 5~iJlì 1'>5 I)! , 7"'\i, ~~"(i¡) 90 \VR.Il>A1HDEI'AIIS (1)2-29 Ri¡ç 1<6£ DruUI: [K.m:¡ 19 crtJ-29 52.&50i v.~ ~ Z~ ~"f,,'D i('Ú.~~ (¡J,J(! l[. q'-,;{. C[I:. H (CD:' I'll M"-I"r K.,.' .D:I-"CV:I~\"hl,,'k1:. . - C[¡~ 1,,\.'[>2 ¡:ii'SI!. M"¡''Il_i! -_.~-~ U,: I~lr..! 15PÐ~.. \bj." f.:J.Jt - (_"U2 i"'; 'l r)~ ,'1, VbJ~"r f.t..l.."~. . CD: ,., '('!'è I'". M."..r Rd. - ('D~ 20 ;1',.: ~(), .!"1.,." KI'.k - ~~r~ ~~ ~~~~ ~~: .~~!~~ ~~~ . I 'D~ ~111'[(: ~..Þf\ I. \l~<'1 kJ,.I,: C[)~ :5 'C['.' Z:.¡ \1..,,-,. R~,I: . \.'l)~ ~f"c[l2 ":e.i \f IJI,,1f RJ~.~ . -:-: fg~.~~:g~ ~::g~:: ~~~:~: ~t. - t 'ú: .;Z It I']. '.' PBI. \L)..1 Rr,k - \' Q] ~2 .([1: 5.:" M.IC1 R1:.f; . - ~;D: .~j ¡. .[¡Z ..,ò; "L,n, Rd. - C[¡~ ,~.CQ~ .~A., M.1I')'-~' - ('D] ."'.('[(' 3.Hh :'111"1R..,}. ~ t [;! 3~ ,C[>'¡~" \-1-.", Rl'~ . - CD?,.;:'I ,CD:..4í'Ð!'- \b¡"r R.d.' n:.: ~5 ,'.'D2 y:. \Ili'.r R...~. ~_. CO2 ;Ij (CD~ ~~I'p. f..bll"ß RI._~}. - I r.'~.... ¡("[)2 !.I>PDII ,"".in, RI',!, þ. .0. I'f,?-.., ,Cl;Z4P. M.lf'" I{¡,-k :"~:~~l~ ;~~~:~~~~[;~~.~,~1.~~.~\.L-I.' CO].F (C[;l-J~I \1",.r R,,-I -,,,,,.,. ('[;2 .1~,,\'[)] -Ir". ;\hl'" kJ:.k .. "[j2"-r'? If l1~.J";',. M.11~" Jb:~ --- CD:' -N ,C[)':: -I~~I \t1i~.r ~ lTI~ 5,,,l'[1~ <:/1. '0.1.'1" 11Y~ .' - CD:.,t1ICl>~ <IJPPI' ,\1:.1'.' Rd" - f'!.so f_"D~ i~ ,;rJrl C[\~ :!~ p~: ~~ - f'llrt. C[\~ ~~~rPL(¡ (lI2l~r" \I.Lrl - ['!.w cr.: '''',PI"" ('['],1"". \4"t - PI,," l [I;: ::,; ¡Pl.,,, C['::'~." - Pb!1 CD] 2_( tP1~f.I. ~lì'::-2.~.. J - PLw CD: -1--'1( I'L.', L L > 1-J! -.-' -- ("l)~::w .~. C [)~ '.'" , "-r~J' . CD2-29 (wpOl) Approved Plan (MWD+IIFR) ') ) Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 10, 2002 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-29 Dear Sir or Madam: Phillips Alaska, Inc. hereby ~pplies for a Permit to Drill an onshore WAG (water alternating gas) injection well from the Alpine CD2 drilling pad. The intended spud date for this well is August 18, 2002. It is intended that Doyon Rig 19 be used to drill the well. CD2-29 will be drilled to penetrate the Alpine reservoir at horizontal. After setting T' ~ intermediate casing, the horizontal section will be drilled and the well completed as an open hole injector. At the end of the work program, the well will be closed in awaiting completion of well work and facilities work that will allow the well to begin injection. Note that it is planned to drill the surface hole without a "'erter. There have been 38 wells drilled on CD1 pad and 21 surface holes drilled on CO2 pad with no significant indication of gas or shallow gas hydrates. 20 of the 21 wells on CD2 have surface casing shoes within a 2200' radius of the planned surface casing shoe of CD2-29. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: . Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed pilot hole schematic. Proposed completion diagram. Pressure information as required by 20 ACC 25.035 (d)(2). CD2-29 Cementing Requirements. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). . . . . . . . . I nformation 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. RECFI\lFD JUL 1 5 2002 Alaska au & Gas Gons. CommiSSion - Anchorage ) If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ) ~IY~~ ' Vern Johnson Drilling Engineer Attachments cc: CD2-29 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer ATO 1530 A TO 868 ATO 848 ATO 844 Nancy Lambert Lanston Chin Anadarko - Houston Kuukpik Corporation e-mail: Tommy_Thompson @anadarko.com ECEtVED JUL 1 5 2002 .t\laska Oil (& Gas Gons. commiSSion Anchorage ~ ~ )J . =~ õ~ 0 0 0 0 0 0 ~ .. - .. ... 0 ~ ... 0 0 OJ ru ~ .. 0 0 [p ... ... [p ... .. ( -~-- II ~ 'á i :s: ... jj: ~ ~ ~ ~ ,! . ~ ~ ,ji i ~ '. . I":,~ ,~ "t ,,I, .t. .u. .:,~ ~ ;':! , .. ,~ '. ", :~ ;! "l ~,;~ ~ ,~ ,'~ ,,:1:: ,. ,. , '. '~ ë ;,;;:. '.u. :~ ,I. Ii ,~ - ,.u. .~ ,o:!' ."~ I I ,~ #..:- ~..;..-- ( ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME C/J 2- -2 7 PTD# 202.-/~? CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production should continue to be reported as a function. of the original API number stated above. In. accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation. order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. (Service Well Only) GEOLOGY APPR DATE jfJ~ -ø11p- I(E~ploratory Only) Cl< Vc WELL PERMIT CHECKLIST COMPANY /i. 'J/ /, ~ WELL NAME ({) Z. - 2. ( PROGRAM: Exp - Dev - Redrll- Re-Enter - Serv Ã- Wellbore seg - FIELD & POOL 1<... 0/0 I"! (NIT CLASS / - b' J 7 / .-Jl. r'J, GEOL AREA Y f CJ UNIT# 0 ~ () :l boON/OFF SHORE .QL!) ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N r J / J/ jJ1 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N ¥ ?:?: ~ c:.. l./I/ ./JP -i c:::;// ¿:(.Jyt!Þ ./ø..~' ð,l) 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 ,APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ',' JJ .&J.~ -7 JHÞ'¿::1 - 8. If deviated, is weHbore plat included.. . . . . . . . . . . . . . Y N ~ ~trG/ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . .. . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . Y N (Service Well Only) 13. W ell located w/in area & strata authorized by injection order # - Y N (5erviceWell Only) 14. All wells w/in X mile area ofreviewidentified.~ . . . . . . .. 0 N r~'N..~~~""'~~ <:..:~~-\" '\ ~~~~~S~ ~~\\ ~ ~~ ~,~ ~'~\~Ct.. ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 0 N ~'''-...~\u..~CV ~,,~~~~<t ~c<c'-\ to 16. Surface casing protects all known USDWs. . . . . . . . . . . Cà N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . ø N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~(N) 19. CMT will cover all known productive horizons. . . . . . . . . . ~N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ~~.\\" ~ 't"''' ~ \'\.0 ,~e-r-...)~ ~, ~ 22. If a re-drill, has a 10-403 for abandonment been approved. . . ¥-N' ~ ~ . C"\ (" ~ 23. Adequate well bore separation proposed.. . . . . . . . . . " ,0" N c- \C\ ,ç. ~ P.~~c}"'c-'" '\ ~~\-\"" \: Il" ~ 24. If divert, er required, does it meet regulations. . . . . . . . . . *<45 N W t:J.." ~ YO"" s.-:þ' . 25. Drilling fluid program schematic & equip list adequate. . . . . Y N 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . Y N 27. BOPE press rating appropriate; test to ~ 000 psig. Y N t--^'-~? ~"">~ (V :J.. s \ ~ I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . .~ N . V-1GÆ 1/ f-!,e'1.- 29. Work will occur without operation shutdown. . . . . . . . . . . VN 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y <M> . ~ - f\ 31. Mechanical condition of wells within AOR verified. . . . . . . . ~ N ~~f(\\ ~ ~\~"\,,\/,, ""\G- <::!. ~~ c-:\ ~\~'U'l ~fÐ~ 32. Permit can be issued w/o hydrogen sulfide measures. . . . .~N 33. Data presented on poten, tial overpressure zones. . . . . . . . ,y N //.1 Lì, 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / '-' (,j (17 \. 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . N 36. Contact name/phone for weekly progress reports. . . . . . . . Y N G~: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER RP r: TEM ~. JDH ()I-- JBR ~ C£Jz.. rllJc APPR DATE Rev: 07/12/02 SFD- WGA W&k' MJW COMMISSIONER: COT f DTS 0 7 J2..~ 0 <: Comments/Instructions: G:\geology\perm its\checklistdoc ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplffy finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special'effort has been made to chronologically organize this category of infonnation. Sperry-Sun Dri_)bg Services LIS Scan Utility a.o~-Iq.g 1,b¿:¡t $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 02 15:05:45 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-29 501032042700 ConocoPhillips Sperry Sun 08 -APR- 03 Alaska, Inc. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22162 M. HANIK D. BURLEY MWD RUN 3 AK-MW-22162 M. HANIK D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 11N 4E 1855 1528 MSL 0) .00 52.55 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2672.0 6.125 7.000 9556.0 # REMARKS: ') ) 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 100 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 200 - 300 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS,ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) AND PRESSURE WHILE DRILLING (PWD). 5. GAMMA RAY ON MWD RUN 300 HAS BEEN CORRECTED FOR KCL MUD AND ALSO BOREHOLE CORRECTIONS WERE APPLIED TO ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. MWD IS CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 9/26/01. ALL MWD LOG HEADER DATA RETAIN ORIGINAL DRILLERS DEPTH REFERENCE. 7. MWD RUNS 100 - 300 REPRESENT WELL CD2-29 WITH API #50-103-20427-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12,560 MD, 7127.26 TVD. SROP = SMOOTHED SGRC = SMOOTHED SEXP = SMOOTHED SESP = SMOOTHED SEMP = SMOOTHED SEDP = SMOOTHED SFXE = SMOOTHED RATE OF PENETRATION WHILE DRILLING. GAMMA RAY COMBINED. PHASE SHIFT DERIVED RESISTIVITY PHASE SHIFT DERIVED RESISTIVITY PHASE SHIFT DERIVED RESISITIVTY PHASE SHIFT DERIVED RESISTIVITY FORMATION EXPOSURE TIME (EXTRA SHALLOW SPACING) . (SHALLOW SPACING) . (MEDIUM SPACING) . (DEEP SPACING) . $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 F i Ie Typ e . . . . . . . . . . . . . . . . La Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPD FET GR RPM RPX RPS ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2626.5 2626.5 2635.0 2651.5 2651.5 2651.5 2682.5 STOP DEPTH 12508.0 12508.0 12501.0 12560.0 12560.0 12560.0 12559.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ ) ) # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 2626.5 3 9565.5 MERGE BASE 9565.5 12560.0 # 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. . . . . . . . . . . . . . . . . . . . . . -999.25 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2626.5 12560 7593.25 19868 2626.5 12560 ROP MWD FT/H 0.19 342.8 151.006 19755 2682.5 12559.5 GR MWD API 30.01 353.87 96.7853 19733 2635 12501 RPX MWD OHMM 0.05 2000 9.03949 19747 2651.5 12560 RPS MWD OHMM 0.05 465.934 9.3606 19747 2651.5 12560 RPM MWD OHMM 0.05 2000 9.95065 19747 2651.5 12560 RPD MWD OHMM 0.11 2000 13.4635 19656 2626.5 12508 FET MWD HOUR 0.1942 64.4118 1.21009 19693 2626.5 12508 First Reading For Entire File....... ...2626.5 Last Reading For Entire File......... ..12560 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ La 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......., )06/02 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 FET RPD GR RPM RPS RPX ROP $ 2 ) header data for each bit run in separate files. 2 .5000 START DEPTH 2626.5 2626.5 2635.0 2651.5 2651.5 2651.5 2682.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRI~LER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9510.0 9510.0 9517.5 9510.0 9510.0 9510.0 9565.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTRO MAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 01-0CT-02 Insite 66.37 Memory 39.7 85.5 TOOL NUMBER 136692 121079 8.500 2672.0 LSND 9.70 42.0 8.9 400 .0 2.400 1.272 2.600 3.000 72.0 141.8 72.0 72.0 # ) ) 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. . . . . . . . . . . . . . . . . . . . . . -999.25 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 MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2626.5 9565.5 6096 13879 2626.5 9565.5 ROP MWD020 FT/H 0.63 342.8 180.13 13767 2682.5 9565.5 GR MWD020 API 41.09 353.87 115.398 13766 2635 9517.5 RPX MWD020 OHMM 0.3 34.66 4.94907 13718 2651.5 9510 RPS MWD020 OHMM 0.06 32.37 5.00647 13718 2651.5 9510 RPM MWD020 OHMM 0.14 2000 5.44756 13718 2651.5 9510 RPD MWD020 OHMM 0.11 2000 12.1347 13768 2626.5 9510 FET MWD020 HOUR 0.19 40.06 1.09806 13768 2626.5 9510 First Reading For Entire File........ ..2626.5 Last Reading For Entire File.......... .9565.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...03/06/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type............... .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 FET GR RPS RPD RPM RPX ROP $ 3 ) ) header data for each bit run in separate files. 3 .5000 START DEPTH 9514.5 9518.0 9546.0 9546.0 9546.0 9546.0 9567.0 STOP DEPTH 12508.0 12501.0 12560.0 12560.0 12560.0 12560.0 12559.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O 06-0CT-02 Insite 66.37 Memory 87.9 94.3 TOOL NUMBER 156435 167218 6.125 9556.0 Flo Pro 8.90 46.0 9.4 15500 4.2 .150 .071 .250 .340 69.0 153.0 69.0 69.0 . .. ) Logg~ng Dlrectlon. . . . . . . .. ~..... . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999.25 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 MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9514.5 12560 11037.3 6092 9514.5 12560 ROP MWD030 FT/H 0.19 223.49 84.0616 5986 9567 12559.5 GR MWD030 API 30.01 72.23 53.8456 5967 9518 12501 RPX MWD030 OHMM 0.05 2000 18.3466 6029 9546 12560 RPS MWD030 OHMM 0.05 465.934 19.2677 6029 9546 12560 RPM MWD030 OHMM 0.05 1576.62 20.1967 6029 9546 12560 RPD MWD030 OHMM 0.05 1738.82 23.6823 6029 9546 12560 FET MWD030 HOUR 0.41 64.41 2.09356 5988 9514.5 12508 First Reading For Entire File......... .9514.5 Last Reading For Entire File.......... .12560 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ La Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name....... ..... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Next Tape Name.......... . UNKNOWN Comments. .......... ..... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. .............. .UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services ) ) Physical EOF Physical EOF End Of LIS File