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Home My WebLink About203-118MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 24, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-55 COLVILLE RIV UNIT CD2-55 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2024 CD2-55 50-103-20463-00-00 203-118-0 W SPT 7302 2031180 3000 2253 2253 2247 2249 675 690 690 690 REQVAR P Austin McLeod 6/9/2024 Two year to MAIP. AIO 18D.002. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD2-55 Inspection Date: Tubing OA Packer Depth 1200 3300 3240 3240IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM240609193723 BBL Pumped:2.4 BBL Returned:2.4 Wednesday, July 24, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 AIO 18D.002. James B. Regg Digitally signed by James B. Regg Date: 2024.07.24 12:32:13 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD2-55 COLVILLE RIV UNIT CD2-55 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 CD2-55 50-103-20463-00-00 203-118-0 W SPT 7302 2031180 3000 1836 1838 1836 1838 829 847 847 847 REQVAR P Matt Herrera 6/28/2022 MIT-IA Performed to MAIP Per AIO 18D.002 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD2-55 Inspection Date: Tubing OA Packer Depth 1080 3320 3280 3270IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220629150117 BBL Pumped:2.6 BBL Returned:2.6 Thursday, July 21, 2022 Page 1 of 1         Regg, James B (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, July 17, 2020 3:11 PM+ To: Regg, James B (CED) �J IZ(J Cc: Brooks, Phoebe L(CED) Subject: RE: [EXTERNAL]RE: CPAI 10-426 Forms From MIT's on 3M & CD2 Pads CRt C)z- 55 Hi Jim, p7,b 705((,60 Thank you for your time this afternoon. I wanted to summarize our phone conversation regarding not having an approved extension for these wells. These wells were shut in for facility maintenance during the month of June when the compliance testing was due. Knowing that the repair would soon be completed, rather than testing the well twice within two weeks, first offline then online, the decision was made to wait and test with AOGCC witness when online. The wells were brought online June 291h, which did not allow time for stabilization before testing by the end of the month, in turn, delaying testing into July. I apologize for the lack of communication regarding the planning for testing these wells and will share this event as a lesson learned to our team. Sincerely, ScwwCairUg& (YPiAi*v) � Stiephan6ePadv Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com From: Regg, James B (CED) <jim.regg@alaska.gov> Sent: Friday, July 17, 2020 1:31 PM To: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Cc: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov> Subject: [EXTERNAL]RE: CPAI 10-426 Forms From MIT's on 3M & CD2 Pads MITs for CD2 -51 and -55 were due NLT 6/30/2020. Please forward a copy of the AOGCC approved extension. Jim Regg Supervisor, Inspections AOGCC 333 W.Th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or lim.regg@alaska.zov. From: Well Integrity Compliance Specialist WNS & CPF3 <n2549Ca@conocophillips.com> Sent: Wednesday, July 15, 2020 5:05 PM To: Regg, James B (CED) <lim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe. bay @a laska.gov_>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; Wallace, Chris D (CED) <chris.vvallace(@alaska.gov> Subject: CPAI 10-426 Forms From MIT's on 3M & CD2 Pads All, Please see the attached 10-426 forms for MIT's recently completed on 3M and Cc12 pads. Sincerely, Saect,CGWwdu-i NeO, f4v) I(StephaniePadv Well Integrity & Compliance Specialist, WNS & C1PF3 KOC F-218, ConocoPhiilipsAlaska Office: 907-659-7126 ( n2549(&cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.corn STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iimreng(ciialaski tion A0GCC.Inspectorst9italaska.gov: ohoebe.brooks0alaska.aov OPERATOR: ConocoPhillips Alaska Inc. FIELD/UNIT/PAD: Alpine/CRU/CD2 PAD DATE: 07/14/20 OPERATOR REP: Duffy AOGCC REP: Waived by Lou Laubenstein chris.wallace(malaska no Well CO2 -51 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4=Four Year Cycle F=Fell PTD 2022490 Type Inj W Tubing 2045 2045 2045 2045 N = Not Injecting Type Test P Packer TVD 6948 BBL Pump 3.0 IA 1010 3300 3275 3270 Interval V Test psi 3000 BBL Return 3.1 OA 800 810 810 810 Result P Notes: MITIA to maximum anticipated injection pressure per A1018C.010 Witness waived by Lou Laubenstein Well C132-55 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031180 Type Inj W Tubing 1830 1830 1830 1830 Type Test P Packer TVD 7325 BBL Pump 2.8 IA 1090 3300 3280 3280 Interval V Test psi 3000 BBL Return 2.9 OA 790 807 811 813 Result P Notes: MITIA to maximum anticipated injection pressure per NO 18D.002 Witness waived by Lou Laubenstein Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. PTD Type Inj Tubing Type Test Packer TVO BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test 1=Initial Test P=pass G=Gas O= Other (describe in Notes) 4=Four Year Cycle F=Fell S=Sluvy V= Required by Variance I-Incanclusive I =Industrial Wastewater O = Other (describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) MIT CRU CD2 -51 55 07-14-20 • • c,ebt Cb 2 - 5 % ir<bo Regg, James B (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Friday, October 13, 2017 1:28 PM ' ' I 1°1(3/I.? To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA);Wallace, Chris D (DOA) Subject: MIT Forms Attachments: MIT CRU CD2-55 Diagnostic 8-4-2017.xlsx; MIT CRU CD4-27 10-11-17.xlsx Hello All— Attached, please find two 10-426 forms for MITIAs performed at CRU. One is a non-witnessed diagnostic MITIA performed at CD2-55 in August,another for a recent witnessed MITIA at CD4- 27. Please let me know ifou have anyquestions. Y Travis scoot 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaq(cDalaska.ciov AOGCC.Inspectorsl5talaska.gov - phoebe.brooks(cdalaska.dov chriss..wa��a�llacet5 alaska.dov OPERATOR: ConocoPhillips Alaska Inc, 'C (DI(It.7 FIELD/UNIT I PAD: Alpine/CRU/CD2 Pad DATE: 08/04/17 1. OPERATOR REP: Winter - AOGCC REP: N/A • Well CD2.55 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031180 ` Type Inj G Tubing 1700 1700.. 1700 - 1700 - Type Test P Packer TVD 7128 ''BBL Pump IA 1491 3005 • 2965'- 2960 - Interval 0 '/ Test psi 1782 ," BBL Return OA 650 - 650 - 655 - 655 . Result P ,/ Notes: Non-witnessed diagnostic MITIA. ✓ Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test I Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test • Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA - Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT CRU CD2-55 Diagnostic 8-4-2017 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday, October 11, 2017 6:07 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: CD2-55 (PTD 203-118) Chris, Alpine injector CD2-55 (PTD 203-118)exhibits TxIA communication on gas injection, but diagnostics and a monitoring period demonstrate that the IA does not re-pressure during water injection service. The leak detect log referenced below was performed,and although there were areas of interest it didn't show results we believe we can immediately act on to restore gas injection service. We may pursue further steps in this regard, and will update you if we do. For the time being,CPAI intends to return CD2-55 to water injection service and submit paperwork proposing Administrative Approval for water-only injection. Please let us know if you have any questions or disagree with this plan. Regards, Travis : NSK Well Integrity Supv CPF3 and WNSSC N��r ,x ;, ,`,) Sent: unday,August 27, 2017 2:33 PM To:Wal ce,Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, .Tyler<R.Tyler.Senden@conocophillips.com> Subject:CD2- 5 (PTD 203-118) Gas LDL Chris, Alpine injector CD2-55(PTD 203 8)was previously reported and identified with TxIA communication while on gas injection. The well is nearing the en. . its water injection monitor period and to date has shown no signs of communication. In order to further invest :.to the gas-only leak source and potential repair options,CPAI intends to perform a gas leak detect log(LDL) in the well. •r the log,CPAI plans to inject dry gas(for no more than 3 days)to clear the tubing of liquid by displacing the liquid to the fo • ation. The LDL will then be ran through the gas filled tubing. Depending on the results of the LDL,CPAI will . - elop a path forward and make the appropriate notifications and/or submit the proper paperwork. Please let us know if you have any questions or disagree with this pl. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday,August 27, 2017 2:33 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: CD2-55 (PTD 203-118) Gas LDL Chris, Alpine injector CD2-55(PTD 203-118)was previously reported and identified with TxIA communication while on gas injection. The well is nearing the end of its water injection monitor period and to date has shown no signs of communication. In order to further investigate the gas-only leak source and potential repair options,CPAI intends to perform a gas leak detect log(LDL) in the well. For the log,CPAI plans to inject dry gas(for no more than 3 days)to clear the tubing of liquid by displacing the liquid to the formation. The LDL will then be ran through the gas filled tubing. Depending on the results of the LDL,CPAI will develop a path forward and make the appropriate notifications and/or submit the proper paperwork. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED *SEP 1. 5 2U • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday,July 25, 2017 7:34 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF3 and WNS Subject: Alpine Injector CD2-55 (PTD#203-118) is showing signs of IA re-pressurization while on MI injection. Attachments: CD2-55.pdf;CD2-55 90 Day TIO plot.JPG Chris- Alpine Injector CD2-55 (PTD#203-118) is showing signs of IA re-pressurization while on MI injection. The IA was recently bled down and has continually increased in pressure after the bleed. It is CPAI's intentions to WAG the well to water injection and perform the initial round of diagnostics. At that point in time a 30 day monitor period will be started to prove inner annulus integrity while on water injection. Depending on the results of the initial diagnostics and 30 day monitor period the proper notifications and/or paperwork for continued diagnostics or administrative approval for water injection only due to TxIA communication while on MI will be submitted. Attached is a copy of the 90 day TIO plot and wellbore schematic. Please let me know if you have any questions or disagree with the plan. Cheers, Dusty Freeborn/Bruce Richwine DHD Field Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7022 Cell phone: (907)943-0167 WELLS TEAM SCANNED AUG 0920.1:' 1 203- lt ( • • 24c212` WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. January 21, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED DATA LOGGED 2.111/201fp Anchorage, Alaska 99501 JAN 2 6 2016 K.BENDER AOGCC RE: Multi Finger Caliper Log/Static Bottom Hole Pressure Survey: CI Run Date: 12/20/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-55 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20463-00 scoOD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ✓Q� .�x.1'u1. / ' ,� Image PI bject Well History File coJer 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. ~ D3 - J l Cf5. Well History File Identifier Organizing (done) ~wo-sided 1111111111111111111 o Rescan Needed 1111111111111111111 R~CAN r Color Items: o Greyscale Items: DI~AL DATA \¢'Oiskettes, No. I o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: 0:;:-( ~aria ) f 0 Other:: Date: I d- ~ V~ 5' Project Proofing BY: ~Ma~ r Date: I~ ì Qç Isl V11 :J 1111111111111111111 Isl rr¡,ð Scanning Preparation BY: ~ L x 30 ':' IJ () + / () = TOTAL PAGES I 3 q 0' .....-- (Count does not include cover she~91J1 .~ Date: l~ 0 OS /s/ If r I Production Scanning Stage 1 Page Count from Scanned File: I '" ~ I (Count does include cover sheet) Page Count Matches Number in Scan~ ing Preparation: v" YES ~ Date: ~ ~ e£" If NO in stage 1, page(s) discrepancies were found: YES BY: Stage 1 BY: Date: Maria Scanning is complete at this point unless rescanning is required. ReScanned 11-111111111 BY: Maria Date: Comments about this file: Quality Checked 11111111111111111 NO Isl VVl Q NO /s/ II1III1I1111 r II /s/ 1III111111111111111 10/6/2005 Well History File Cover Page.doc • MEMORANDUM TO: Jim Regg P.I. Supervisor ~~~~ ~ Z7El ~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-55 COLVILLE RIV UNIT CD2-55 Src: Inspector NON-CONFIDENTIAL Reviewed By~ P.I. Suprv Comm Well Name: COLVILLE RIV UNIT CD2-55 Insp Num: mitJJ100719115006 Rel Insp Num: API Well Number: 50-103-20463-00-00 Permit Number: 203-118-0 Inspector Name: Jeff Jones Inspection Date: 6/11/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well cDZ-ss iType Inj. ~''~ TVD n2s ' IA Isis 2000 ~ Is6o 1860 ' P.T.D 2031180 ' TypeTest SPT Test psi 1782 ~ OA 400 410 400 - 400 ~ Interval 4YRTST p~ P (Tubing 2540 2540 2540 2540 NOtes: 1.1 BBLS diesel pumped. 1 well inspected; no exceptions noted. R~z-,i+- t~'~ ~ti~f' Monday, July 26, 2010 Page 1 of 1 • • ~." " " "~' >, ~p .,- MICROFILMED 03101 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ti¡CANNED APR 2 7 2007 ;103- r\ C6 Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~.z::::~~ ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name pro # cement pumped cement date inhibitor sealant date ft bbls ft Qal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-404 206-054 6" na 6" na 1.8 3/22/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CD2-86 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 318/2007 CO2-58 203-085 6" na 6" na 1 318/2007 CO2-59 204-248 6" na 6" na 1.5 318/2007 C02-60 205-068 6" na 6" na 1 318/2007 Alpine Field March 31,2007 . . ~ ConocoPhilIi ps Alaska /~\ PF: P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 " ,:'i!;~ ~ March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 scANNED AFR 0 9 2007 .9v0~ ~ ll~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 ~~ LV 't't.)~.VV I r UIiUW Up e e ~'-\~s~ Tom, Jim, ~O'-\"'\SOdOS--O(Q<6 As a fOllowlup to AA CO \. 43A.001 allowing the temporary removal of injection valves from CRU ì)O"'r\\.t~C02-55, C02-56, C02-~t which expired 8/31/06, this email is to notify the commission that the injection valves have been reinstalled and function tested as of 8/31/06 on all three wells. The wells are still SI but can be available for State Inspector Witnessed SSSV testing if requested. Please let me know if you need any additional details or a more formal notification that the injection valves have been installed. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 $(;ANNEfJ AUG 3 1 2DDS 1 of 1 9/5/2006 9:39 AM MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg -0 ,,_ c¿C~JCG P.I. Supervisor N'Pf ¡ I DATE: Wednesday, August 30, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD2-55 COLVILLE RIV UNIT CO2-55 ~-,\\C6 d-0 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv,'TDt?- Comm Well Name: COLVILLE RIV UNIT CD2-55 API Well Number 50-103-20463-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060828 145600 Permit Number: 203-118-0 Inspection Date: 8/26/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CO2-55 Type Inj. N TVD 7128 IA 750 2470 2430 2430 I P.T. 2031180 TypeTest SPT Test psi 1782 OA 475 475 475 475 Interval 4YRTST P/F P Tubing 1000 1000 1000 1000 Notes Pretest pressure observed and found stable NON-CONFIDENTIAL SCANNED SEP 082006 Wednesday, August 30,2006 Page I of 1 . . FRANK H. MURKOWSKI, GOVERNOR A1tASIiA. OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRA TIVE APPROVAL CO 443A.OOl Ms. MJ Loveland Problem Well Supervisor - NSK 69 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 'f'4ÁÏ't.íoì.ic:n HJN 1 "12.0Cb ¡:)..,n!~~"¿;"\''''''' I\,.i - Re: Temporary Removal ofInjection Valves Colville River Unit Dear Ms. Loveland: Pursuant to Rule 11 of Conservation Order ("CO") 443A, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants ConocoPhillips Alaska, Inc. ("CP AI")' s request for administrative approval to temporarily remove the required subsurface safety valve from injection wells C02-55, CD2-56, and CD2-60. AOGCC finds that CPAI will remove the A-I injection valve from each well to allow for monitoring of the surface pressures. The injection valves will be out of the wells through early August 2006. The Commission further finds that CP AI will leave these wells shut in except for a I-hour period every two weeks when each well's master valve will be opened to monitor tubing pressure. Recent inspections of CD2 location indicates the safety valve systems for all wells are suitable for the intended service, with only a few deficiencies identified that were immediately corrected. No state witnessed safety valve system tests of the 3 wells have been performed since they have only injected water. The Commission has no record of well integrity concerns for the 3 mentioned injection wells and believes that removal of the injection valves from CD2-55, CD2-56, and CD2- 60 will not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to allow the temporary removal of injection valves from CRU CD2-55, C02-56, and CD2-60 is conditioned upon the following: 1. Wells shall be tagged showing the date and reason for removal of the injection valve; Ms. MJ Loveland May 18, 2006 Page 2 of2 . . 2. Wells shall be attended while the master valve IS open for monitoring tubing pressure; 3. Wells shall remain shut-in except during the monitoring of tubing pressure; 4. The injection valve must be reinstalled within 15 days of commencing injection in a well; 5. This approval expires on August 31, 2006 As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. , Alaska and dated May 18, 2006. Cathy P. oerster Commissioner CO 443A.OQ I, AI04E.00 1, AI04E.002, AI04C.005 . . Subject: CO 443A.00l, AI04E.00l, AI04E.002, AI04C.005 From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Fri, 19 May 2006 09:26:09 -0800 To: undisclosed-recipients:; BCC: Cynthia B Mciver <bren_mciver@admin.state.ak.us>, Robert E Mintz <robert_mintz@law.state.ak.us>, Christine Hansen <c.hansen@iogcc.state.ok.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, trmj r I <trmjr 1 @aol.com>, shaneg <shaneg@evergreengas.com>, jdarlington <jdarlington@forestoil.com>, nelson <knelson@petroleumnews.com>, cboddy <cboddy@usibelli.com>, Mark Dalton <mark.dalton@hdrinc.com>, Shannon Donnelly <shannon.donnelly@conocophillips.com>, "Mark P . Worcester" <mark. p. worcester@conocophillips.com>, Bob <bob@inletkeeper.org>, wdv <wdv@dnr.state.ak.us>, tjr <tjr@dnr.state.ak.us>, bbritch <bbritch@alaska.net>, mjnelson <mjnelson@purvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "Randy L. Skillern" <SkilleRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Steven R. Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross <kuacnews@kuac.org>, Gordon Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SommerFS@BP.com>, Mikel Schultz <MikeI.Schultz@BP.com>, "Nick W. Glover" <GloverNW@BP.com>, "Daryl J. Kleppin" <KleppiDE@BP.com>, "Janet D. Platt" <PlattJD@BP.com>, "Rosanne M. Jacobsen" <JacobsRM@BP.com>, ddonkel <ddonkel@cfl.rr.com>, mckay <mckay@gci.net>, Barbara F Fullmer <barbara.f.fullmer@conocophillips.com>, Charles Barker <barker@usgs.gov>, doug_schultze <doug_schultze@xtoenergy.com>, Hank Alford <hank.alford@exxonmobil.com>, Mark Kovac <yesnol@gci.net>, gspfoff <gspfoff@aurorapower.com>, Gregg Nady <gregg.nady@shell.com>, Fred Steece <fred.steece@state.sd.us>, rcrotty <rcrotty@ch2m.com>, jejones <jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <eyancy@seal-tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <mapalaska@ak.net>,jah <jah@dnr.state.ak.us>, buonoje <buonoje@bp.com>, Mark Hanley <mark_hanley@anadarko.com>, loren_Ieman <loren_Ieman@gov.state.ak.us>, Julie Houle <julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>" tablerk <tablerk@unocal.com>, Brady <brady@aoga.org>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kenai.ak.us>, Jim White <jimwhite@satx.rr.com>, "John S. Haworth" <john.s.haworth@exxonmobil.com>, marty <marty@rkindustrial.com>, ghammons <ghamm~ns@aol.com>, rmclean <rmclean@pobox.alaska.net>, mkm 7200 <mkm nOO@aol.com>, Brian Gillespie <ifbmg@uaa.alaska.edu>, David L Boelens <dboelens@aurorapower.com>, Todd Durkee <TDURKEE@KMG.com>, Gary Schultz <gary_schultz@dnr.state.ak.us>, Wayne Rancier <RANCIER@petro-canada.ca>, Brandon Gagnon <bgagnon@brenalaw.com>, Paul Winslow <pmwinslow@forestoil.com>, Sharmaine Copeland <copelasv@bp.com>, Kristin Dirks <kristin_dirks@dnr.state.ak.us>, Kaynell Zeman <kjzeman@marathonoil.com>, John Tower <John.Tower@eia.doe.gov>, Bill Fowler <Bill_Fowler@anadarko.COM>, Scott Cranswick <scott.cranswick@mms.gov>, Brad McKim <mckimbs@BP.com>, Steve Lambe <lambes@unocal.com>, jack newell <j ack.newell@acsalaska.net>, James Scherr <james.scherr@mms.gov>, nI617@conocophillips.com, Tim Lawlor <Tim_Lawlor@ak.blm.gov>, Lynnda Kahn <Lynnda_Kahn@fws.gov>, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com>, crockett@aoga.org, Tamera Sheffield <sheffield@aoga.org>, Jon Goltz <Jon.Goltz@conocophillips.com>, Roger Belman <roger.belman@conocophillips.com>, Mindy Lewis <mlewis@brenalaw.com>, Kari Moriarty <moriarty@aoga.org>, Patty Alfaro <palfaro@yahoo.com>, Jeff <smetankaj@unocal.com>, Todd Kratz <ToddKratz@chevron.com>, Gary Rogers <gary _rogers@revenue.state.ak.us>, Arthur Copoulos <Arthur _ Copoulos@dnr.state.ak.us>, Ken <ken@secorp-inc.com>, Steve Lambert <salambert@unocal.com>, Joe Nicks <news@radiokenai.com>, 10f2 5/19/2006 9:26 AM CO 443A.0(}1, AI04E.00 1, AI04E.002, AI04C.005 . . Jerry McCutcheon <susitnahydronow@yahoo.com>, Paul Todd <paulto@acsalaska.net>, Bill Walker <bill-wwa@ak.net>, Iris Matthews <Iris_Matthews@legis.state.ak.us>, Paul Decker <paul_decker@dnr.state.ak.us>, Rob Dragnich <rob.g.dragnich@exxonmobil.com>, Aleutians East Borough <admin@aleutianseast.org>, Marquerite kremer <margueriteßemer@dnr.state.ak.us>" Alicia Konsor <alicia_konsor@dnr.state.ak.us>, Mike Mason <mike@kbbi.org>, Garland Robinson <gbrobinson@marathonoil.com>, Cammy Taylor <Camille_Taylor@law.state.ak.us>, Winton GAubert <winton_aubert@admin.state.ak.us>, Thomas E Maunder <tom_maunder@admin.state.ak.us>, Stephen F Davies <steve_davies@admin.state.ak.us>, Keith Wiles <kwiles@marathonoil.com> Content- Type: application/pdf C0443A-001.pdf Content-Encoding: base64 Content-Type: application/pdf AI04E-002.pdf Content-Encoding: base64 Content-Type: application/pdf AI04E-OOl.pdf Content-Encoding: base64 Content-Type: application/pdf AI04C-OOS Cancellation.pdf b 6 Content-Encoding: ase 4 ~ of2 5/19/2006 9:26 AM . Màry Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 North Slope Borough PO Box 69 Barrow, AK 99723 . Mona Dickens Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 · \Q¡ð/ 0 (ß m~\ ~ 'J-I \ \ \ J. ......-... .....-.,....:,.,.... ..."".. '- .a...t".........- "-"~~ .. . . Jim, I'm following up on this request, it appears that our new guy sent it to the wrong place. I wanted to make sure you got it since Alpine would like to pull the SSSV's this week and begin monitoring the 3 SI wells. Please advise if this is acceptable. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 -----Original Message----- From: NSK Problem Well Supv Sent: Tuesday, May 16, 20069:19 AM To: bob_fleckenstein@admin.state.ak.us Subject: Request for Alpine SSSV variance Bob, In order to monitor offset wells to the planned CD4-16 D&C; ConocoPhillips would like to monitor the surface pressure's of injection wells CD2-55,56,60 (All SI). In order to do this, we would like to leave the A-1 inj. valve out of th~ hole until early August. ConocoPhillips requests a variance from the state rule that all Alpine wells require an operational SSSV. The wells will remain shut in during the monitoring period with the exception of a 1 hour period every two weeks where the master will be opened to monitor tubing pressure. To bring the well back online ConocoPhillips would have 15 days to install a functioning SSSV per state rule. Sincerely Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 1 of 1 5/18/2006 2: 17 PM Conservation Order 443. October 7,2004 A' , . Lp¡,\,t:.. . Page 7 Rule 4 Drillin2: and Completion Practices (Restated from CO 443) a. After drilling no more than 50 feet below a casing shoe set in the AOP, a formation integrity test must be conducted. The test pressure need not exceed a predetermined pressure. b. Casing and completion designs may be approved by the Commission upon applica- tion and presentation of data that demonstrate the designs are appropriate and based upon sound engineering principles. c. Permit(s) to Drill deviated wells within the AOP shall include a plat with a plan view, vertical section, close approach data and a directional program description in lieu of the requirements of20 AAC 25.050(b). d. A complete petrophysical log suite acceptable to the Commission is required from below the conductor to TD for at least one well on each drilling pad in lieu of the re- quirements of 20 AAC 25.071(a). The Commission may, in its discretion, require additional wells on a pad to be logged using a complete petrophysical log suite. Rule 5 Automatic Shut-in Equipment (Restated from CO 443) a. All production and gas injection wells must be equipped with a fail-safe automatic surface safety valve ("SSV") and a surface controlled subsurface safety valve ("SSSY"). b. Water injection wells must be equipped with either a double check valve arrangement or a single check valve and SSY. c. Safety Valve Systems ("SYS") must be tested on a six-month ftequency. Sufficient notice must be given so that a representative of the Commission can witness the tests. d.' Subsurface safety valves may only be removed after demonstrating to the Commis- sion that the well is not capable of unassisted flow of hydrocarbons. Sufficient no- tice must be given so that a representative ofthe Commission can witness the tests. Rule 6 Reservoir Pressure Monitorin2: (Restated from CO 443) a. Prior to regular injection, an initial pressure survey shall be taken in each injection well. b. A minimum of six bottom-hole pressure surveys shall be measured annually. Bot- tom-hole surveys in paragraph (a) may fulfill the minimum requirement. c. The reservoir pressure datum shall be 7000 feet TYD subsea. d. Pressure surveys may consist of stabilized static pressure measurements at bottom- hole or extrapolated from surface, pressure fall-off, pressure buildup, multi-rate tests, drill stem tests, and open-hole formation tests. e. Data and results ftom pressure surveys shall be reported annually on Form 10-412, Reservoir Pressure Report. All data necessary for analysis of each survey need not be submitted with the Form 10-412 but shall be made available to the Commission upon request. f. Results and data from special reservoir pressure monitoring tests or surveys shall also be submitted in accordance with part (e) of this rule. Conservation Order 443. October 7, 2004 . Page 10 Rule 11 Administrative Action (Restated from CO 443) Upon proper application or its own motion, the Commission may administratively waive the requirements of any rule stated above or administratively amend this order as long as the change does not promote waste, jeopardize correlative rights, or compromise ultimate recovery and is based on sound engineering principles. DONE at Anchorage, Alaska and dated October 7,2004. John K. Norman, Chair Alaska Oil and Gas Conservation Commission Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23'd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an appJication by not acting on it within the to-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30 day period for appeal to Superior Court runs from the date on which the request is deemed de- nied (i.e., totlt day after the application for rehearing was filed). Safety Valve & Well Pressures Test Report InspNo SVSOP000002627 Operator Rep Gary Seltenteich Related Insp: svsJCr0604191223J I Reason 180-0ay Src: Operator Pad: CRU_CD2 Insp Dt 3/19/2006 Inspected by John Crisp Interval Field Name COLVILLE RIVER Operator CONOCOPHILLIPS ALASKA INC Well Permit Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code ~",.~_.._.-- CD2-0 I 2051180 151 100 96 P P P _.._-_."-----_..__.._._~ . ____.____n........___ C02-02 2051090 -'^.~_.__..__.-.-.- ___..._n....'____. C02-03 2050920 151 100 98 P P P --"------~.._._--- ---- --""---'-- -.--- CD2-05 2040970 151 100 94 P P P ~--- ----.------...--- ----..-..,--- .--.......- ---~-"--,..._---. CD2-06 2031590 Date SI OiI,WAG,GINJ, Inner GAS,CYCLE, SI PSI Outer Tubing PSI PSI YeslNo YeslNo ---.--..---.......--- __·_'_'_m_...~" OIL __ _n.._,___ ----------....--, .'-'-'-. -..- --.'-------- WAG - -------..,...-- --._----,-'-_. --....-..... --'- OIL - -------~. -----.--..---.,".,'-- ---...--.--- ----..--.-- -....,---..----...--.---"-- OIL _____.'___..n_'__ GINJ C02-07 .__._.._~.._. ----" ~- .-._--~. ._~.._. ~.---.~ - .~-----_._..._- ____._..__.__~___..__n --.....---- -- 2031870 WAG -- _.._~.--._-------,-- - --....--... ,,- C02-08 - --_.--------~- ...-----... ..----- -.- .-- --,--.---...--------...- _ _ ----.-----.----- -- -----..---....- 2022500 GINJ .-------..--....--....--- -..-.....----.-.-..----------.-~--..- C02-09 ~...__._--_.._._..._-- --. -.. -- 2041290 151 100 99 P P P OIL _._. .._______._____ ..._____.__.. ".__..n._ ___~n___ ----..--- ---..--..---.----.-...- CD2-10 _.____......_ .________._ ____"___"___ __ _,,__ .....______n___ _____...,.____,,__._.__. ---"-"----"'-~-""--'" --..-------------- --..--. 2031950 151 100 99 6 P P OIL Retest Date: 3/19/2006 C02-II _______...____n__ __ _.________._.____....._ _..______..__ ..n_ .____..___...___ __ ______ _.._____ n_~" ___ CD2-12 _______."._._ _____._n__.____ C02-13 .. ----..._"---,,.. ~------ C02-14 ._._-_._...~....__._._-- CD2-15 --------..---.---... C02-16 _'. "___"'__ _.____·____.__..___,___.._._..n___.____ __. _ _~.___ 2051320 WAG I ft I -1 ----.---------.,...-- -------- -----..-..-- -- __'__.n.__' __._n..___ _n__.....___..··__m__ 2030730 GINJ ---------"-....._-----_.. ---. - - ..-.----.-....--.---- ~ -'" ----.. ------... _.__._n_~...____._. .___ ___.... ~___...__. - .----------...- __...__..____. ...___.______.___n .__ ,_....__ ___....__ 2022030 ] 51 100 97 P P OIL P ______.._...__n_.____ _.__.... _____....__ ..__.____...... .___ __....____..n.____...____ __" ------.--.--.------ --'-"- ..~-- --...---.------- _._---_._-------~---_..._-._.._- 2011770 15] 100 99 P 9 OIL P Retest Oate: 3/27/2006 ----.. -'--"- .---- ....-- - ..-".-----. .-- ---- -"- ..------.- ----.--~ -- -- ---.-...--.------- -- ---"- --- - ._....~--_..._- .----..---. - -.----- -.---- 2011590 GINJ -.---------..-.----.--- .--.. -.--- - - -"-- ----. --_.---~_.._._-~- ..--------------. .----..--.-----..- .....--..-.....- --~-----~--- ---- -- -..-.----. 2021440 WAG _._..___.~_.___________ _n_.....______".....___. ___.__ ___....._.._.....__n..._ 1_- .-~.--.--.---- ------------....---- ----- -- --- ---- C02-17A .______ _._.__n__ __...n___··.·__ __ ------ ---.--- ....---..------..- ____...___ _._,__,,_~_' .___..__.... __.__ .____...__M _.__ ._ 2050170 WAG __.....~_n...____.__.... __________________...___ .. ____.n__.__.___ __.. -.-- ..------- -_...._~. ....-.,.--.- --_..~--_.._- C02-IS 2031510 WAG -- -~.."'-'---'---- --------_.----~- ~ -------.---. ---- -----~._.-.._---- .---...--. -.....- C02-19 2021120 151 100 99 P Thursday, May 18, 2006 P P OIL -----...---..--.-..------..... Pad: CRU_CD2 Insp Dt 3/19/2006 Inspected by John Crisp Interval Field Name COLVILLE RIVER Operator CONOCOPHILLIPS ALASKA INC InspNo SVSOP000002627 Operator Rep Gary Seltenteich Related lnsp: svsJCr060419122311 Reason 180-Day Src: Operator l' Well Permit Separ Set LIP Test Test Number Number PSI PSI Trip Code Code -. ---,._--,~--.__. -- ---I~~ CD2-20 2031050 151 100 97 P P -- -_...---..,--~ CD2-21 2042450 151 100 97 P P - -- ~-, ..._-,-_..~---- __0', ...__..._~____._._ CD2-22 2020920 CD2-23 ---....... .-----,....----..- -. "---'-""-'~_..--'--" P CD2-24 ---.-.........-.--.--...-..--- 2021340 151 100 96 2020740 2010950 151 100 97 P P CD2-25 . ~___...__.._____._ _____.__....____.__....___. ____ 0' "_ ___._____._..__ 151 100 95 -.--------......-.-.....-....--- --,...,...~-.-,-_._---- -----~. ------.'...'."---- -~,- '- CD2-27 CD2-26 ' 2012320 2031770 .~_..____.~__.._.,____ __·__.._n__'O'___ ..__ "_ ----.,.-------,-...-- -.,.--,-------.- --._~._'"--- CD2-28 2022170 ___________...__n...___ __......_________.___.___. 2021480 CD2-29 n' ________..._._~~__. ___.._~._____ 2031350 CD2-30 CD2-31 ~_~_.. ___..___.__n _ ..___._ _....___. 2040820 __.______._...___ - ___ .__..._m._. CD2-32 2020290 __~_....._..n_._...._________.._ .._. _.__......____.".__ CD2-34 CD2-33B 20] 1250 2011910 -----,,---.._-------- --.-.- .---..--...--.......-- ___...._____ _""_.n _. ._..____.. ..._.... ...___ CD2-35A -..-----.---.-....---...- CD2-36 2022440 ----......_._-.._._.._._.~-_.. '- CD2-37 ~_"."----.._-----'-- - ----- .--....---.-- 2030140 2022110 151 100 96 .-.. .------.--..-. --.. -_....,,--~.----- .- ----- ..._--~-_._... CD2-38 2021710 2011600 151 100 97 _._._m__..____ _._.-..--._._--~_."._----.._-- --- ..-.-...-.---,,-- CD2-39 ---...----. _..~..._.._---~-. -.--...- --~-_.._- Thursday, May 18, 2006 ------.--------...--..-----.-- 151 100 93 P 15 I 100 96 P ._-----.._-----.--~- 151 100 98 P P P __.." "___n.___ 151 100 98 P P P --~~ ..-- ..-.... _._-~- ----" .._._-~..- -~--. P ,- .--.-..------.-.... .--- -.._- P Test Date SI Oil,WAG,GlNJ, Code GAS,CYCLE, SI r- p-- --------üii-- ___0··..---·0._------ .___.._. _..__..____~_ P OIL ~.__..___~._._._._____.. __~_.. _.~___.n_~___....___ WAG -.-...-,-----" -~ p P OIL P P OIL P OIL P .' --..-----......-- .-' -..-- ---....-......-- GINJ _···_·_______~_o_ WAG P P OIL WAG WAG ____._..______n__ P P OIL _____ - .m__ __.._._____ .__.__ .._ WAG ---"'-'-- ....---... ..~.-." ---......-- OIL _.__' __.._.n..__...___~__._ OIL -~--_..-._------- --- ----.---.-- .'--".-"-- GINJ -- ---.... ~---_.._.- --. .----..-------"..-- ---- GINJ --.---....---,,--- ----- "---"--'-- P P OIL GINJ P 9 OIL --.---..- -- Inner PSI Outer PSI Yes/No Yes/No Tubing PSI - .._nn_____ -~...._...---._~- _._n.....__._ - ---_.-. -.....- --~ ..._--- ~.~_.~---- ________.._". ___."'___"_ 0·_....._·_·_______. - ..-.-.---....-.-- ._-_._._~.--_..- ~.._------- . ..~._-- ..--- . _..~.... --. -- -.-.--"..-- _.--._....__.-..~ ---.' ..----- _...-~-- .-- - ._--.----~-~ --' ---_... ..~. _._______.__n._ -~.. ------~~_...__.------~~-_..- __. _. _____..____n.___.....___~____ __.......____.______ .__~__...__.___ ....___.. e_____ __. . _____n__ __.__.__ . _''-' ..~__. ___n_.._........_ _____. _~~_...__~_ ~_._--.._._._--_.. ----...------ ---~ .._-------_.-".~-- ....~- ...._~_..----- -~.- -..---... -.- _______.~...n____~ - -.--. --~---_..._...._- -- .- --. _...._-~.. ------.-- ~. -".--.'--- -'-~"-' -- ----, .--..--...-----.-.-- --I -I. _.~---j --- --~_._- _".,..__._ ___ .______ ,_.. n___. ___.__ -- ---. -------..-- ------.~- .. --...._-~--_._._..._._~._..--- -----'"."._------ -~_. ...._.__._.~--..- .-...- .--.- ---.- .._.~_.-- .--.......-- - ~---. ----. ---..... -.----.--.- .~-,.. .~_...__._._- ---- --.. --~- .....-. -" .--- --~, ....._- .- -- ...__....~-"...._-- --.... ~-_._._...--.._--- ...-..- ----. ._~...-..._---_._._-- .._---. -.. -- -------- - --.--.. ._-~ Retest Date: 3/30/2006 -.-...-..- -----. ._--.. ..-.- Pad: CRU_CD2 Insp Dt 3/19/2006 Inspected by John Crisp Interval Field Name COLVILLE RIVER Operator CONOCOPHILLIPS ALASKA INC InspNo SVSOP000002627 Operator Rep Gary Seltenteich Related Insp: svsJCr060419122311 Reason 180-Day Src: Operator ., CD2-46 2020820 ~ ~~~:~~~~~~_I~_IÕO ~ 98=I_p _P ~IP Well Permit Separ Set UP Number Number PSI PSI Trip [- Cri2~40~J _~~3~=~_ -~-~~ ~~~~~~__ I~ CD2-4 ~ __ _ ~O= 1260 _ _1_~ ~OO 99 CD2-42 2010670 151 100 97 --~- - -- --- - --- - - - I CD2-43 2031970 151 100 97 CD2-44 2021650 --- -~".."--~---------- --'~-.--_.~'-_.~-- -~--_._----.-' CD2-45 2012120 151 100 97 -.- --'._.._~_.'-'-"'- ..-.-.---...--.. .--- ...---.-.- -.. ---- '---'-"'~--'-----"'- -'.--..-----.-.----- CD2-50 2020490 151 100 97 ---------~_._.~._- ._-._--------- ---~_._---- CD2-51 2022490 -------.-- .----..... CD2-52 2030930 151 100 96 __n_______.___·_______ __...,__,___,___,,__ -0" ___.. ___..,_,___,_"__,_ ,.___ CD2-53 2040890 _____ ----_-'_'-0'--·-__·- --',-----_._----_."- --.~--_.._._-- CO2-54 2041780 --.... -..,---...---,."-,---- ~---_.. --- -- ----.-.-..--. .' CD2-56 2041500 _.._-_...._-_._-_._._-~ ..----...----.--...------.----- ~_..- --.--.-"--.- CD2-57 2040720 .---.....----..---.------------ -~_._._-......,,--~_.. _...~ CD2-58 2030850 ___~________..._.__"._..__ _____.....______.___... u_ Þ ~~2-6~_1__2050~8_0 J Thursday, May 18, 2006 Test Test Test Date SI Oil,WAG,GlNJ, Inner Code Code Code GAS,CYCLE, SI PSI WAG ---"...------ _.-- .---..-----"..- .--- P P P OIL ~_._-"'_.._-- P P P OIL ------..----....- ....-----..- -------..-.-.---- P P P OIL Outer PSI Tubing PSI YeslNo YeslNo - --.. ------ _. _..n __..._______..___-.__._ __n.___..".___.....___ .__ __._.. --------_.--..._~ --...-..--- . --. .-'---..-----.. _om. ____ ___....._.._..___.._...___...__________ ___...___.. ___.". ___ ..___ n_~ __I ... ~ - ~'.."_' _____.__.__n ._... _._u___ _>...___ ___.__ WAG --.--..------ ..--- -_._.~.--~_.- --.--..--- ----...---..--- -- -~_..-----_._----_....__..._._---- - - .--- -..-- - P OIL P P - --.-.--...--- WAG -...-..--.,---- --. .--..... .-.---- --- .---....--- --_.. -----.. -...-.--......---. OIL ._..__..____._...,____ _n_·_. _____________ --- ..--------... --- GIN] .__.___..__ __ .______.n..._. -- .---"...- _u_____..__·_ _.____.._.._~ _.__"..__ --...---- ..-.-..- ----..-.-.... - --- GIN] ....--'---."-,,---. --.. .----.----- -- -- ---- -,- -.--. --........- -.-..----,,- ...-----....-.-- -.,,--....--.-..---- -- -'--- P OIL P P --.-------.--- - _n~_. ____ _____.____ GIN] .- -_._.._-~_.._..._.- __ _..___n_._____ _... -.--- . .-- ..--- -- -...-----.--.....--. P OIL p P I ----..------..-- . -. _..-------...--- ---....----. -- --- - --.-- --.- -...- --.-.. -------..---. ------ .----....--. ----.--- 3/l2/2006 SI -.---..--....--- -.- - .--.-.-- --.._~- -----.--.---- ----- .----..--. GIN] --------.--...-.-- - -- --,,--_. ----- - --. __... _ ._m._~__ ___.,,__ ____. ._._. .___ ___" WAG -------~_.._----_.- .---......---...--.-- .-- ---" WAG --.--..-- -----" ----. -----.. -- WAG ---_..---~_..- -..--------.---~. -- ....-.. ---.--.-.-----.-.--.---.-.---..-. 317/2006 SI -~....._~.._.--..~--.- Pad: CRU_CD2 Insp Dt 3/19/2006 Inspected by John Crisp Interval Field Name COLVILLE RIVER Operator CONOCOPHILLIPS ALASKA INC InspNo SVSOP000002627 Operator Rep Gary Seltenteich .. Related Insp: svsJCr060419122311 Reason i80-Day Src: Operator ~ Well Number Permit Number Separ Set LIP Test Test Test PSI PSI Trip Code Code Code Date SI OiI,WAG,GINJ, Inner GAS,CYCLE, SI PSI Outer PSI Tubing PSI YeslNo YeslNo Comments CD2-41, CD2-42, CD2-43, CD2-45, CD2-47, C02-50, C02-52 were tested 3/20/06 CD-IO had a frozen SSV & would not close. The valve was thawed & retested OK. CD2-14 SSSV was serviced and retested good 3/27/06 CD2-39 SSSV was serviced and retested good 3/30/06 Thursday, May 18, 2006 Performance [ Wel;;-- C~;p~~e~~ . -~~~I~res-F~il~~eRa~~H-- 26 78 3 _____}~5% ~_ -~~~~, ~ ---~~~:=--~=--=~=-~=-~~-,-~-~=-=~-~~=- . . / þJ I) '/ 20"")- DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 7355 - Completion Date 1 0/1/2003 .",..., Operator CONOCOPHILLlPS ALASKA INC Completion Stat~WIN~ ~ Jrq)., Þ:) M .~J API No. 50-103-20463-00-00 Permit to Drill 2031180 Well Name/No. COLVILLE RIV UNIT CD2-55 MD 15238......... TVD Current Status 1WINJ éu,c y) IlL -------~---. - ----------- --- --- REQUIRED INFORMATION Mud Log No Samples No .. ~~) Directional survt ~ -- ------------------ DATA INFORMATION Types Electric or Other Logs Run: GRlRes, GR-CCL. SCMT Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OH/ .~ Jl!t _Med/~~tNumber Name Scale Media No Start Stop CH Received Comments ! D D Asc Directional Survey 0 15238 2/3/2005 IIFR (Sag Corrected) I ¡ «;g Cement Evaluation ,t "1 .l\t.~ ~" 5 Col 11600 12075 Case 9/28/2003 Slim Cement Mapping i Tool- I SCMT /GRlPresslTemplTra / ctor Log Gradiometer ^ 1 )\;'" )-.~ ~ 5 Col 11600 12075 Case 9/28/2003 Slim Cement Mapping Tool- SCMT /GRIP resslT em pIT ra ~ ctor Pressure .t \ J tA~ ~---~ 5 Co I 11600 12075 Case 9/28/2003 Slim Cement Mapping Tool- SCMT/GRlPresslT emplTra ctor /ÍOg Temperature )" 1 J~ )'\t'" ~ 5 Col 11600 12075 Case 9/28/2003 Slim Cement Mapping Tool- SCMT/GRlPresslTemplTra ~ J" Molt) ctor \Jfg ---- See Notes À.\.t 5 Col 9083 11720 Case 9/28/2003 USIT Log - USRS-AB/CAL- Y/SGT-L U AA~~) ! Log Cement Evaluation 5 Col 11440 11826 Case 10/1 0/2003 Slim Cement Mapping Tool SCMT/GRlPresslT emplTra ~ ~'" ) ctor ~Og Pressure ^"\ 5 Col 11440 11826 Case 1 0/1 0/2003 Slim Cement Mapping Tool I SCMT/GRlPresslTemplTra ~~~) ctor , Log Temperature 5 Col 11440 11826 Case 1 0/1 0/2003 Slim Cement Mapping Tool SCMT/GRlPresslTemplTra ctor v(:RPt 12187 LIS Verification 2776 15183 Open 10/27/2003 ED D Lis 12187 Rate of Penetration 2776 15183 Open 10/27/2003 ROP, GR, EWR4 DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031180 Well Name/No. COLVILLE RIV UNIT CD2-55 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20463-00-00 ~ 15238 TVD 7355 Completion Date 10/1/2003 Completion Status 1WINJ Current Status 1WINJ UIC y ------------ D Lis 12187 I nd uction/Resistivity 2776 15183 Open 10/27/2003 Rap, GR, EWR4 ~ Directional Survey 0 15238 1 0/27/2003 Directional Survey 0 15238 1 0/27/2003 MWD ~g Temperature Blu 1-3 10406 14616 Case 1/12/2004 Warm Back, Temperature Log .,....ED C Pds 12376 Temperature 1-3 10406 14999 Case 1/20/2004 Warm Back Temp Log ~ C Las 12376 Temperature 1-3 10406 14999 Case 1/20/2004 Warm Back Temp Log ~. hg Temperature BM 1-3 10406 14999 Case 1/20/2004 Warm Back Temp Log ~ C Lis 12596 Gamma Ray 114 15238 Open 4/23/2004 MWD, Rap, DGR, EWR - ---------- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ~ Daily History Received? &N ~/N . .... Chips Received? - Y / I~ Formation Tops Analysis Y / N Received? ------.- --- . - ------ - ~ Comments: -- --------- Compliance Reviewed By: I..... ,("') Date: r /)M-~j- -------- ----- ) ') 01-Feb-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-55(Sag Corrected) Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD . 15,238.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: . Sperry-Sun Drilling Services AUn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 /1/ ¡ ()I/ Date '1 h0.lMÇ Signed ¡¡~ ¡,jAJ Please call me at 273-3545 if you have any questions or concerns. Regards, " Carl Ulrich Survey Manager Attachment(s) ;Za,~-lt8 ') . IJ:l1;-. ~) cf(& 3 -If ?5' /2- S- <jç, WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 April 20, 2004 RE: MWDFoflnation Evaluation Logs: CD2-55, A:K-MW-2546011 CD2-55: Digital Log In1ages: 50-103-20463-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF TI-IE TRANSMITTAL LETTER TO TI-IE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~fr(o¡ si~QÚr;:KL 1- ~ RECEIVED A.PR 2 :5 2004 Alaska Oil & Gas Cons. Commisaton Anchorage ') MEMORANDUM ) State 0.. Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ,-~ . }(~/ctJ P.I. Supervisor {i DATE: January 25, 2004 SUBJECT: Mechanical Integrity Test Conoco Phillips CD2 CRU FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well CD2-06 Type Inj. S TV.D. 6922 Tubing 511 511 511 511 Interval I P.T.D. 203-159 Type test P Test psi 1731 Casing 200 2050 2050 2050 P/F E Notes: Well CD2-18 Type Inj. S TV.D. 7055 Tubing 1053 1053 1053 1053 Interval I P.T.D. 203-151 Type test P Test psi 1764 Casing 350 1850 1800 1800 P/F E Notes: Well CD2-27 Type Inj. S T.V.D. 6946 Tubing 1252 1252 1252 1252 Interval I P.T.D. 203-177 Type test P Test psi 1737 Casing 150 2250 2250 2250 P/F f Notes: Well CD2-40 Type Inj. S T.V.D. 7091 Tubing 1530 1530 1530 1530 Interval I P.TD. 203-126 Type test P Test psi 1773 Casing 1000 1900 1800 1800 P/F E Notes: Well CD2-55 Type Inj. S TV.D. 7170 Tubing 1190 1190 1190 1190 Interval I P.T.D. 203-118 Type test P Test psi 1793 Casing 500 2150 2125 2125 P/F E 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 during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details I traveled to Conoco Phillips CD2 Pad in the Alpine field and witnessed the initial MITIs on the above listed 5 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed: ~ Attachments: Number of Failures: º Total Time during tests: 6 hours cc: MIT report form 5/12/00 L.G. MIT CRU C02 1-25-04 CS-1.xls 1/30/2004 ck3s,I. Wt:2L LOG TRANSMITTAL ') ~03-(\<Z: ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave. Ste. 1 00 Anchorage. AK 99501-3539 RE : Distribution - Final Print( s] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey BUrton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 13B9 Stafford, TX 77497 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 CD 2-55 1-7 -04 Res. Eva!. CH )¿)37 ("0 1 1 Mech. CH Caliper Survey 1CD 1 Rpt or 1 Color Signed: "'~ ~ ~ ---"\~0-",~ ~ ~ .J'Ý"-'~ \. C~~~ ~~ Date: -RECEIVEu Print Name: JAti 2 0 2004 AI31ka Oit & Gas Cons. Commisaton Ar;chorage PRoAcTivE DiAGNOSTic SERVicES, INC., PO Box 1 ~69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~'Df\\~ 1/12/2004 1 :07 PM lof2 You will no doubt recall, CPAI recently conducted a remedial cement squeeze on the 7" casing in CD2-55. The post squeeze bond log suggested that the remedial cement job was adequate to provide zonal isolation. CPAI subsequently moved the rig back on, drilled the open hole section and completed the well. During the squeeze evaluation, we agreed that it would be prudent to conduct a post start up temperature profile to Tom Crabtree, C L wrote: Hi Cliff, Was there supposed to be a temperature plot?? I did get some digital data{lis) but I there is nothing in the TIF. Tom -----Original Message----- From : Thoma s Ma un d e r [!:0..9.:..~..~..!:..S?:....!::..S?.~_~.9.:g.!.?:.s?.:.~E.~!..9.:,s?.:~..~,.~...:....§.,!::..9.:.!:..~...:...,~..~...:...~.§..] Sent: Friday, January 09, 2004 3:08 PM To: Crabtree, C L Subject: Re: CD2-55 Temp Warmback Log Tom I have arrange for a hard copy to be delivered today Thanks Cliff Crabtree, C L wrote: Cliff, I have looked at the temperature log for the subject well. I concur with your assessment that the log does not show any temperature anomalies above the 7" casing shoe. Thanks for acquiring and submitting the information. The efforts of you and your colleagues with regarding to verifying the external mechanical integrity on this and other wells at Alpine is acknowledged and appreciated. Tom Maunder, PE AOGCC Subject: Re: CD2-55 (203-118) Temp Wannback Log From: Thomas Maunde~ <tom _ maunder@admin.state.ak.us> Date: Man, 12 Ian 2004 13:06:52 -0900 To: "Crabtree, C L" <C.L.Crabtree@conocophillips.com> cc: Chip Alvord <Chip.Alvord@c.onocophillips.com>, JimE-egg <jim_regg@admin.state.ak.us> ') Re: CD2-55 (203-118) Temp Warmback Log ) Re: CD2-55 (203-118) Temp Warmback Log ) ') confirm the bond log results. This has been completed. The well was placed on seawater injection December 23, 2003 to stabilize the injection rate and establish a stable temperature profile. Logging operations commenced on January 6 with an injecting temperature log conducted at a stabilized rate of 3800 to 4000 BWPD. Following the injection pass, the well was shut in and two additional temperature passes were conducted at approximately 24 and 48 hours elapsed time. These passes showed the typical warm back response of an Alpine injector in the open hole section and indicated there was no water movement above the 7" casing shoe. As you can see from the attached log, the temperature above the shoe is quite uniform with no cooling anomolies. Based on all available information I have concluded that zonal isolation has been achieved. Depths of interest (bottom) are: 7" casing shoe - 12,210' MD 4.5" Tubing Tail - 11,995' MD Lower Packer - 11,942' MD Regards Cliff Crabtree Alpine Subsurface Office Telephone: Mobile Telephone: Development - ConocoPhillips Alaska, Inc. (907) 265-6842 (907) 240-5357 «2-55fwb.zip» «CD2-55 Schematic.pdf» 2 of2 1/12/2004 1 :07 PM " ConocoPhiUips Alaska,..~:g!~ TUBING (0-11995, 00:4.500, 10:3.958) 'RODUCTION (34-12210, 00:7.000, Wt:26.00) Gas Lift I , MandrelNalve 1 ,-.- (10489-10490, ¡ :; 00:5,984) ì ::: , r L NIPPLE (11027·11028, 00:5.000) PACKER (11126-11127, 00:5.970) PACKER (11935-11936, 00:5,970) NIP (11983-11984, 00:5.000) OPEN HOLE (1221 0-15238, 00:6.125) -. ~ :'". ~j'~;' . : . . ,,,;. 1.·,.·.:,."" '0:". ..... ',,,":"~ ::.Ff..i"t I ,:,,1, w~ ''"'';;;;'''):< ''1'" >.1 r·:;~;·:;~~~,~~ ~~~}:; ~,~~~¡ Casing String - ALL STRINGS Description CONDUCTOR PRODUCTION SURFACE OPEN HOLE Tubing String - TUBING . Size J Top 4.500 0 G.ss Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Mfr Run 1 10489 6832 CAMCO KBG-2 OV 1,0 BK 0.250 0 11/5/2003 Other (plugs, equip., etc.) . JEWELRY (Top of Alpine estimated (Ö} bottom of Production String) Depth TVD Type Description 34 34 HANGER 4.5" IBT FMC TUBING HANGER 2248 1992 NIP CAMCO 'DB-6' LANDING NIPPLE 11027 7070 NIPPLE HES 'X' NIPPLE 11126 7107 PACKER BAKER PREMIER PACKER 11935 7302 PACKER BAKER PREMIER PACKER 11983 7306 NIP HES 'XN' NIPPLE 11994 7307 WLEG General Notes Date Note 8/31/2003 CEMENT SQUEEZE @ 11,300' to 12,100' CTMD, FOLLOWED BYMILLOUT; REDRILL BY RIG 10/1/2003 TREE: FMC 4 1/16 5K TREE CAP CONNECTION: 7" OTIS CD2.55 API: 501032046300 SSSV Type: NONE Annular Fluid: Reference Log: 36' RKB Last Tag: Last Tag Date: ,:> Os - \ \ <?;. ) ALPINE Well Type: SVC Orig 7/28/2003 Completion: Last W/O: Ref Log Date: TO: 15238 ftKB Max Hole Angle: 93 deg @ 14738 Size 16.000 7,000 9,625 6.125 Top o 34 36 12210 Bottom 109 12210 2797 15238 Bottom 11995 Wt I Grade I 12,60 . L-80 TVD 7307 CD2-55 Angle @ TS: deg @ Angle @ TO: 93 deg @ 15238 Rev Reason: Change TBG top Last Update: 11/23/2003 TVD 109 7321 2406 15238 Wt 62.50 26,00 36.00 0.00 Grade H-40 L-80 J-55 Thread WELDED BTCM BTC Thread IBTM Vlv Cmnt ID 3.958 3,812 3.813 3.875 3.875 3.725 3.875 ') ConocóP'hillips G. C. Alvord Alpine Drilling Team Leader ) Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 January 6, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for C02-55 (APD 203-118) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well C02-55. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ¡fI'.: / 0 C ¡/' \:)< \......f" . G. C. Alvord Alpine Drilling Team Leader CP AI Drilling and Wells GCA/skad RECEIVED JAN 0 7 2004 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL ) STATE OF ALASKA '\ ALASì,r\ OIL AND GAS CONSERVATION COMM. liON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas U GINJ D 2. Operator Name: WINJ 0 WDSPL 0 Plugged 0 Abandoned 0 20AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. Q. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 2113' FNL, 1497' FEL, Sec. 2, T11 N, R4E, UM At Top Productive Horizon: 976' FSL, 404' FEL, Sec. 10, T11 N, R4E, UM Total Depth: 1965' FNL, 1183' FWL, Sec. 14, T11 N, R4E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371738 .j y- TPI: x- 367431 ¡ y- Total Depth: x - 368970 y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GR/Res, GR-CCL, SCMT 22. CASING SIZE WT. PER FT, 34"x16" 62.5# 9.625" 36# 7" 26# GRADE H-40 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2797' Surface 12210' J 5974244 5966848 ./ 5963879 Zone-4 Zone-4 Zone-4 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 11883'-11884' MD 7295' -7295.5' TVD 6 spf 11775' MD 7280' TVD The perforations noted above were shot to perform a cement squeeze; they are / not open to production. The perforations are plugged with cement and straddled by two Premier packers. 26. Date First Injection December 23, 2003 Date of Test Hours Tested N/A Flow Tubing Casing Pressure Suspended 0 WAG 0 20AAC 25.110 Other 5. Date Comp., Susp., ¡/ or Aband.: October 1,2003 6. Date Spudded: July 13, 2003 v 7. Date TO Reached: ,/ September 29, 2003 8. KB Elevation (ft): RKB 37' 152.5' AMSL 9. Plug Back Depth (MD + TVD): 15238' MD 1 7355' TVD 10. Total Depth (MD + TVD): 115238' MD 1 7355' TVDI 11. Depth where SSSV set: Land Nipple @ 2248' 19. Water Depth, if Offshore: N/A feet MSL HOLE SIZE 1b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic Test 0 12. Permit to Drill Number: 203-118 1 303-211/303-232/303-293 13. API Number: 50-1 03-20463-00 14. Well Name and Number: C02-55 15. Field/Pool(s): Colville River Field Alpine Oil Pool 16. Property Designation: ADL 380075 1 387207 17. Land Use Permit: N/A 20. Thickness of Permafrost: 1561' MD 42" CEMENTING RECORD Portland Type III 401 sx AS III Lite & 232 sx Class G 263 sx Class G /0 ' /'-(13 ~ì) cÕ'RrG=V\!ÄL 12.25" 8.5" AMOUNT PULLED SIZE cement retainer at 11860' MD TUBING RECORD DEPTH SET (MD) 11995' PACKER SET (MD) 11126', 11935' 24. 4.5" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11300'-12100' 15.8 ppg Class G Cement, 6 bbls total (4.3 bbls in 8.3" x 7" annulus, 1.7 bbls in formation) WATER-BBL GAS-MCF W A TER-BBL PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL GAS-MCF Test Period n> Calculated OIL-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessaryR E eEl V E 0 Submit core chips; if none, state "none". ROO~~S B~:·L j~" 01-- NONE Form 10-407 Revised 2/2003 JAN 0 7 2004 Alaska Oil & Gas Cons. Commission Anchorage Submit in duplicate ~f GEOLOGIC MARKERS ') 29. ") FORMATION TESTS 28. NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD2-55 Seabee Form. Nanushuk Gamma Ray Shale Kalubik Kuparuk Form. Miluveach Top Alpine D Top Alpine C Alpine A Base Alpine TD 2804' 4679' 10541' 10987' 11091' 11215' 11680' 11890' not available not penetrated 15238' 2412' 3843' 6857' 7055' 7095' 7137' 7263' 7296' n/a N/A RECEIVED JAN 0 7 2004 7355' Alaska Oil & Gas Cons. Commission Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name G. L. Alvord S~nalure .;4 i.. ~ Title: Alpine Drilling Team Leader l &)'. G (1.. 0 Date ¡ i 0(:, ( 0 4-. Phone Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: list all test information. If none, state "None". Form 1 0-407 Revised 2/2003 O~IGtNAL 4.50 MOVE MOVE MOVE Move pits and motor complex away fro rig. Slide rig floor back. Jack-up legs and move rig away from CD2-20. Move rig over CD2-55 and spot sub. Lower legs and slide floor into drilling position. Move motor and pit complex. Accept rig @ 17:00 hrs 7/13/2003. Take mud into pits. Hook up hoses and N/U riser P/U mud motor and bit. M/U stand hwdp Circulate conductor for leaks. Test mud line to 3000 psi Clean out conductor to 115'. Rack back stand of hwdp P/U MWD and M/U BHA. Orient and upload, M/U stabilizer and D.C's Drill from 114' to 220' wI gyro surveys. ART =.5, AST =.2, ADT =. 7, TVD= 220', PU=90k, SO= 85 k, Rot=90k, Rotary=60, WOB=10-15, Pmp=810 psi @ 120 spm, Drill from 220' to 1068'. ADT =6.2, ART =1.8, AST =4.4, PU=120k, SO=118k, Rot= 120k, Torque=8000 on, 5500 off. Rotary=60, WOB=25/30, Pump=1350 psi @ 120 spm Lost highline power go to rig engines, CBU POOH tight from 836' to 801', POOH to 793'. Hole swabbing. Try to circulate-packed off, unable to circulate. RIH to 973'. Establish circulation. Circulate @ 929'. PUmp out to 778' and started packing off. Circulate and pump out to 703'. Regained highline power RIH from 703' to 1010' and wash and ream to bottom. CBU Drill from 1068' to 2210'. ART=4.7, AST=1.7, ADT-6.4, PU=133k, SO=123k, Rot = 132k, Torque= 8000 on, 6000 off, Rotary=60, WOB=20-30, Pump =1820 psi @ 120 spm, Drill 12 1/4" hole f/2210' to 2810' MD 2416' TVD ADT - 7.4 hrs = ART- 5.30 hrs. AST- 2.1 hrs. WOB 30/40 k RPM - 60 GPM 588 @ 2060 psi St. wt. PU 150 SO 130 Rot 137 Torque onloff btm 9000/8000 ftllbs. Circulate hole clean for wiper trip 630 gpm @ 1950 psi wI 70 RPM Monitor well- static - Wiper trip f/ 2810' to 1232' pulled on trip tank- Hole took proper filII - Hole swabbing @ 1232' Tight spots @ 2473', 1810' & 1232' - 40 k over Circulate btms. up @ 1232' - work pipe 294 gpm @ 560 psi - pump out to 1194' - flow check - static Contiune wiper trip fl 1194' to 643' on trip tank - hole in good condition - Flow check -static RIH fl 643' to 2728' - wash to btm fl 2728' to 2810' - hole in good condition Pump sweep & circulate hole clean for trip out for casing Flow check - static - POOH on trip tankk fl 2810' to 167' - hole slick - took proper fill - Std back HWDP & jars - Std back 8" NM DC's LD 12 1/4" BHA - stab, UBHO sub, Float sub, MWD, motor & bit RU to run 9 5/8" casing - held PJSM Run 9 5/8" 36# J-55 BTC casing as follows: FS, 2 jts. FC, 2 jts. SakerLoc 1 st four connections - fill pipe - circ & check floats - 25 jts. to 1218.27' (29 jts. total) - took wt. on jt # 30 - 1220' - washed downd jts 30,31,32,& 33 to 1375' - Circ @ 1375' - 4 bblsl min @ 200 psi - 1.75 CASE RUNC SURFAC Continue running 9 5/8" 36# J-55 BTC casing fl 1375' as follows: ran 33 jts to 2757.8' ( 66 jts. total) - PU FMC hanger & landing jt. - land casing on landing ring wI fluted mandrel hanger wI shoe @ 2796.62' & FC @ 2708.82' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-55 C02-55 ROT - DRILLING doyon1 @ppco.com Doyon 19 Date Fròm-ToHóUts Code 8o~~ Phase·· 7/13/2003 12:00 - 16:30 16:30 - 18:00 1.50 DRILL RIRD RIGUP 18:00 - 19:00 1.00 DRILL PULD SURFAC 19:00 - 20:00 1.00 DRILL CIRC SURFAC 20:00 - 20:30 0.50 DRILL REAM SURFAC 20:30 - 22:00 1.50 DRILL PULD SURFAC 22:00 - 00:00 2.00 DRILL DRLG SURFAC 7/14/2003 00:00 - 09:15 9.25 DRILL DRLG SURFAC 09:15 - 09:45 0.50 DRILL CIRC SURFAC 09:45 - 10:15 0.50 DRILL WIPR SURFAC 10: 15 - 11: 15 1.00 DRILL WIPR SURFAC 11:15 -13:00 1.75 DRILL WIPR SURFAC 13:00 - 14:00 1.00 DRILL WIPR SURFAC 14:00 - 00:00 10.00 DRILL DRLG SURFAC 7/15/2003 00:00 - 09:45 9.75 DRILL DRLG SURFAC 09:45 - 11 :15 1.50 DRILL CIRC SURFAC 11 :15 - 12:30 1.25 DRILL WIPR SURFAC 12:30 - 13:00 0.50 DRILL CIRC SURFAC 13:00 - 13:30 0.50 DRILL WIPR SURFAC 13:30 - 14:30 1.00 DRILL TRIP SURFAC 14:30 - 15:30 1.00 DRILL CIRC SURFAC 15:30 - 17:30 2.00 DRILL TRIP SURFAC 17:30 - 19:00 1.50 DRILL PULD SURFAC 19:00 - 20:30 1.50 CASE OTHR SURFAC 20:30 - 00:00 3.50 CASE RUNC SURFAC 7/16/2003 00:00 - 01 :45 Start: 7/13/2003 Rig Release: 10/2/2003 Rig Number: Spud Date: 7/13/2003 End: 10/1/2003 Group: .. .. DescriþtiöhofOpßr~ti()h$ Printed: 10/8/2003 1 :29:29 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: · Date 7/16/2003 01 :45 - 02:15 02:15 - 03:45 03:45 - 06:00 C02-55 C02-55 ROT - DRILLING doyon1 @ppco.com Doyon 19 Hours CödeSub. P.. .haSè .Code Start: 7/13/2003 Rig Release: 10/2/2003 Rig Number: Spud Date: 7/13/2003 End: 10/1/2003 Group: 0.50 CASE OTHR SURFAC LD fill up tool & MU cement head & lines 1.50 CEMENTCIRC SURFAC Stage pumps up slow - Circulate hole clean & condition mud for cement job - 6.5 bbl/min @ 300 psi - reciprocating pipe - Held PJSM 2.25 CEMENT PUMP SURFAC Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water wI nut plug - Pump 5 bbls water fl Dowell - Test lines to 2500 psi - Drop btm plug - Mix & pump 50 bbls Mud Push XL @ 10.5 ppg @ 5.5 bbls/min @ 250 psi - Mix & pump lead slurry ASL @ 10.7 ppg @ 7 bbls/min @ 270 psi - Observed nut plug @ shakers wI 284 bbls lead slurry pumped - finished pumping down surge can - pumped 306 bbls lead slurry - switched to tail slurry - mixed & pumped tail slurry Class G wI D-46 0.20 %, D65 0.30%, S001 2%, @ 15.8 ppg @ 5.4 bbls/min @ 230 psi - pumped 43.7 bbls tail slurry - Dropped top plug wI 20 bbls water fl Dowell- switched to rig pumps & displaced cement w/189 bbl - 9.6 ppg mud @ 7 bbls/min @ 250 to 490 psi - slowing pumps to 3.5 bbls/min for last 17 bbls of displacement - bumped plug wI 1230 psi - check floats - floats held - CI P @ 0545 hrs. Full circulation through job observed spacer @ shakers but no cement returns to surface - Notified AOGCC Jeff Jones & Drilling engineer about top job Pressure test 9 5/8" casing to 2500 psi for 30 mins. RD cement lines & head - LD landing jt - long bails & casing elevators PJSM - ND flow line, turn buckles, riser, mouse hole & service lines - Remove Slip lock starting head Cut slot in conductor - MU & run 1 11/16" Hydril pipe to 142' - unable to get deeper - pulled back to 128' - observed cement on pipe @ 20' below bottom of conductor - rig up cement line - pump water to establish circulation - pumped 12 bbls ASL wI good cement returns to cellar - Pull out 1 11/16" pipe - flush lines & RD 1.50 DRILL OTHR SURFAC Weld up slot in conductor - change saver sub on TD - Change pump liners to 5 1/2" 1.00 WELCTL NUND SURFAC NU FMC Unihead - test seals to 1000 psi - ok 1.50 WELCTL NUND SURFAC NU BOPE 4.50 WELCTL BOPE SURFAC Set test plug - RU to test BOPE - Test BOPE - pipe rams, blind rams, choke & kill line valves, choke manifold valves, TD IBOP's, floor dart & TIW valves to 250 psi & 5000 psi - Hydril to 250 & 3500 psi - performed accumulator closure test - RD test euqipment - Pull test plug - set wear bushing - Witnessing of test waived by Jeff Jones AOGCC PU & RIH 87 jts.(29 stds) 4" drill pipe f/ shed (for 8 1/2" hole section) - Pull & std back in derrick MU BHA#2 - 81/2" Geo Pilot assembly - upload MWD - RIH to 675' - Test Geo Pilot skid unit to 2500 psi - pulse test MWD RIH wI Geo pilot assembly - picking up 4" drill pipe fIshed to 2559' ( 60jts) 06:00 - 06:30 0.50 CEMENTOTHR SURFAC 06:30 - 07:30 1.00 CEMENTOTHR SURFAC 07:30 - 08:45 1.25 WELCTL NUND SURFAC 08:45 - 12:00 3.25 CEMENTTOPJ SURFAC 12:00 - 13:30 13:30 - 14:30 14:30 - 16:00 16:00 - 20:30 20:30 - 00:00 3.50 DRILL PULD SURFAC 7/17/2003 00:00 - 03:30 3.50 DRILL PULD SURFAC 03:30 - 05:30 2.00 DRILL TRIP SURFAC 05:30 - 07:00 07:00 - 10:00 10:00 - 10:30 * PU #2 ghost ream 1.50 RIGMNT RSRV SURFAC Slip & cut drill line 60' - service top drive 3.00 DRILL REAM SURFAC Wash & ream f/2600' to 2706'- Clean out shoe track(cmt - wiper plugs - FC @ 2708' - cmt - FS @ 2796' - rat hole to 2810' 0.50 DRILL DRLG SURFAC Drill 20' new hole fl 2810' to 2830' MD 2432' TVD ADT -.2 hrs. WOB 2/8 k RPM 110 GPM 538 @ 2030 psi Printed: 10/8/2003 1 :29:29 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . d9r1oCQehillipsAlä~kéi . Ope"åti()rI~SU rnmåryf¡~p()rt C02-55 C02-55 ROT - DRILLING doyon1 @ppco.com Doyon 19 Hdurscddêcf6Je Phase 7/17/2003 10:00 - 10:30 0.50 DRILL DRLG SURFAC 1 0:30 - 11: 15 0.75 DRILL CIRC SURFAC 11:15 -12:00 0.75 DRILL LOT SURFAC 12:00 - 00:00 12.00 DRILL DRLG INTRM1 7/18/2003 00:00 - 09:00 09:00 - 09:45 09:45 - 12:00 12:00 - 18:00 9.00 DRILL DRLG INTRM1 0.75 RIGMNT RGRP INTRM1 2.25 DRILL DRLG INTRM1 6.00 DRILL DRLG INTRM1 18:00 - 20:30 2.50 DRILL CIRC INTRM1 20:30 - 22:30 2.00 DRILL WIPR INTRM1 22:30 - 00:00 1.50 DRILL TRIP INTRM1 7/19/2003 00:00 - 00:30 0.50 DRILL TRIP INTRM1 00:30 - 01 :00 0.50 DRILL REAM INTRM1 01 :00 - 12:00 11.00 DRILL DRLG INTRM1 12:00 - 00:00 7/20/2003 00:00 - 12:00 12:00 - 12:30 12.00 DRILL DRLG INTRM1 12.00 DRILL DRLG INTRM1 0.50 DRILL DRLG INTRM1 Start: 7/13/2003 Rig Release: 10/2/2003 Rig Number: Spud Date: 7/13/2003 End: 10/1/2003 Group: pesÞriþtidh øfOperatjons String wt. PU 145 SO 110 Rot 125 Torque on/off btm - 9500/8000 ft./lbs Circulate hole clean for FIT RU - perform FIT/LOT - to 16.0 ppg EMW wI 800 psi w/ 9.6 ppg mud @ TVD 2407' - *Observed leak off @ 790 psi - 15.9 ppg EMW - RD Drill 8 1/2" hole w/ Geo Pilot fl 2830' to 4082' MD 3377' TVD ADT - 8.64 hrs. WOB 10/20 k RPM 150 GPM 616 @ 2080 psi String wt. PU 150 SO 120 Rot 133 Torque on/off btm - 9000/8000 ft./lbs. Change over to 9.6 ppg while drilling fl 2830' to 2845' Experiencing excess housing roll on Geo Pilot Drill 8 1/2" hole wI Geo Pilot fl 4082' to 5036' MD Change out liner & swab on pump #1 Drill 8 1/2" hole wI Geo Pilot f/ 5036' to 5323' MD 4636' TVD ADT 0000 to 1200 hrs. - 7.81 hrs. WOB 15/20 k RPM 80/160 GPM 615 @ 2650 psi String wt. PU 180 SO 125 Rot 150 Torque on/off btm - 11500/10000 ft/lbs. Drill 8 1/2" hole fl 5323' to 6086' MD 4636' TVD ADT - 3.89 hrs. WOB 15/20 k RPM 160 GPM 615 @ 2750 psi String wt. PU 185 SO 125 Rot 148 Torque on/off bmt. - 11500/9500 ft./lbs. Pump hi-vis sweep & circulate hole clean for wiper trip - 615 gpm wI 170 RPM - 2X btms up - pump out 5 stds. to 5609' POOH f/ 5609' to 2745' on trip tank - hole slick 5/10 k over flow check - static RIH f/2745' to 4720' - fill pipe Continue RIH fl 4720' to 5991' Establish circulation - Precautionary wash & ream fl 5991' to 6086' RPM 150 GPM 500 - 613 2620 psi Circulate bottoms up Drill 8 1/2" hole wI Geo Pilot fl 6086' to 7519' MD 5357' TVD WOB 20/22 k RPM 160 GPM 616 @ 3000 psi String wt. PU 205 SO 130 Rot 160 Torque on/off btm. 13500/12500 ft./lbs. ADT - 7.71 hrs. Drill 8 1/2" hole wI Geo Pilot f/7519' to 8982' MD 6037' TVD WOB 20/23 k RPM 160 GPM 616 @ 3130 psi String wt. PU 220 SO 137 Rot 170 Torque on/off btm. 14000/13000 ft./lbs ADT - 8.18 hrs. Drill 8 1/2" hole wI GeoPilot fl 8982' to 10,423' MD 6799' TVD WOB 20/23 k RPM 160 GPM 614 @ 2970 psi String wt. PU 255 SO 140 Rot 183 Torque on/off btm. 16,500/15,500 ft/lbs. ADT - 8.81 hrs. Drill 8 1/2" hole wI Geo Pilot fl 10,423' to 10, 534' MD 6854' TVD WOB 20/23 k RPM 160 GPM 614 @ 3250 psi String wt. PU 255 SO 160 Rot 183 Torque on/off btm. 16,500/15,500 ft/lbs. Printed: 10/8/2003 1 :29:29 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-55 C02-55 ROT - DRILLING doyon1 @ppco.com Doyon 19 Hours·.. Code.· .. Sub. . ... .......... Code Phase ..Date· Frörn "'. To 7/20/2003 12:00 - 12:30 12:30 - 13:30 13:30 - 00:00 0.50 DRILL DRLG INTRM1 1.00 RIGMNT RGRP INTRM1 10.50 DRILL DRLG INTRM1 7/21/2003 00:00 - 06:45 6.75 DRILL DRLG INTRM1 06:45 - 07:15 0.50 RIGMNT RGRP INTRM1 07:15 - 08:30 1.25 DRILL DRLG INTRM1 08:30 - 09:00 0.50 DRILL CIRC INTRM1 09:00 - 10:30 1.50 DRILL OTHR INTRM1 10:30 - 11 :00 0.50 DRILL TRIP INTRM1 11 :00 - 13:00 2.00 DRILL OTHR INTRM1 13:00 - 16:30 3.50 DRILL WIPR INTRM1 16:30 - 18:30 2.00 DRILL CIRC INTRM1 18:30 - 00:00 5.50 DRILL TRIP INTRM1 7/22/2003 00:00 - 02:30 2.50 DRILL TRIP INTRM1 02:30 - 04:30 2.00 DRILL PULD INTRM1 04:30 - 10:30 6.00 DRILL PULD INTRM1 10:30 - 12:30 2.00 DRILL TRIP INTRM1 12:30 - 15:30 3.00 DRILL CIRC INTRM1 Start: 7/13/2003 Rig Release: 10/2/2003 Rig Number: Spud Date: 7/13/2003 End: 10/1/2003 Group: DesöriptidrJofOp~rations . ADT - .7 hrs. Change out 2 swabs on #2 mud pump - Circ & work pipe Drill 8 1/2" hole w/ GeoPilot fl 10,534' to 11529' MD 7230' TVD WOB 22/24 k RPM 160 GPM 580 @ 3790 psi String wt. PU 260 SO 135 Rot 185 Torque onloff btm. 17,000/16,000 ft.llbs. ADT - 7.32 hrs. Drill 8 1/2" hole w/ G P fl 11 ,529' to 12,160' MD 7315' TVD WOB 20 k RPM 160 GPM 579 @ 3660 psi String wt. PU 270 SO 130 Rot 180 Torque on/off btm. 19,000/18,000 ft. Ibs. ADT - 5.16 hrs. Work on pump #2 - replace 2 seats & valves Drill 8 1/2" hole w/ GP fl 12,160' to 12,220' TD 7320' TVD same parameters as above ADT - .63 hrs. Pump hi-vis sweep & circulate hole clean for wiper trip GPM 500 @ 3500 psi RPM 140 Lost returns - mix & spot 40 bbls - 20#/bbl LCM pill (12 sks G-seal, 4 sxs MI seal fine, 5 sxs mix II fine, - @ 2.3 bbl/min @ 420 psi (no returns - keeping annulus full wI hole fill) POOH wI pump fl 12,220' to 11,838' - @ 2 bbbls/min @ 410 psi no returns - keeping aannulus full w/ hole fill Monitor well - hole full - no static losses - Estabilsh circulation wI 2.3 bblsl min. well circulating wI approx. 25 bbls/hr lose rate mix and pump 20 bbls LCM pill - same as above- 2.3 bbls/min @ 410 psi @ 1,838' - pump out to 11,755' total losses - 384 bbls POOH on trip tank fl 11,755' to 10,324' - tight hole @ 11,694 & 11,374 - pulled & worked through various tight spots fl 11,103' to 10,650' - pulling 40 to 75 k over Establish circulation - stage pumps up to 13 bbls/min. -@ 2950 psi - hole begin taking fluid @ 130 bbls/hrs. - slowed pumps to 10.8 bbls/min loss rate slowed to 50 bbls/hr. - circulate and lower mud wt. fl 10 ppg to 9.8 ppg Monitor well - no static losses - POOH f/ 10,324' to 2679' - hole slick & taking 2 t03 bbls excees fill per 5 stds. pulled - monitor well @ 2679' fluid dropped 5' below flow line in 10 mins. Continue POOH fl 2679' - Stand back HWDP & Jars - Flush BHA wI water - continue to POOH wI BHA - std back NM flex DC's Handle BHA - LD float sub - Service GeoPilot while downloading MWD - LD MWD - GeoPilot & bit - Remove GeoPilot skid f/ rig floor MU & RIH wI BHA # 3 - bit (no jets) bit sub - XO - stab - NM flex DC's - stab - 3 HWDP - jars - 11 HWDP - XO - Ghost reamer - 39 jts. 4" DP Ghost reamer - RIH to 9935' (fil pipe every 2000') had returns to 9935' - Continue to RIH wI partial returns 11,620' Drag 10 - 15 k fl 10,985 to 11,400' - drag 10 - 25 k fl 11,400' to 11,573' - Drag increasing to 15 to 35 k fl 11,573' to 11,620' Pull back out fl 11,620' to 11,367' - Pulled 50 to 75 over fl 11,620' to 11,462' Establish circ @ 11,367' - 3.3 bbls/min @ 630 psi - stage pump up to 5 bbls/min 790 psi - Hole started taking fluid @ 48 bbls/hr. slowed pump to 2.5 bbls/min @ 550 psi - Lost all returns - fluid level 2" below flow line - Work pipe & pump @ 2.5 bbls/min while mixing LCM pill 40 bbls @ Printed: 10/8/2003 1 :29:29 PM .·.··C(in()ë(j~hinips.·~Ia.skª Øþe"å~iqn$ ..$~I11rT1arYRep()"t Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-55 CD2-55 ROT - DRILLING doyon1 @ppco.com Doyon 19 Start: 7/13/2003 Rig Release: 10/2/2003 Rig Number: Spud Date: 7/13/2003 End: 10/1/2003 Group: Date . From..; To Hours COdè ..Sub ··C6de 7/22/2003 12:30 - 15:30 3.00 DRILL CIRC INTRM1 15:30 - 18:00 2.50 DRILL CIRC INTRM1 . pescription· of. Operations·. 45#/bbl - spot LCM pill Increase pump rate to 3.3 bbls/min hole taking fluid @ 48 bblsl hr - losses slowed to < 10 bbls/hr - Increase pump to 3.75 bbls I min. - Circulate hole to lower mud wt. 10.5 ppg returns fl well - 9.8 ppg going in - losses @ 10 to 15 bblsl hr. - getting 9.9 ppg mud out RIH f/11 ,367' to 11,621' - took wt - wash & ream fl 11,621' to 12,220' @ 4.5 bbls/min wI 50 RPM's Rotate & recip pipe & circulate @ 5bblsl min @ 620 psi (3000 stks) - loss rate <15 bbls/hr - Pump out 7 stds. fl 12,220' to 11,553' @ 5 bbls/min 670 psi 50 RPM's Circulate to clean up hole - 6 bbls/min @ 770 psi 70 RPM - standing back 1 std every 45 to 60 mins. Losses less than 5 bbls/hr Circ hole clean - increased rate to 7 bpm 1930 psi 170 rpm, set back one stand per hour, no losses. Monitor well, static. POOH on trip tank from 11171' to 2579', hole in good shape, hole fill 24 bbls over calc. Slip and cut drlg line - service top drive. (1.4 bbl hole fill) POOH to HWDP, LD ghost reamer, change elevators to 5" and stand back hwdp. LD bit & XO, set back collars, clear tools and clean rig floor. Make up wash sub and flush BOP stack. Pull wear bushing and set test plug wI 7" test joint. Change top rams to 7" - test rams to 250 & 5000 psi. Pull test plug and test jt. - set thin wall wear bushing. Change bails - MU fill up tool - RU casing elevators, spider and tongs. Held Prejob Safety and Opts meeting. Ran 7", 26#, L-80 BTCM as follows: FS (Ray Oil Tools bullet nose) 2 jts. casing - FC (Weatherford) 2 jts casing (all connections Baker Loc'd - circ and check floats) 62 jts casing -66 jts total to 2755'. Stage pumps up to 5 bpm I 290 psi and circ pipe volume 105 bbls, no losses - PUW 135K SOW 118K. Continue running 7" casing to 4572', 110 jts of 294 jts. ran at midnight. Run casing from 4572' to 7054' (170 jts total) PUW 245K SOW 145K Circ and cond mud - initial rate 2.9 bpm 1480 psi, final rate 4.5 bpm I 400 psi. Maintained mud wt. in @ 9.8 ppg, mud wt. out 10.0 - 10.2 ppg. Circ untill 9.9 ppg mud wt. out - total pumped 269 bbls with full returns. PU wt. 245 SO wt. 145 4.00 CASE RUNC INTRM1 Continue running 7" fl 7054' to 10,354' (250 jts. total) 0.50 CASE CIRC INTRM1 Establish circulation - 4 bblsl min @ 620 psi -lost reutrns after pumping for 10 mins. PU wt. 325 SO wt 160 - continue pumping & attempting to regain returns - lost approx. 120 bbls - fluid level in annulus staying just below flow line 11.00 CASE RUNC INTRM1 Continue runnng 7" casing fl 10,354' to 11550' (279 jts. total) String began excess down drag @ 11565' (15' in on jt # 280) worked casing down f/11,565' to 12,174' (294 jts. total ran) PU hanger & landing jt.-Iand 7" casing on FMC fluted mandrel hanger in wellhead wI shoe @ 12,210' & FC @ 12,124' 0.50 CASE OTHR INTRM1 LD fill up tool- MU cement head and lines. 2.00 CEMENT CIRC INTRM1 Pumped 150 bbls of mud w/4 ppb Mix II fine @ 1.5 -3.0 bpm 1300-380 psi attempting to establish circ, no returns. Pumped 40 bbls pill with 10 ppb Mix II fine I G seal, no returns - total 190 bbls of mud losses. Unable to reciprocate pipe @ 400K - annulus remained full throughout. 18:00 - 20:30 2.50 DRILL REAM INTRM1 20:30 - 22:30 2.00 DRILL CIRC INTRM1 22:30 - 00:00 1.50 DRILL CIRC INTRM1 7/23/2003 00:00 - 02:30 2.50 DRILL CIRC INTRM1 02:30 - 08:30 6.00 DRILL TRIP INTRM1 08:30 - 10:00 1.50 RIGMNT RSRV INTRM1 10:00 - 12:00 2.00 DRILL TRIP INTRM1 12:00 - 13:00 1.00 DRILL PULD INTRM1 13:00 - 13:30 0.50 DRILL OTHR INTRM1 13:30 - 17:15 3.75 CASE OTHR INTRM1 17:15 - 17:45 0.50 CASE SFTY INTRM1 17:45 - 21 :00 3.25 CASE RUNC INTRM1 21 :00 - 21 :30 0.50 CASE CIRC INTRM1 21 :30 - 00:00 2.50 CASE RUNC INTRM1 7/24/2003 00:00 - 02:45 2.75 CASE RUNC INTRM1 02:45 - 04:00 1.25 CASE CIRC INTRM1 04:00 - 08:00 08:00 - 08:30 08:30 - 19:30 19:30 - 20:00 20:00 - 22:00 Printed: 10/8/2003 1 :29:29 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-55 CD2-55 ROT - DRILLING doyon1 @ppco.com Doyon 19 Date · Ërom- To Hours Gpde cfd~e· phase 7/24/2003 20:00 - 22:00 22:00 - 00:00 2.00 CEMENTCIRC INTRM1 2.00 CEMENT PUMP INTRM1 7/25/2003 00:00 - 00:30 0.50 CEMENT DISP INTRM1 00:30 - 01 :30 1.00 CEMENTOTHR INTRM1 01 :30 - 02:30 1.00 CEMENT PULD INTRM1 02:30 - 03:30 1.00 DRILL OTHR INTRM1 03:30 - 05:30 2.00 DRILL OTHR INTRM1 05:30 - 10:00 4.50 WELCTL BOPE INTRM1 10:00 - 10:30 0.50 DRILL OTHR INTRM1 10:30 - 11 :30 1.00 DRILL PULD INTRM1 11 :30 - 16:00 4.50 DRILL PULD INTRM1 16:00 - 17:30 1.50 RIGMNT RSRV INTRM1 17:30 - 19:30 2.00 DRILL TRIP INTRM1 19:30 - 22:30 3.00 WAlTON EQIP INTRM1 7/26/2003 22:30 - 00:00 00:00 - 03:00 1.50 LOG 3.00 LOG OTHR INTRM1 OTHR INTRM1 03:00 - 05:00 2.00 LOG PULD INTRM1 05:00 - 07:00 2.00 LOG ELOG INTRM1 07:00 - 08:30 1.50 LOG ELOG INTRM1 08:30 - 10:00 1.50 LOG PULD INTRM1 10:00 - 15:30 5.50 LOG ELOG INTRM1 Start: 7/13/2003 Rig Release: 10/2/2003 Rig Number: Spud Date: 7/13/2003 End: 10/1/2003 Group: DeSëriptionofOperations .. PJSM. Cement 7" casing as follows: Pumped 3 bbls of fresh water and tested lines to 3500 psi. Mixed and pumped 52 bbls of Mud Push XL @ 12.5 ppg - Dropped bottom plug - Mixed and pumped 53 bbls of cement slurry (Class G wI 0.2% D046, 0.25% 0065, 0.02% EX920, 0.4% 0167, 0.25 Ib/sx D029, 2.0 ppb 0095) @ 15.8 ppg - 4.5 bblslmin 225 psi - Dropped top plug - pumped 20 bbls FW from Dowell - switched to rig pumps and displaced with 8.8 ppg brine - 5 bpm 200 - 660 psi first 343 bbls pumped - increased rate to 7 bpm with spacer at shoe - 374 bbls of brine displaced at midnight (calc to bump 444 bbls). Continue displacing cement w 8.8 ppg brine @ 7 bbls/min. I 830 - 1160 psi - Reduced rate to 3.5 bpm last 10 bbls final pressure 920 psi -bumped plug to 1400 psi - total displacement 458.2 bbls (Used 95% pump output .0836 bbls/stk - calc disp. 463.9 bbls) CIP @ 0010 hrs. Check floats - did not hold. Bumped plug to 1400 psi (4.2 bbls pumped) line up to cement unit - check floats, bled back 2 bbls, floats held. Pressure test 7" casing to 3500 psi for 30 mins. Rig down cement lines & head - LD landing jt. - casing slips & elevators - long bails Pull thin wall wear bushing - Install & test pack-off to 5000 psi for 15 mins. PJSM - Change top pipe rams bac k to 3 1/2" X 6" VBR - Change junk sub in TD Set tet plug - Test BOPE - Hydril to 250 & 3500 psi - Pipe rams - bkind rams, kill and choke line valves, choke manifold valves, Top drive IBOP's',rig floor TIW & dart valves to 250 & 5000 psi Performed accumulator closure test - witnessing of test waived by Chuck Scheve & John Crisp AOGCC Rig down test equipment - Pull test plug - set wear bushing PU drilling bails & DP elevator PU motor & AGS, function AGS, LD motor & AGS PU & RIH wI 171 jts (5437') 4" DP for 61/8" section Slip & cut drill line - Service Top Drive. POOH - stand back 4" drill pipe. Schlumberger E-line truck would not start. APC mechanics worked on truck and replaced dead batteries. Logging truck arrived on location @ 2230 hours. Schlumberger crew arrived at Alpine @ 1730 hrs. Spot Schlumberger equipment and rehead from 0.23" line to 0.39" line. Continue to re-head wireline tool - RU 440V generater for SWS - Meg cable, found one conductor shorted out. Cut 400' of cable, meg line 6 of cable, still bad. Located problem at collective on drum, repaired same- rehead cable again. PJSM wI SWS & rig crew - RU SWS - PU tools & function test tools RIH wI Run # 1 USIT/GR/CCL to 11750' - tool failure - SWS worked through surface soft ware attempting to make tool work - no luck POOH wI tools -tool started sending signal to surface @ 2300' - continue POOH check tools @ surface - found nothing in motor Change out tool string RIH wI run # 2 USIT/GR/CCL to 11,730' -logging down - Log showed no cement to 11,730' - tool started acting up same as before @ same depth - Pulled up to 11,650' - attempt to get tool working - Ran logging Printed: 10/8/2003 1 :29:29 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-55 C02-55 ROT - DRILLING doyon1 @ppco.com Doyon 19 ····Date Frorï1~ To Hours · Code cfo~e Phase 7/26/2003 10:00 - 15:30 5.50 LOG ELOG INTRM1 15:30 - 17:00 17:00 - 22:00 22:00 - 23:00 1.50 WAlTON EQIP INTRM1 5.00 DRILL TRIP INTRM1 1.00 CEMENTCOUT INTRM1 23:00 - 00:00 1.00 DRILL CIRC INTRM1 7/27/2003 00:00 - 00:30 0.50 DRILL CIRC INTRM1 00:30 - 04:30 4.00 DRILL TRIP INTRM1 04:30 - 07:30 3.00 LOG PULD INTRM1 07:30 - 08:00 0.50 LOG PULD INTRM1 08:00 - 11 :30 3.50 LOG ELOG INTRM1 11 :30 - 13:00 1.50 LOG ELOG INTRM1 13:00 - 13:30 0.50 DRILL OTHR INTRM1 13:30 - 17:00 3.50 DRILL TRIP INTRM1 17:00 - 17:30 0.50 RIGMNT RSRV INTRM1 17:30 - 00:00 6.50 DRILL PULD INTRM1 7/28/2003 00:00 - 01 :00 1.00 DRILL OTHR SUSPEN 01 :00 - 02:30 1.50 DRILL PULD SUSPEN 02:30 - 04:45 2.25 WELCTL NUND SUSPEN 04:45 - 06:00 1.25 WELLSR NUND SUSPEN 9/23/2003 22:00 - 00:00 2.00 MOVE DMOB DEMOB 9/24/2003 00:00 - 07:00 7.00 MOVE RURD MOVE 07:00 - 08:30 1.50 MOVE RURD MOVE 08:30 - 09:00 0.50 DRILL RIRD SUSPEN 09:00 - 11 :00 2.00 WELCTL BOPE SUSPEN 11 :00 - 12:30 1.50 WELCTL BOPE SUSPEN 12:30 - 14:00 1.50 WELCTL BOPE SUSPEN 14:00 - 18:00 4.00 WELCTL BOPE SUSPEN Start: 7/13/2003 Rig Release: 10/2/2003 Rig Number: Spud Date: 7/13/2003 End: 10/1/2003 Group: Description of Operå.tibhs tools in hole f/11 ,650' to 11,842' wI tractor - amps increased on tractor indicating possible fill - Pulled up to 11,812' - attempt to get tools working - no signal to surface - POOH and LD logging tools. Wait on 7" casing scraper and xo's. MU bit, csg scraper and bha, RIH to 11732', fill pipe every 2000'. Wash and ream from 11732' to 11953', drill out cement from 11953' to 12100' - 8.0 bpm I 1640 psi I 75 rpm. Pumped 40 bbls 130 FV viscosified brine sweep and circ hole clean. 9.0 bpm I 1890 psi I 75 rpm PUW 265K SOW 140K ROT WT 180K Torgue onloff 15.5K I 14K Continue to circulate btms up - 9 bblslmin @ 1890 psi wI 75 rpm - flow check - Pump dry job POOH - std back HWDP & NM flex DC's - LD bit, scraper & bit sub RU SWS - work on SCMT tool string PU SCMT tools & tractor for Run #3 - surface test tools RIH wI SCMT& tractor - to 11,185' tools string set down - Power up tractor & RIH SCMT wI tractor fl 11,185' to 12,075' - log fl fl 12,061' to 11,600' - Run repeat fl 12,061' to 11,650' - SCMT log indicated no cement isolation above top of Alpine sand .. NOTE - Decision made to suspend well POOH wI wireline - LD tools - RD SWS Prep to RIH wI 4" drill pipe MU mule shoe - RIH wI 4" drill pipe to 1 0408' (109 stds). Servive Top Drive and Drawworks. POOH to 2289' - LD 255 jts of 4" drill pipe for rig move. PJSM - RU & test lines to 1000 psi - Freeze protect 7" casing wI 73 bbls diesel Finish laying down 4" drill pipe Pull wear bushing - ND BOPE - Change out TD junk sub - top off 7" casing wI diesel NU tree & test to 2500 psi - bleed off pressure to 0 psi - Secure well SUSPEND WELL RELEASE RIG @ 0600 HRS. 7/28/2003 RD to move to CD2-55. Weld Cattle Chute door rails, move pipe shed, move pits, move sub off of CD2-18 well. Move rig from CD2-18 to CD2-55. Install landing, spot substructure, pits and motors. RU service lines, RU to highline power. Spot ball-mill. NOTE: RIG ACCEPTED AT 0830 HRS, 9/24/2003. ND tree. NU BOPE, change out Top Drive crossover. Set test plug - RU to test BOPE - Test BOPE - pipe rams, blind rams, choke & kill line valves, choke manifold valves Change out lower IBOP and retest Continue wI floor dart & TIW valves to 250 psi & 5,000 psi - Hydril to 250 & 3,500 psi - performed accumulator closure test - RD test equipment - Pull test plug - set wear bushing - Witnessing of test waived by Lou Grimaldi, AOGCC. 0.50 RIGMNT RSRV SUSPEN Service rig. 5.50 RIGMNT RGRP SUSPEN Attempt to fully open Blind Ram, by functioning. Only one side (off 18:00 - 18:30 18:30 - 00:00 Printed: 10/8/2003 1 :29:29' PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-55 C02-55 ROT - DRILLING doyon1 @ppco.com Doyon 19 Hours Cbdé .ðo~be Phase· 9/24/2003 18:30 - 00:00 9/25/2003 00:00 - 04:45 04:45 - 05: 15 05:15 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 09:00 09:00 - 09:30 09:30 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 18:00 18:00 - 19:00 19:00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 9/26/2003 00:00 - 02:00 02:00 - 03:00 03:00 - 06:30 06:30 - 07:00 07:00 - 08:00 08:00 - 09:00 09:00 - 10:30 10:30 - 12:00 12:00 - 15:30 15:30 - 17:30 17:30 - 18:30 18:30 - 21 :00 21 :00 - 22:00 Start: 7/13/2003 Rig Release: 10/2/2003 Rig Number: Spud Date: 7/13/2003 End: 10/1/2003 Group: 5.50 RIGMNT RGRP SUSPEN driller side) would close. Inspect and change out Ram. NOTE: RIG ON DOWNTIME AS OF 1830 HRS, 9/24/2003. 4.75 RIGMNT RGRP SUSPEN Change out double gate blind Ram. NU BOPE and install blind ram. 0.50 RIGMNT RGRP 0.75 RIGMNT RGRP 0.50 RIGMNT RGRP 1.50 DRILL TRIP 1.00 DRILL CIRC 0.50 DRILL TRIP 1.00 DRILL 0.50 DRILL 1.00 DRILL 6.00 DRILL 1.00 DRILL TRIP PULD PULD TRIP OTHR 2.50 DRILL 1.50 DRILL TRIP TRIP 1.00 DRILL SUSPEN SUSPEN SUSPEN SUSPEN SUSPEN SUSPEN SUSPEN SUSPEN SUSPEN SUSPEN SUSPEN SUSPEN SUSPEN DRLG SUSPEN 2.00 DRILL DRLG INTRM1 1.00 DRILL DEOT SUSPEN 3.50 DRILL DRLG INTRM1 0.50 DRILL DRLG INTRM1 1.00 DRILL CIRC INTRM1 1.00 DRILL FIT INTRM1 1.50 DRILL TRIP PROD 1.50 DRILL 3.50 DRILL 2.00 DRILL TRIP PROD TRIP PROD PULD PROD 1.00 DRILL TRIP PROD 2.50 DRILL TRIP PROD 1.00 RIGMNT RSRV PROD Pull wear ring and install test plug. Test pipe ram BOP body, test blind rams 250/5,000 psi. Pull test plug, install wear ring, install mouse hole. PU overshot and RIH to 1,950'. Displace diesel from hole with 8.8 ppg brine at 140 gpm pumping to outside tank. Approximately 65 bbls recovered. Note: A rig fire and man-down evacuation drill was held with the Alpine Rescue team. RIH and engage wireline retrievable bridge plug, WRP, at 2,001' driller depth. Open bypass and monitor well, circulate 10 bbl of brine to outside tank, with no diesel. Release WRP. POOH with WRP. LD WRP and retrieving tool. Makeup BHA for cleanout run. PJSM. PU 75 stands of 4" DP, RIH filling every 2,000'. Slip and cut 60' of drill line and service TD and rig. Circulate out diesel from the well at 7,456'. Continue RIH from 7,456'-11,848' SLM. Wash to 11,873' and tag cement retainer. Remove 55-60 bbls of diesel from the pits that was circulated out while RIH. Drill cement retainer (20 minutes), drill cement stringers to 11,880'. WOB 5/10 k RPM 50 GPM 350 @ 1300 psi String wt. PU 270 SO 140 Rot 185 Torque onloff btm - 12,000/14,500 ft./lbs. Drill cmt stringers from 11,880 - 12,105' at 350 GPM and 1,450 psi, 90 RPM. Test csg to 1,025 psi, with 8.8 ppg brine to 11.5 ppg EMW for 15 min, attempt to isolate leak and retest 5 min. RD test equip. Drill Float Collar, shoe track and Float Shoe f/12,1 05 - 12,220. Tag shoe at 12,210'. Drill new hole from 12,220-12,240' while displacing hole to 8.8 ppg Flo-Pro system, pumping at 250 GPM, 900 psi, and 100 RPM. Circulate and continue displacing hole to 8.8 ppg Flo-Pro system, pumping at 250 GPM, 900 psi, and 100 RPM. POOH to 12,162', flow check, close rams and attempt FIT to 11.5 ppg EMW, pressure leaked off at 800 psi or 10.8 ppg EMW. Check flow pump out to 11,683' at 140 GPM, 520 psi, hole took 2 bbl excess fill. Blow dwn TD, flow check, POOH on trip tank to 8,425' POOH to BHA, flow check, stand back BHA and break bit. MU BHA #6, orient MWD, upload. Shallow hole test MWD at 150 GPM and 310 psi. Finish RIH wI BHA, RIH wI 10 stds of 4" DP from the derrick. RIH picking up 99 jts of 4" DP from the shed to 4,470'. Repair broken cable on Service Loop, service drawworks and TD, cut and slip drill line. Printed: 10/8/2003 1 :29:29 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-55 C02-55 ROT - DRILLING doyon1 @ppco.com Doyon 19 ··Date Suþ ·FrorTI...To· Hours Gode Code Phase 9/26/2003 9/27/2003 22:00 - 00:00 00:00 - 02:30 2.00 DRILL TRIP PROD 2.50 DRILL TRIP PROD 02:30 - 12:00 9.50 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 9/28/2003 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 9/29/2003 00:00 - 05: 15 5.25 DRILL DRLH PROD Start: 7/13/2003 Rig Release: 10/2/2003 Rig Number: Spud Date: 7/13/2003 End: 10/1/2003 Group: Continue RIH with 4" DP from the derrick. Continue RIH with 4" DP from the derrick to 12,220', break circulation and wash and ream from 12,220-240' at 200 GPM, 1250 psi, RPM 50. Note: Saw 4 spots of decreasing string weight from 11,000'-11,378'. Spot at 11,378' took 25K, PU and worked thru without seeing the spot again. Drill 61/8" horizontal section fl 12,240' to 12,865' MD 7358' TVD ADT - 6.98 hrs. = ART - 6.65 hrs. AST - 0.33 hrs. WOB 5/8 k RPM 0/80 GPM 204 @ 1,620 psi String wt. PU 210 SO 145 Rot 180 Torque onloff btm - 10,500 I 9,500 ft/lbs. Average ECD 10.0 ppg Motor: 1.22 deg, 0.77 revslgal Bit to DIR - 34.43' Bit to RES - 48.48' Bit to GR - 55.24' Drill 6 1/8" horizontal section fl 12,865' to 13,370' MD 7357' TVD ADT - 6.42 hrs. = ART - 4.42 hrs. AST - 2.0 hrs. WOB 4/10 k RPM 0/95 GPM 211/186 @ 1,860 I 1580 psi String wt. PU 215 SO 150 Rot 182 Torque on/off btm - 10,000 I 9,500 ft/lbs. Average ECD 10.1 to 10.2 ppg Note: Began seeing losses of 10-20 bbl/hr at 13,340'. Added NutPlug-Med to system at 10 min/sack. Losses quit by the time the next two stands were drilled down. Drill 61/8" horizontal section fl 13,370' to 14,201' MD 7374' TVD ADT - 6.73 hrs. = ART - 6.73 hrs. AST - 0.0 hrs. WOB 5/8 k RPM 60/90 GPM 204 @ 1,800 psi String wt. PU 210 SO 150 Rot 180 Torque on/off btm - 10,500 I 10,000 ft/lbs. Average ECD 10.2 to 10.3 ppg Total mud loss over 12 hours: 30 bbl Motor: 1.22 deg, 0.77 revslgal Bit to DIR - 34.43' Bit to RES - 48.48' Bit to GR - 55.24' Drill 6 1/8" horizontal section fl 14,201' to 14,911' MD 7355' TVD ADT - 10.2 hrs. = ART - 9.2 hrs. AST - 1.0 hrs. WOB 4/10 k RPM 60/90 GPM 204 @ 1,960 psi String wt. PU 220 SO 150 Rot 182 Torque on/off btm - 11,000 I 10,000 ft/lbs. Average ECD 10.3 to 10.4 ppg Total mud loss over 12 hours: 20 bbl Drill 6 1/8" horizontal section fl 14,911' to 15,238' MD 7343' TVD ADT - 2.67 hrs. = ART - 2.5 hrs. AST - 0.17 hrs. WOB 5/10 k RPM 0/80 GPM 204 @ 1,770 psi String wt. PU 220 SO 145 Rot 185 Printed: 10/8/2003 1 :29:29 PM Legal Well Name: CO2-55 Common Well Name: CO2-55 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 . Date From-fo HÖurs Code Sub PhaSe Códe 9/29/2003 00:00 - 05:15 5.25 DRILL DRLH PROD 05:15 - 09:00 3.75 DRILL CIRC PROD 09:00 - 10:15 1.25 DRILL TRIP PROD 10:15 - 10:45 0.50 DRILL TRIP PROD 10:45 - 12:00 1.25 DRILL CIRC PROD 12:00 - 14:00 2.00 DRILL CIRC PROD 14:00 - 17:00 3.00 DRILL CIRC PROD 17:00 - 19:30 2.50 DRILL TRIP PROD 19:30 - 20:30 1.00 RIGMNT RSRV PROD 20:30 - 00:00 3.50 DRILL PULD PROD 9/30/2003 00:00-01:15 1.25 DRILL PULD PROD 01:15-04:00 2.75 DRILL TRIP PROD 04:00 - 05:00 1.00 DRILL PULD PROD 05:00 - 13:30 8.50 DRILL TRIP PROD 13:30 - 14:00 0.50 DRILL TRIP PROD 14:00 - 15:00 1.00 RIGMNT RSRV PROD 15:00 - 18:30 3.50 DRILL PULD PROD 18:30 - 21 :00 2.50 DRILL TRIP PROD 21 :00 - 21 :30 0.50 DRILL PULD PROD 21 :30 - 22:00 0.50 CMPL TN RURD CMPL TN 22:00 - 00:00 2.00 CMPL TN RUNT CMPL TN 1 0/1/2003 00:00 - 00:45 0.75 CMPL TN RUNT CMPL TN 00:45 - 01:15 0.50 RIGMNT RSRV CMPL TN 01 :15 - 02:45 1.50 CMPL TN RUNT CMPL TN 02:45 - 03:15 0.50 RIGMNT RGRP CMPL TN 03:15 - 09:30 6.25 CMPL TN RUNT CMPL TN 09:30 - 10:45 1.25 CMPL TN NUND CMPL TN 10:45 - 13:00 2.25 CMPL TN NUND CMPL TN 13:00 - 15:30 2.50 CMPL TN NUND CMPL TN Start: 7/13/2003 Rig Release: 10/2/2003 Rig Number: Spud Date: 7/13/2003 End: 10/1/2003 Group: DescriptiOn· öfOperations· Torque on/off btm - 11,500 I 11,000 ft/lbs. Average ECD: 10.4 ppg Circ Btms Up per geologist (Well TD'd early), at 80 rpm and 204 GPM, 1780 psi. Circ Hi-Vis sweep at 90 rpm, 200 GPM, 1,700 psi. Final circulating pressure 1,550 psi. Pump out from 15,238' - 14,296', check flow. RIH to 15,150', check flow. Establish circulation at 90 rpm, 204 GPM, 1,700 gpm. CBU and work pipe from 15,160'-15,238'. Circulate, rotate and recipricate pipe while taking on 8.8 ppg, KCI brine and mixing Hi-Vis displacement pill. PJSM. Pump 40 bbl Hi-Vis, 8.8 ppg spacer. Displace hole with 8.8 ppg KCI brine at 215 GPM with Initial circulating pressure of 1,610 psi and final circ. pressure of 1,310 psi when the brine was at the surface. (maximum ECD during displacement = 10.4 ppg). Pumped 40 bbl LCM pill when displacement pill arrived at surface. Displaced LCM 1,000' above bit, in open hole. Monitor well. Well losing 6 bbllmin after hole was displaced to brine. POOH from 15,160' to 12,193', using the trip tank. Monitor well. Static loss rate = 6 bbllhr Service drawworks and TD. PJSM. POOH laying down excess DP from 12,193' to 7,932' (135 jts). Lay down drill pipe to 6378 (48 jts) POOH to 1000'. Check flow. POOH to BHA. Flush BHA and stand back Flex Collars. UD BHA M/U bit, boot baskets and casing scraper. RIH to 12034', made two passes across packer setting depths and squeeze perfs. Monitor well, static losses @ 5 bph. POOH from 12034' to 11555' on trip tank. Losing 5 bph. Cut and slip 60' of drilling line. Flow check and pump slug UD 147 jts. 4" d.p. from 11555' to 6882' POOH to BHA @ 200'. Flow check-annulus dropping UD bit, junk baskets and scraper. Recovered handfull of metal in junk baskets Pull wear bushing. Clear rig floor and rlu to run tubing Hold safety meeting. M/U WLEG, pup, XN nipple, 1 jt tubing and Baker packer. Run 18 jts tubing and 2nd Baker packer. Lost total of 87 bbl brine to formation last 24 hrs. Pick up 41/2" tubing - RIH with Completion equipment from 956' to 1800'. Service rig Continue to pick up tubing from 1800' to 3735'. Change tubing tongs Continue to pick up tubing ( 274 jts total) MU hanger and land in wellhead with WLEG @ 11995'. RILDS - LD LJa - install TWC - MU LJb and test hanger seals to 5000 psi - LD LJb NID BOPE to top of annular preventer. R/U potato masher and break cap on annular for inspection NID BOPE, Change out junk sub on top drive. N/U tree and test tuing hanger adapter to 5000 psi/10 min. Test treet to 250/5000 psi 10 min.-OK. R/U lines and displacement manifold. Hold prejob meeting Printed: 10/8/2003 1 :29:29 PM C()h()qo~hillips ..Alpska (,):þè~~ti()r1~¡ Sumrnåry .~t!pørt· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ·.·Date· . From;.To C02-55 C02-55 ROT - DRILLING doyon1 @ppco.com Doyon 19 Hours Code: Sub Code· Start: 7/13/2003 Rig Release: 10/2/2003 Rig Number: Spud Date: 7/13/2003 End: 10/1/2003 Group: Phase 10/1/2003 13:00 - 15:30 15:30 - 22:00 2.50 CMPL TN NUND CMPL TN on displacement 6.50 CMPL TN FRZP CMPL TN Fill lines and test to 5000 psi. Pump 186 bbl 9.2 ppg brine down tubing @ 3 bpm. ICP=260 psi, FCP=160 psi. DS pumped 54 bbl diesel down tubing @ 3bpm 400 psi FCP. Drop packer setting ball @ 17:30 hrs. Retest lines to 5000 psi. Pump 101.2 bbl diesel wI DS and ball landed on seat in XN nipple. SI tubing and bullheaded 55 bbl diesel down 7" x 4-1/2" annulus. Pressured up on annulus to 4500 psi to set Baker Premier packers. Test tubing for 30 inutes @ 4500 psi-OK. Bled tubing to 700 psi and tested 7" x 4-1/2" annulus to 3500 psi for 30 minutes-OK. 2.00 CMPL TN NUND CMPL TN Blow down lines and RID. FMC set BPV and secured tree. RIG released @ 00:00 hours 10/2/03. 22:00 - 00:00 Printed: 10/8/2003 1 :29:29 PM ') CD2-55 Summary of Events ) 8- 29-03 PRE CMT SQUEEZE PERFS: LOGGED CORRELATION PASS FROM 12000-11500' W/GR-CCLMEMORY TOOLSTRING. PERFORATED 11883-11884' RKB WI l' X 4.5" HSD, PF 4621, 6 SPF, 60 DEG PHASING. WILL CONTINUE PROGRAM IN AM. PLAN TO SHOOT SECOND SET OF PERF'S I SET CEMENT RETAINER. [Cement-Poly Squeeze] 8- 30-03 PRE CMT SQUEEZE: PERFORATED UPPER CIRC HOLES AT 11755 MD-RKB. SET BAKER K-l 7" CEMENT RETAINER AT 11860' MD-RKB. [Cement-Poly Squeeze] 8-31-03 PERFORMED A CMT SQUEEZE WITH 15.8 PPG CLASS G CEMENT FROM 12,100' TO 11,300' CCTMD WITHIN THE 7" CASING. DISPLACED 6 BBLS OF 15.8 PPG CLASS G CEMENT BEHIND THE 7" BY 8.5" ANNULUS. DISPLACEMENT BETWEEN PERFORATIONS = 4.3 BBLS, THIS SHOWS A SQUEEZE OF 1.7 BBLS INTO THE FORMATION. LOADED WELL WITH 8.8 PPG BRINE FROM 11,300- 2,000' CCTMD. FREEZE PROTECTED TO 2,000' CCTMD WITH 6.8 PPG DIESEL. [Cement-Poly Squeeze] 9-6-03 PERFORMED A CEMENT MILLOUT FROM 11,030' TO 11,096' CTMD. 9- 7 -03 PERFORMED A CEMENT EXTRACTION BY MEANS OF AN EXTREME MOTOR ACCOMPANIED BY A 6 1/8" HC. PDC. BIT TO A DEPTH OF 11,837.6' CTMD. 9-8-03 ATTEMPT TO PT WELL. CAN PUMP INTO WELL AT 0.6 BPM AT 1800 PSI. SUSPECT TOP SQUEEZE PERFS ARE TAKING FLUID. REVERSE CIRCULATE OUT CEMENT FROM PREVIOUS MILL JOB. JOB IN PROGRESS, 9-9-03 REVERSE CIRCULATE OUT CEMENT RESIDUE WITH MULE SHOE COIL TO 11,819' CTMD ON MECHANICAL COUNTER, 11,803' CTMD ON ELECTRICAL COUNTER. TAGGED HARD AND COULD NOT GO DEEPER. ENCOUNTERED CHUNKS OF CEMENT DURING CLEANOUT. POOH LEAVING 8.8 PPG BRINE IN WELL WITH 2000' DIESEL CAP. ATTEMPTED TO PT WELL AGAIN, WAS ABLE TO PUMP INTO WELL AT 0.5 BPM AND 1900 PSI. SUSPECT TOP SQUEEZE PERFORATIONS ARE TAKING FLUID. [FCO] 9-18-03 PERFORMED A CEMENT MILLOUT FROM 11,000 CTMD TO RETAINER TOP @ 11,796' CTMD USING 6 1/8" CONCAVE MILL. MOTORED THROUGH TIGHT SPOTS AROUND 11,230, 11,278, 11,562, AND 11,764 CTMD. CONTINUED TO -) CD2-55 Summary of Events ) WORK MULTIPLE SWEEPS THROUGH 11,000 - 11,750 CTMD. ABLE TO PASS THROUGH TO RETAINER W/OUT PUMPING, 5 CLEAN RUNS. CHANGED MHA & INSTALLED NOZZLE FOR UPCOMING REVERSE CIRCULATE JOB. [Cement- Poly Squeeze] 9-19-03 REVERSE CIRCULATE OUT CEMENT FOLLOWING RECENT MILL JOB. CLEANED 7" CASING FROM 11,0000' TO 11,780' CTMD. RETURNS HAD SOME CEMENT FRAGMENTS AND RESIDUE. REVERSE CIRCULATE FROM 6,000 TO 11,780 CTMD (APPROXIMATELY 20' OFF RETAINER). JET BIOZAN FROM 11,000 TO 11,780' CTMD. FINAL REVERSE FROM 11,000' - 11,780'. POOH LEAVING 8.8 PPG BRINE WITH 2000' DIESEL CAP 9- 20-03 LOGGED SCMT FROM 11826' TO 11440' (USED WELL TEC TRACTOR TO GET DEEPER THAN 11250') -- GOOD CEMENT: 11725'-11732' & 11740'-11780', FAIR CEMENT WITH VOIDS: 11680'-11725'. 9-21-03 SET WEATHERFORD 7" WRP PLUG WITH MID ELEMENT AT 2000' COMPANY FIELD SITE WELL WELLPATH DEPTHUNT SURVDATE ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Final Survey CD2-55 CD2-55 ft 2003-1 0-08 - ------ -- --- -- - - - -.... --.......... --.. -. ---.. --.. --- -....... --- ----.. -- -- ----- WELL INFORMATION WELL EW MAP 371738.44 WELL NS MAP 5974244.05 DATUM ELEVN 52.40 VSECT ANGLE 151.90 VSECT NORTH 0.00 VSECT EAST 0.00 C AS I N G ---------------------------------------------------------------- SURVEY TYPE INFORMATION 87.00 - 267.00 CB-GYRO-SS 306.16 - 15201. MWD+IFR-AK-CAZ-SC -' -- -- --.. --- -- --- ---.. --........ --...... -- ---.. --.. -- --.. ---.. --.... --.. ---- -- --- SURVEY LIST MD INC AZI TVDS' TVD NS EW NSMAP EWMA DLS VSEC 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5974244.05 371738.44 0.00 0.00 87.00 0.35 303.00 34.60 87.00 0.08 -0.13 5974244.14 371738.31 0.69 -0.14 173.00 0.50 240.00 120.60 173.00 0.04 -0.67 5974244.10 371737.77 0.54 -0.35 267.00 2.25 21 0.00 214.57 266.97 -1.76 -1.95 5974242.32 371736.46 1.95 0.64 306.16 2.46 21 0.00 253.69 306.09 -3.16 -2.76 5974240.94 371735.63 0.54 1.49 394.82 3.81 207.25 342.22 394.62 -7.42 -5.06 5974236.71 371733.26 1.53 4.17 482.89 5.95 208.69 429.97 482.37 -14.03 -8.59 5974230.17 371729.61 2.43 8.33 575.78 8.75 216.79 522.09 574.49 -23.91 -15.13 5974220.40 371722.90 3.21 13.97 664.12 11.59 212.01 609.03 661.43 -36.82 -23.86 5974207.64 371713.95 3.35 21.24 753.33 12.20 212.48 696.32 748.72 -52.37 -33.67 5974192.26 371703.88 0.69 30.34 843.44 14.92 209.14 783.92 836.32 -70.54 -44.44 5974174.28 371692.80 3.14 41.30 932.94 18.38 205.65 869.65 922.05 -93.33 -56.16 5974151.70 371680.70 4.02 55.88 1028.27 22.67 208.11 958.91 1011.31 -123.10 -71.33 5974122.20 371665.02 4.59 74.99 1123.42 27.87 208.34 1044.93 1097.33 -158.87 -90.54 5974086.76 371645.20 5.47 97.50 c~ 1218.52 31.16 208.42 1127.67 1180.07 -200.09 -112.81 5974045.94 371622.24 3.46 123.37 1313.93 33.18 208.69 1208.43 1260.83 -244.70 -137.09 5974001.75 371597.19 2.12 151.29 1409.05 35.65 208.48 1286.90 1339.30 -291.91 -162.81 5973954.99 371570.68 2.60 180.81 1504.39 38.61 209.05 1362.90 1415.30 -342.34 -190.51 5973905.04 371542.12 3.13 212.26 1599.37 38.00 208.54 1437.43 1489.83 -393.94 -218.87 5973853.95 371512.88 0.72 244.41 1695.01 37.61 209.20 1513.00 1565.40 -445.28 -247.17 5973803.10 371483.71 0.59 276.37 1789.45 37.81 209.40 1587.71 1640.11 -495.65 -275.44 5973753.22 371454.58 0.25 307.49 1884.51 38.69 208.41 1662.36 1714.76 -547.17 -303.88 5973702.20 371425.27 1.13 339.54 1979.59 39.84 209.28 1735.98 1788.38 -599.88 -332.92 5973650.00 371395.34 1.34 372.36 2074.78 41.22 208.68 1808.33 1860.73 -653.99 -362.88 5973596.42 371364.45 1.51 405.98 2169.73 40.19 211.08 1880.31 1932.71 -707.68 -393.72 5973543.27 371332.71 1.97 438.82 2264.93 40.35 212.50 1952.95 2005.35 -759.98 -426.13 5973491.53 371299.41 0.98 469.69 ~. 2359.96 40.18 213.04 2025.46 2077.86 -811.63 -459.38 5973440.47 371265.29 0.41 499.59 2455.37 41.07 209.64 2097.89 2150.29 -864.68 -491.66 5973387.98 371232.10 2.50 531.17 2550.25 41.87 210.87 2168.98 2221.38 -918.94 -523.32 5973334.27 371199.52 1.20 564.13 2645.41 41.36 208.30 2240.13 2292.53 -973.89 -554.53 5973279.87 371167.38 1.87 597.91 2740.89 41.24 209.06 2311.86 2364.26 -1029.17 -584.77 5973225.11 371136.20 0.54 632.43 2768.76 41.06 209.87 2332.85 2385.25 -1045.14 -593.79 5973209.30 371126.91 2.02 642.27 2868.60 41.33 210.90 2407.97 2460.37 -1101.86 -627.05 5973153.16 371092.69 0.73 676.64 2964.10 41 .42 209.34 2479.64 2532.04 -1156.46 -658.72 5973099.12 371060.09 1.08 709.88 3059.43 41.38 209.96 2551.15 2603.55 -1211.25 -689.91 5973044.88 371027.97 0.43 743.52 3155.01 41.00 210.12 2623.07 2675.47 -1265.74 -721.42 5972990.94 370995.54 0.41 776.75 3250.79 40.70 210.39 2695.52 2747.92 -1319.85 -752.98 5972937.38 370963.05 0.36 809.61 3346.34 40.73 209.90 2767.95 2820.35 -1373.75 -784.28 5972884.03 370930.84 0.34 842.42 3441.35 41.27 210.28 2839.65 2892.05 -1427.68 -815.54 5972830.64 370898.67 0.63 875.27 3536.77 41.28 21 0.34 2911.37 2963.77 -1482.02 -847.30 5972776.85 370865.98 0.04 908.24 3632.24 40.99 210.41 2983.27 3035.67 -1536.21 -879.06 5972723.23 370833.31 0.31 941.08 3727.78 41.19 210.65 3055.28 3107.68 -1590.29 -910.96 5972669.70 370800.49 0.27 973.77 "-" 3823.27 41.28 209.77 3127.09 3179.49 -1644.69 -942.63 5972615.86 370767.90 0.61 1006.83 3918.66 40.42 207.49 3199.25 3251.65 -1699.44 -972.53 5972561.63 370737.07 1.80 1041.05 4014.58 39.60 205.89 3272.71 3325.11 -1754.53 -1000.23 5972507.03 370708.43 1.37 1076.60 4109.70 39.16 205.96 3346.24 3398.64 -1808.81 -1026.62 5972453.22 370681 .12 0.46 1112.05 4205.28 38.79 206.09 3420.54 3472.94 -1862.83 -1052.99 5972399.66 370653.82 0.40 1147.28 4300.80 38.53 206.39 3495.13 3547.53 -1916.35 -1079.38 5972346.60 370626.53 0.34 1182.06 4396.33 38.55 207.39 3569.85 3622.25 -1969.43 -1106.30 5972293.99 370598.71 0.65 1216.21 4492.09 38.17 207.69 3644.94 3697.34 -2022.13 -1133.77 5972241.77 370570.34 0.44 1249.75 4587.55 38.17 208.43 3719.99 3772.39 -2074.19 -1161.52 5972190.20 370541.71 0.48 1282.60 4683.29 40.42 212.99 3794.09 3846.49 -2126.25 -1192.52 5972138.68 370509.83 3.82 1313.94 4779.07 39.69 215.78 3867.41 3919.81 -2177.12 -1227.31 5972088.42 370474.17 2.02 1342.41 4874.52 39.92 216.55 3940.74 3993.14 -2226.45 -1263.37 5972039.72 370437.28 0.57 1368.95 4969.32 42.43 217.10 4012.09 4064.49 -2276.40 -1300.78 5971990.42 370399.02 2.68 1395.39 5064.62 45.08 217.73 4080.92 4133.32 -2328.73 -1340.83 5971938.78 370358.09 2.82 1422.69 5160.24 53.37 217.25 4143.32 4195.72 -2386.15 -1384.84 5971882.13 370313.10 8.68 1452.61 5256.08 57.86 216.03 4197.43 4249.83 -2449.61 -1432.01 5971819.49 370264.85 4.80 1486.37 5351 .1 0 60.24 215.24 4246.29 4298.69 -2515.84 -1479.48 5971754.09 370216.26 2.60 1522.43 5446.59 60.88 214.25 4293.23 4345.63 -2584.17 -1526.87 5971686.58 370167.71 1.12 1560.39 5541.76 61.73 213.28 4338.92 4391.32 -2653.57 -1573.27 5971617.99 370120.14 1.26 1599.76 5637.17 62.41 212.24 4383.61 4436.01 -2724.46 -1618.88 5971547.90 370073.33 1.20 1640.81 5732.65 63.04 210.91 4427.37 4479.77 -2796.76 -1663.31 5971476.38 370027.67 1.40 1683.65 ~ 5827.87 63.59 209.97 4470.13 4522.53 -2870.11 -1706.41 5971403.78 369983.33 1.05 1728.06 5923.50 63.39 209.45 4512.82 4565.22 -2944.43 -1748.83 5971330.20 369939.65 0.53 1773.65 6016.89 62.77 209.71 4555.10 4607.50 -3016.85 -1789.93 5971258.50 369897.32 0.71 1818.17 6114.34 62.13 210.26 4600.17 4652.57 -3091.69 -1833.11 5971184.42 369852.87 0.83 1863.84 6209.80 61.16 210.85 4645.51 4697.91 -3164.03 -1875.81 5971112.83 369808.94 1.15 1907.54 6305.28 60.42 211.12 4692.10 4744.50 -3235.47 -1918.72 5971042.13 369764.82 0.81 1950.36 6400.70 59.73 212.46 4739.71 4792.11 -3305.77 -1962.28 5970972.60 369720.07 1.42 1991.85 6496.46 59.87 212.72 4787.88 4840.28 -3375.50 -2006.86 5970903.65 369674.31 0.28 2032.36 6592.12 60.02 212.86 4835.79 4888.19 -3445.10 -2051.70 5970834.82 369628.29 0.20 2072.64 6687.26 60.24 213.06 4883.17 4935.57 -3514.32 -2096.58 5970766.38 369582.23 0.29 2112.56 6783.02 59.88 214.26 4930.96 4983.36 -3583.39 -2142.57 5970698.12 369535.07 1.15 2151.83 6878.42 59.59 215.13 4979.05 5031.45 -3651 .14 -2189.47 5970631.19 369487.02 0.84 2189.50 6974.10 59.78 215.06 5027.34 5079.74 -3718.72 -2236.96 5970564.44 369438.39 0.21 2226.75 7069.54 60.10 215.16 5075.15 5127.55 -3786.29 -2284.47 5970497.69 369389.73 0.35 2263.98 7164.99 59.81 215.31 5122.94 5175.34 -3853.78 -2332.14 5970431.04 369340.92 0.33 2301.06 7260.31 59.58 215.41 5171.04 5223.44 -3920.89 -2379.76 5970364.75 369292.16 0.26 2337.83 '-' 7356.33 59.10 215.77 5220.00 5272.40 -3988.06 -2427.83 5970298.42 369242.95 0.59 2374.44 7451.62 58.79 215.13 5269.16 5321.56 -4054.56 -2475.18 5970232.75 369194.48 0.66 2410.80 7547.15 58.99 215.63 5318.52 5370.92 -4121.25 -2522.53 5970166.89 369145.99 0.49 2447.32 7642.68 59.14 216.10 5367.63 5420.03 -4187.65 -2570.54 5970101.32 369096.86 0.45 2483.28 7738.17 59.43 216.76 5416.40 5468.80 -4253.70 -2619.29 5970036.12 369046.99 0.67 2518.59 7833.35 61.56 215.91 5463.27 5515.67 -4320.43 -2668.36 5969970.24 368996.79 2.37 2554.34 7929.15 61.50 215.63 5508.94 5561.34 -4388.76 -2717.59 5969902.77 368946.40 0.26 2591 .42 8022.73 61.57 215.31 5553.54 5605.94 -4455.76 -2765.33 5969836.60 368897.53 0.31 2628.04 8118.30 61.21 214.70 5599.31 5651.71 -4524.48 -2813.46 5969768.72 368848.24 0.68 2665.99 8215.13 60.95 212.22 5646.14 5698.54 -4595.18 -2860.18 5969698.83 368800.31 2.26 2706.35 8310.40 60.35 211.72 5692.83 5745.23 -4665.62 -2904.15 5969629.16 368755.15 0.78 2747.78 8405.85 59.88 212.59 5740.39 5792.79 -4735.69 -2948.20 5969559.86 368709.92 0.93 2788.84 8501.56 59.59 214.47 5788.63 5841.03 -4804.59 -2993.85 5969491.75 368663.09 1.72 2828.12 8596.91 59.50 215.43 5836.96 5889.36 -4871.96 -3040.94 5969425.21 368614.87 0.87 2865.37 8692.55 59.93 215.31 5885.20 5937.60 -4939.31 -3088.74 5969358.69 368565.92 0.46 2902.26 8787.98 60.22 214.34 5932.80 5985.20 -5007.20 -3135.97 5969291.62 368517.54 0.93 2939.91 8883.12 60.30 213.63 5980.00 6032.40 -5075.70 -3182.15 5969223.93 368470.20 0.65 2978.58 8979.25 60.51 213.76 6027.47 6079.87 -5145.24 -3228.52 5969155.20 368422.65 0.25 3018.09 9074.47 59.95 214.58 6074.75 6127.15 -5213.63 -3274.94 5969087.62 368375.07 0.95 3056.55 9170.43 59.40 214.08 6123.20 6175.60 -5282.03 -3321.66 5969020.03 368327.20 0.73 3094.88 9264.29 59.32 214.05 6171.04 6223.44 -5348.93 -3366.89 5968953.92 368280.83 0.09 3132.59 ~ 9361.39 60.24 214.66 6219.91 6272.31 -5418.19 -3414.24 5968885.48 368232.31 1.09 3171.39 9456.83 60.17 215.34 6267.34 6319.74 -5486.04 -3461.74 5968818.47 368183.65 0.62 3208.86 9552.60 60.14 216.06 6315.00 6367.40 -5553.50 -3510.22 5968751.85 368134.04 0.65 3245.53 9648.03 60.44 216.04 6362.29 6414.69 -5620.51 -3558.99 5968685.69 368084.12 0.31 3281.67 9743.51 60.54 215.66 6409.32 6461 .72 -5687.86 -3607.66 5968619.19 368034.32 0.36 3318.16 9839.02 60.28 215.59 6456.49 6508.89 -5755.37 -3656.04 5968552.52 367984.80 0.28 3354.93 9934.88 60.08 215.57 6504.16 6556.56 -5823.01 -3704.43 5968485.72 367935.26 0.21 3391.81 1 0030.44 60.14 215.58 6551.78 6604.18 -5890.40 -3752.63 5968419.18 367885.92 0.06 3428.55 10125.58 60.03 215.38 6599.22 6651.62 -5957.55 -3800.49 5968352.86 367836.92 0.22 3465.24 10221.41 60.30 214.39 6646.90 6699.30 -6025.74 -3848.03 5968285.50 367788.22 0.94 3503.00 10316.26 60.57 213.90 6693.70 6746.10 -6094.02 -3894.34 5968218.03 367740.76 0.53 3541 .42 1 0411 .33 60.16 213.87 6740.71 6793.11 -6162.62 -3940.41 5968150.23 367693.53 0.43 3580.23 10507.10 60.08 213.28 6788.42 6840.82 -6231.80 -3986.33 5968081.85 367646.43 0.54 3619.63 10602.28 64.00 208.42 6833.06 6885.46 -6303.96 -4029.36 5968010.44 367602.18 6.11 3663.02 10697.57 63.74 204.45 6875.04 6927.44 -6380.55 -4067.44 5967934.52 367562.80 3.75 3712.64 10793.14 63.25 202.60 6917.69 6970.09 -6458.96 -4101.57 5967856.71 367527.33 1.81 3765.73 ~ 10888.43 63.66 201.53 6960.28 7012.68 -6537.96 -4133.60 5967778.28 367493.96 1.09 3820.34 10984.36 65.62 199.93 7001.37 7053.77 -6619.03 -4164.27 5967697.75 367461.91 2.54 3877.40 11079.68 68.25 197.79 7038.71 7091.11 -6702.01 -4192.60 5967615.27 367432.17 3.45 3937.26 11172.86 70.89 194.55 7071.24 7123.64 -6785.86 -4216.89 5967531.86 367406.45 4.32 3999.79 11269.98 72.33 189.04 7101.90 7154.30 -6876.03 -4235.70 5967442.03 367386.10 5.58 4070.47 11365.29 72.72 184.57 7130.54 7182.94 -6966.28 -4246.46 5967351.99 367373.79 4.49 4145.01 11461.37 73.75 180.34 7158.26 7210.66 -7058.16 -4250.39 5967260.19 367368.29 4.35 4224.21 11557.01 76.05 175.61 7183.19 7235.59 -7150.41 -4247.11 5967167.91 367370.00 5.35 4307.13 11651 . 1 6 77.95 171.41 7204.37 7256.77 -7241.53 -4236.73 5967076.63 367378.82 4.79 4392.40 11748.39 79.83 167.15 7223.12 7275.52 -7335.24 -4218.98 5966982.64 367394.96 4.71 4483.42 11843.27 82.33 162.56 7237.84 7290.24 -7425.68 -4194.49 5966891.80 367417.90 5.46 4574.74 11938.71 83.32 157.65 7249.76 7302.16 -7514.69 -4162.27 5966802.26 367448.59 5.21 4668.43 12034.15 86.05 153.34 7258.61 7311.01 -7601.13 -4122.86 5966715.16 367486.51 5.33 4763.25 12129.38 87.10 151.23 7264.30 7316.70 -7685.28 -4078.65 5966630.28 367529.27 2.47 4858.30 12151.23 87.41 150.97 7265.34 7317.74 -7704.39 -4068.11 5966611.00 367539.49 1.85 4880.12 12256.94 86.60 150.42 7270.87 7323.27 -7796.44 -4016.44 5966518.08 367589.57 0.93 4985.66 12352.70 86.11 149.56 7276.95 7329.35 -7879.19 -3968.64 5966434.53 367635.94 1.03 5081.17 12448.17 85.43 150.65 7284.00 7336.40 -7961.73 -3921.19 5966351.19 367681.97 1.34 5176.33 12543.97 87.34 151.67 7290.04 7342.44 -8045.48 -3875.07 5966266.68 367726.64 2.26 5271.93 12638.63 87.16 151.47 7294.58 7346.98 -8128.63 -3830.06 5966182.78 367770.23 0.28 5366.48 12735.06 87.04 150.85 7299.46 7351.86 -8212.99 -3783.60 5966097.64 367815.23 0.65 5462.78 -" 12830.06 86.98 151.33 7304.41 7356.81 -8296.04 -3737.74 5966013.83 367859.66 0.51 5557.64 12924.93 88.76 150.92 7307.94 7360.34 -8379.05 -3691.96 5965930.05 367904.01 1.93 5652.43 13020.25 90.31 151.51 7308.71 7361.11 -8462.59 -3646.06 5965845.75 367948.47 1.74 5747.74 13116.25 90.99 150.15 7307.62 7360.02 -8546.40 -3599.28 5965761.15 367993.81 1.58 5843.71 13208.95 90.62 150.48 7306.32 7358.72 -8626.93 -3553.37 5965679.86 368038.32 0.53 5936.37 13306.45 90.37 150.14 7305.48 7357.88 -8711.63 -3505.08 5965594.35 368085.15 0.43 6033.82 13402.12 90.00 150.60 7305.17 7357.57 -8794.79 -3457.79 5965510.41 368131.02 0.62 6129.46 13497.59 89.69 150.68 7305.43 7357.83 -8877.99 -3410.98 5965426.42 368176.39 0.34 6224.91 13593.23 89.26 150.99 7306.30 7358.70 -8961.50 -3364.37 5965342.13 368221.56 0.55 6320.52 13688.68 89.01 151.34 7307.74 7360.14 -9045.11 -3318.34 5965257.75 368266.15 0.45 6415.96 13784.16 88.83 151.37 7309.54 7361.94 -9128.89 -3272.58 5965173.21 368310.47 0.19 6511 .41 13879.66 88.52 152.07 7311.75 7364.15 -9212.97 -3227.35 5965088.38 368354.25 0.80 6606.89 13975.35 88.09 152.42 7314.58 7366.98 -9297.61 -3182.80 5965002.99 368397.34 0.58 6702.53 14070.79 88.09 152.92 7317.76 7370.16 -9382.35 -3139.01 5964917.52 368439.67 0.52 6797.91 14166.47 87.96 152.80 7321.06 7373.46 -9467.44 -3095.39 5964831.70 368481.83 0.18 6893.52 14261.75 87.84 153.42 7324.55 7376.95 -9552.36 -3052.33 5964746.06 368523.43 0.66 6988.72 --' 14357.02 90.19 152.42 7326.19 7378.59 -9637.17 -3008.97 5964660.54 368565.33 2.68 7083.95 14452.55 91.54 151 .46 7324.75 7377.15 -9721 .46 -2964.04 5964575.50 368608.81 1.73 7179.46 14547.72 92.59 151.16 7321.32 7373.72 -9804.89 -2918.38 5964491.31 368653.03 1.15 7274.57 14643.53 92.22 151 .40 7317.30 7369.70 -9888.84 -2872.38 5964406.59 368697.58 0.46 7370.29 14738.46 93.09 151.32 7312.90 7365.30 -9972.06 -2826.93 5964322.61 368741.60 0.92 7465.11 14834.78 92.90 151 .43 7307.87 7360.27 -10056.50 -2780.85 5964237.41 368786.23 0.23 7561.29 14930.03 92.53 151 .99 7303.36 7355.76 -10140.27 -2735.75 5964152.87 368829.87 0.70 7656.44 15025.85 92.04 151.87 7299.54 7351.94 -10224.76 -2690.70 5964067.64 368873.47 0.53 7752.18 15119.81 91.67 151.96 7296.49 7348.89 -10307.61 -2646.49 5963984.05 368916.25 0.41 7846.09 15201.54 15238.00 92.96 92.96 152.04 7293.19 7345.59 -10379.71 -2608.15 5963911.31 368953.35 152.04 7291.31 7343.71 -10411.87 -2591.08 5963878.86 368969.87 1.58 7927.75 0.00 7964.16 ~ ~ Well: CD2·55 Date: 711512003 Possible Error dO _OJ --- \~ 0 ') Casing Detail 95/8" Surface CasinCl ~PHILLIPS Alaska, Inc. C) 0' 3 I 'd ~ A Subsidiary or PHILLIPS PETROLE~ OOfv1PANY c;;;{ ,"- 0' Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH Jts 3 to 66 Doyon 19 AKB to LDS FMC Gen V Hanger 64 Jts 9-5/8- 36# J·55 BTC Csg Weatherford Float Collar 2 Jts 9-5/8- 36# J-55 BTC Csg Ray Oil Tools - Silver Bullee Float Shoe 36.59 2.23 2670.00 1.50 84.11 2.19 Jts 1 to 2 9- 5/8- shoe @ TD 12 1/4- Surface Hole RUN TOTAL 38 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #3) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52,54,56,58,60,62,64 70 joints total in shed - 66 joints total to run Last 4 joints stay out, # 67 thru # 70. Use API Mod Best 0 Life Artie Grade Csg Compound. Remarks: Up Wt - 175K Ibs Dn Wt - 115K Ibs Block Wt 75K Ibs Supervisor: Don Mickey DEPTH TOPS 36.59 38.82 2708.82 2710.32 2794.43 2796.62 2810.00 '" ...0" 'J ') ,RonOC()Pt1iUi~SAI~ska ,:,~_Q'l~m"'~I¡:"~PÐrt Legal Well Name: C02-55 Common Well Name: C02-55 Event Name: ROT - DRILLING Primary Hole Size: 12.250 (in) TMD Set: 2,797 (ft) Date Set: 7/15/2003 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger .. , Rot Time Start: Rec Time Start:02: 15 Report #: Start: 1 7/13/2003 Spud Date: 7/13/2003 Report Date: 7/16/2003 End: 10/1/2003 : (;írnfÞnt ~øb,mY~::l:Þrlro4:1tY· Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: SO Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SO TMD: sa Date: Cmtd. Csg: Cementer: Jim Thompson Cmtd. Csg: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: ,.. .. Pipe 'Movement Pipe Movement: Reciprocating Time End: Time End: 05:20 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 165,000 (Ibs) Drag Down: 135,000 (Ibs) Type: Cement Casing Volume Excess %: 3.00 Meas. From: 0 Time Circ Prior To Cementing: 1.50 Mud Circ Rate: 273 (gpm) Mud Circ Press: 290 (psi) . : ;støge .,NQ: 1. :.9f.,~i' ,.... Start Mix Cmt: 04:13 Start Slurry Displ: 04:14 Start Displ: 05:12 End Pumping: 05:47 End Pump Date: 7/16/2003 Top Plug: Y Bottom Plug: Y . :' .. . . Type: Spud Mud Density: 9.6 (ppg) Visc: 44 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud ." ,,' Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.00 (bbl/min) 7.00 (bbl/min) y 490 (psi) 1 ,230 (psi) 10 (min) Y I: . . , Retums: 100 Total Mud Lost: Cmt Vol to Surf: ~---- I) , (bbl) · Ann Flow After: N Mixing Method: Density Meas By: densometer . . . . ." . ;¡··r'·: '/..' . <M~·~,'Dä_~··.· .,'. . .. ......;"~¡~\~~~~~~'; ~~I(i~.·~i:;r~ti. PV/yP: 15 (cp)/13 (lb/100ft2) Gels 10 sec: 4 (lb/100ft2) Gels 10 mln: 8 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 189.00 (bbl) . , Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: Biozan water w/ nut plug Class: Cmt Vol: 40.0 (bbl) Density: 803.00 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: 40.0 (bbl) Other Vol: () Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: Flush Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 11f712003 11 :04:29 AM ') Conoc.OPhilliþs·Alaska :Oe~;_~ti:~Ø¡':·il~RØ.rt'·· Legal Well Name: C02-55 Common Well Name: C02-55 Event Name: ROT - DRILLING Report #: Start: 1 7/13/2003 Slurry Data Fluid Type: Spacer Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: eF) ') Page20f 3, Spud Date: 7/13/2003 Report Date: 7/16/2003 End: 10/1/2003 ~t~ge'N,9:1..SlurrYiN():2Øf ~.. '.,. Description: MUDPUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: . '" . . Stage No:·1.Slurry·No:.3,·of 4: Slurry Data Fluid Type: LEAD Slurry Interval: 2,297.00 (ft}ro: 36.59 (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) ~.:,¡.~,:,;.'.,,',j,.:...,.,:.;.:..'.·.'.l:~,·.~::. '.',:':. '..,:,...~ .,:,:.. ·.i';':'ti¡ ,J\ ' ',. . :.' ,- >:·::;,TrådEJ:Nâtné.";:·: :': ' D-53 D-46 D-79 S1 D-124 D-44 D-65 Class: Density: 10.70 (ppg) Yield: 4.28 (ft3/sk) Water Vol: 376.0 (bbl) Other Vol: () Temperature: eF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Temp (OF) (OF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) . ,': ·,.<~lB·~k.';~U:'~,~;;:&6~1;~~1 ", '. ',.<' .'>"', ..~ ".:' :. .,. '~,,' . . '" .' : r '-:', ·l·' ": . ".,;; :' -', ....: " '.- . ·,:<St~g·e:¡Nø(1';$lurry :Nbf$ø(4'!Ò': AdCUJJV"$".::" ".,",'. : :'~',:>,",~ <.~":., ";,"":,I?"¡ ~'-:">" "", : :",": ::':, " ",:;"" ,::)(', ,'<',' ::, . :':': ~> "".,>:}"':::'",: : :..~:',::' -:' ~:L , :'.::: ,~,,:·:::t~Þè:.\'·'; : ·;;Öbnëé~t~âtiôn::·.: ; ;:~.:' ':.:::::Unít~:·:: GYPSUM 30.0C % DEFOAMER 0.6C % EXTENDER 1.5C % ACCELERATOR 1.50 % FILLlTE 43.1C % ACCELERATOR 9.0C %BWOW DISPERSANT 0.5C % , ,. ""J" I' :... / stå~e J·~O:,~·. $IUrry ;No: ··4:01· .{ ".. Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,797.00 (ft}ro: 2,297.00 (ft) Cmt vo~: .~bbl) Water Source: Slurry Vz:;'¿ (sk) Class:~~ Yield: .16. (ft3/sk Other 01: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Density: 15.80 (ppg) Water Vol:28.0 (bbl) Temperature: eF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Printed: 11/7/2003 11 :04:29 AM ) ) .?onoc()Phi11ips :~Ia~~~ .·i~·~;~:'.~·~i:~·Ø;.:,:~IÂ~~··· Legal Well Name: C02-55 Common Well Name: C02-55 Event Name: ROT - DRILLING Report #: Start: 1 7/13/2003 Spud Date: 7/13/2003 Report Date: 7/16/2003 End: 10/1/2003 . -.. ' '. '" "':'," ...".... ,""', . :,'" ,'.",,',", ".".. " ,.",..,.,,,, . . , ,,'" ":..... ',... .",' ,-... , . ... . .' .. .... """ , , .. "., ." ." StageNô: 1SlurrÿNo: 4ôf4~ Acldïtlves Trade Name Type DEFOAMER DISPERSANT ACCELERATOR Concentration 0.2C% 0.3C% 2.0C% Units . Liquid Conc. Units 0-46 0-65 S1 Casing Test Shoe Test Liner rop T~st Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N .. . ! ',," ."',' .' .. "·~~g(~urV~Ýl:valliatiqi1·... . .' .", . . .... , " . . . .1i1t~rþretåtlo~ ~.t.irr'~arY.· . CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: . ,:' . ',t' ;;:.R~~~.{, ,.",," ::, ~ ~.....;. . '. " : :.~~., >:,1.,,' ~ ~:,,,-:..f i "..;... : Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water wI nut plug - Pump 5 bbls water fl Dowell- Test lines to 2500 psi - Drop btm plug - Mix & pump 50 bbls Mud Push XL @ 10.5 ppg @ 5.5 bbls/min @ 250 psi - Mix & pump lead slurry ASL @ 10.7 ppg @ 7 bbls/min @ 270 psi - Observed nut plug @ shakers wI 284 bbls lead slurry pumped - finished pumping down surge can - pumped 306 bbls lead slurry - switched to tail slurry - mixed & pumped tail slurry Class G wI D-46 0.20 %, 065 0.30%, S001 2%, @ 15.8 ppg @ 5.4 bbls/min @ 230 psi - pumped 43.7 bbls tail slurry - Dropped top plug wI 20 bbls water fl Dowell- switched to rig pumps & displaced cement wI 189 bbls 9.6 ppg mud @ 7 bbls/min @ 250 to 490 psi - slowing pumps to 3.5 bbls/min for last 17 bbls of displacement- bumped plug wI 1230 psi - check floats - floats held - CIP @ 0545 hrs. Full circulation through job observed spacer @ shakers but no cement returns to surface - Notified AOGCC Jeff Jones & Drilling engineer about top job Printed: 11/7/2003 ":04:29 AM 24 HR FORECAST Clean shoe track - FIT- Drill 8 1/2" hole UTHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 7/15/2003 2,768.76 41.060 209.870 9.625 (in) @ 2,797.0 (ft) ·':DE~~ITv(P.~~) I 9.60 I pp I ECDl9.60 IMUD DArA.I· DAILY COST I .FV·· PV/VP GELS WL/HTHP FCIT.SOL OILIWAT %SandIMBT· .flh/pM 46 15/13 4/8 14.01 11 I 0.2/20.0 8.31 '·OPERATION·SSo.MMARY . ., .:.<.... . .. F,:RQ",. "TO ", . HOURS· . CODE· . TR'O.UBIlE .. sua:· . : PHÄSE . . ,: .. DESC~~PTI.Ç)N .... . .. \ 00:00 01 :45 1.75 CASE P RUNC SURFAC Continue running 95/8" 36# J-55 BTC casing fl 1375' as follows: ran 33 jts to 2757.8' (66 jts. total) - PU FMC hanger & landing jt. -land casing on landing ring wI fluted mandrel hanger wI shoe @ 2796.62' & FC @ 2708.82' OTHR SURFAC LD fill up tool & MU cement head & lines CIRC SURFAC Stage pumps up slow - Circulate hole clean & condition mud for cement job - 6.5 bbl/min @ 300 psi - reciprocating pipe - Held PJSM PUMP SURFAC Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water wI nut plug - Pump 5 bbls water fl Dowell - Test lines to 2500 psi - Drop btm plug - Mix & pump 50 bbls Mud Push XL @ 10.5 ppg @ 5.5 bbls/min @ 250 psi - Mix & pump lead slurry ASL @ 10.7 ppg @ 7 bbls/min @ 270 psi - Observed nut plug @ shakers wI 284 bbls lead slurry pumped - finished pumping down surge can - pumped 306 bbls lead slurry - switched to tail slurry - mixed & pumped tail slurry Class G wI D-46 0.20 %, D65 0.30%, S001 2%, @ 15.8 ppg @ 5.4 bbls/min @ 230 psi - pumped 43.7 bbls tail slurry - Dropped top plug w/ 20 bbls water fl Dowell - switched to rig pumps & displaced cement wI 189 bbl - 9.6 ppg mud @ 7 bbls/min @ 250 to 490 psi - slowing pumps to 3.5 bbls/mir for last 17 bbls of displacement - bumped plug w/1230 psi - check floats - floats held - CIP @ 0545 hrs. Full circulation through job observed spacer @ shakers but no cement retums to surface - Notified AOGCC Jeff Jones & Drilling engineer about top job OTHR SURFAC Pressure test 9 5/8" casing to 2500 psi for 30 mins. OTHR SURFAC RD cement lines & head - LD landing jt - long bails & casing elevators NUND SURFAC PJSM - ND flow line, turn buckles, riser, mouse hole & service lines - Remove Slip lock starting head TOPJ SURFAC Cut slot in conductor - MU & run 1 11/16" Hydril pipe to 142' - unable to get deeper - pulled back to 128' - observed cement on pipe @ 20' below bottom of conductor - rig up cement line - pump water to establish circulation - pumped 12 bbls ASL w/ good cement returns to cellar - Pull out 1 11/16" pipe - flush lines & RD OTHR SURFAC Weld up slot in conductor - change saver sub on TD - Change pump liners to 51/2" NUNO SURFAC NU FMC Unihead - test seals to 1000 psi - ok NUNO SURFAC NU BOPE BOPE SURFAC Set test plug - RU to test BOPE - Test BOPE - pipe rams, blind rams, choke & kill line valves, choke manifold valves, TD IBOP's, floor dart & TIW valves to WELL NAME SUPERVISOR Don Mickey CURRENT STATUS C02-55 I RIG NAME & NO. doyon 1 @ ppcO.co Slip & cut drill line 01:45 02:15 02:15 03:45 0.50 1.50 CASE P CEMENT P 03:45 06:00 2.25 CEMENT P 06:00 06:30 0.50 CEMENT P 06:30 07:30 1.00 CEMENT P 07:30 08:45 1.25 WELCTL P 08:45 12:00 3.25 CEMENT T DH 12:00 13:30 1.50 DRILL P 13:30 14:30 1.00 WELCTL P 14:30 16:00 1.50 WELCTL P 16:00 20:30 4.50 WELCTL P ) ') OOl1ocOPhunps,AlaSka Dally Drilling Report . Page1øf.2 I JOB NUMBER I EVE~Dc~DE 124 HRS PROG Doyon 19 TMD I TVD I DFS 2,810.0 2,416.0 3.00 I FIELD NAME /OCS NO. AUTH MD I DAILY TANG Alpine 17,618.0 0 ACCIDENTS LAST 24 HRS. ? DAILY INT w/o MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 7/14/2003 412,411 LEAKOFF AFE 10029728 I NEXT CASING 7.000 (in) @ 12,186.0 (ft) o I· CUM (:()ST I PfIMf CI Ca H2S 0.01/0 60 o LIME . ES I REPT NO. I DATE 4 7/16/2003 ICUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 746,380 AUTH. LAST BOP PRES TEST 7/16/2003 Printed: 11 rT/2003 11 :04:43 AM ) C02-55 , . ,'.: ':"" .' "" ,',; , .".,. ,,, ".. ", '"''''',''''' ." :'. ,', :': ,.. '."; " .,,' ·ê~n~c~Phll¡ip8,:Älåskå .. .' Dally'Dr.i~Ung J~~e·pon JOBNUMBER IEVE~DC~DE 24HRSPROG IT~~810.0 'Pê1.Qe: :2i;qf:?· WELL NAME ITVD DFS 2,416.0 3.00 IREPT N40. DATE 7/16/2003 FROM . ·TO HOURS CODE TROUBLE SUB 16:00 20:30 4.50 WELCTL P BOPE 20:30 00:00 3.50 DRILL P PULD OPERATION·S SUMMARY PHASE DESCRIPTION SURFAC 250 psi & 5000 psi - Hydrll to 250 & 3500 psi - performed accumulator closure test - RO test euqipment . Pull test plug - set wear bushing - Witnessing of test waived by Jeff Jones AOGCC SURFAC PU & RIH 87 jts.(29 stds) 4· drill pipe fl shed (for 8 1/2· hole section) - Pull & std back In derrick 24 HR SUMMARY: Run & cmt. casing - perform top job - NU & test BOPE· PU 4· drilll pipe . :,:PERSONNEL·DATA:' , , ..·CO~PANY ConocoPhillips Company Doyon Drilling Inc ACI - Arctic Catering Halliburton - Sperry-Sun Halliburton - Sperry-Sun Si:RVICE' . ~O..: 1 26 5 2 2 ~OUR$. ·CO~pANY M-I Drilling Fluids Swaco Dowell FMC Corporation Well he . . S~RVICE . 'NO.· ., . HOUI={~. .. 3 4 2 1 .UNrn;..·< . gals bbls '::JVïÄTERIÄLsJCONSUMPTION... . ·::.~SA~E'::'·: ,:::< ·d..NH~Nb;>;::>::::·. .:.,;>~",:!",: . . . 888 -2,808 Water, Potable 1 ,475 -3,765 :^iJ~~:~~~~~~?~~~~:!~~~~~n~TA 2025 3.8 1500 ... . . T. . + , I ~.. ~ :.' ," .; . . . Fuel Water, Drilling ·,:.:UNrrs: .. bbls : OSÄ~E: 120 .... ;O~.H~þ:::Y::· -340 . .1,1-' ,,", '. . .,: < ~.«';.'I~. ¡~~,'~:;;/?:; ~,~:, ~·;:~t~:.:;¡rf~~~¡ ,. :,':COMitËNtš::,/:',:y';V':,": >: .! " ~""., I '", " .,"." " )t-.~~::<'ë\:"~~E:"Vg'"R:~ÄME . C02-41 ¡ . ,~ C02-55 Printed: 1117/2003 11 :04:43 AM Well Name: Drilling Supervisor: C02-55 I Rig: Don Mickey ,PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 7/17/2003 pump used: I #1 Mud Pump I. ... Pumping down annulus and DP. I· Casing Shoe Depth 2,797 Ft-MD 2,407 Ft-TVD 19-5/8" 36#/Ft J-55 BTC Hole Depth 2,830 Ft-MD 2,432 Ft-TVD 1·1 9.6 ppg 12.0 Lb/100 Ft2 2,500 psi 75,000 Lbs 75,000 Lbs 2 bbls Pressure IntearitvT est Mud Weight: 9.6 ppg Mud 10 min Gel: 12.0 Lb/100 Ft2 Rotating Weight: 125,000 Lbs Blocksffop Drive Weight: 75,000 Lbs Desired PIT EMW: 16.0 ppg Estimates for Test: 801 psi 0.6 bbls I· 1·1 = Leak-off Pressure + Mud Weight = 770 j 0.052 x TVD 0.052 x 2407 + 9.6 EMW at 2797 Ft-MD (2407 Ft-TVD) = 15.8 ppg EMW 3000 . 2500· 2000 . W ex: ::> tJ) 1500 . tJ) w ex: c.. 1000 . PIT 15 Second Shut-In Pressure, psi 780 / ,/ / - Lost 10 psi during test, held = 99.6% of test pressure. 4~i4ct~4:~1~1;-.1 1-~~: 500· o~~ o ~CASING TEST Comments: ::::::;. .:::;:::*:~::::;:;:;:::::::::::::~:::::~:: 2 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point 3 Barrels ___LEAK-OFF TEST Tested casing after bumping plug and checking floats on cement job I Volume Input ... BarTels ~ 0.0836 Bbls/Strk ~ Pressure integrity Test Casing Test Shut-in Min psi o 2500 1 2500 2 2500 3 2500 4 2500 5 2500 6 2500 7 2500 8 2500 9 2500 10 2500 15 2500 20 2490 25 2490 30 2490 Volume Bled Back 2.3 Bbls Pumping Bbls psi o 0 0.084 30 0.167 40 0.251 60 0.334 90 0.418 140 0.502 240 0.585 310 0.669 370 0.752 430 0.836 500 0.92 580 1.003 650 1.087 720 1.17 770 1.254 800 ~ f~~ }~~ ~, ~r :~~' \:\~ ,\ ~ J J\~, '~~ ~,:\~.:~:~~~ ~'~~~I ~¡.j,I.\, I ~" "I, ~:¡r¡.<' ,~~ it \{~<'*",~\\ ~n'\"~ Iii', ., (, ~~ ,I. *1~\I~ ,i! ~~II ,\~~V ~~~~~ ~~,~~,~,..~~ ~,~ ,"~ ~~\. ~'*'. ~ ~ \ a\ I ¡I~ 'it~;'h~J~~ì \ ; :~~F~~"M,~ ~~\~\ ~I "- .,' all, ,(i!>.. ",-,I , "~o 'b~:\. \ ..\ ,'~. L¡e "LÇ;C'~~~\}q t:\ :r 9~~~ ~J:m~, L~ t\ t~~~~ '. ,~I..; ~.ê;,\~ ~~~ :Y~:'\~.h~ :~~~r ì~L.\3 ~~~~~:~4; ~¡ ¡.¡i!:¡;, ~ I~'.l,';; ~ ~' ~'.,'ô]"i!: ~~~ \~~1~~ ~T~' "" _, 'r-.~ 1~li is!.'~ .~. a." .'.""' ~ D. " "." ~ ~..~ .~~~ 0' :è:'I ¡ 'N, t~D,a" , ' ! ~q ~ ~ ,~'-.!. ~~, ~ ~~ ~ ~~ìa ~~~ F, ~ II ~' ~(,(~~.~\::~~ ~~"'<I~ Volume Pumped 1.3 Bbls Pump Rate: 0.5 Bbl/min ... Type of Test: Casing Shoe Test LOT/AT Hole Size: 18-1/2" RKB-CHF: 36.6 Ft Casin~ Size and Description: Casina Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: BlocksfTop Drive Weight: Estimates for Test: Shut-in Min psi o 800 0.25 780 0.5 750 1 720 1.5 715 2 )() 2.5 ..-Æõ 3 690 3.5 680 4 680 4.5 670 5 670 5.5 665 6 660 6.5 660 7 655 7.5 650 8 650 8.5 650 9 650 9.5 645 10 'S ~~ Volume Bled Back 1.0 Bbls ') ) Casing Detail 7" Intermediate Casina ConocoPhillips Alaska, Inc. Jt Number Num of Jts Jts 3 to 294 Jts 1 to 2 Remarks: 292 Jts 2 Jts Up Wt = 450+k COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKS to LDS FMC 11· X 7· Hanger 7· 26# L-80 STCM Csg 7· Weatherford Float Collar 7· 26# L-80 STCM Csg 7· Ray Oil Tools Float Shoe 7· shoe @ 8-1/2· TD straight blade centralizer one per jt on jts # 1-35 Straight blade centralizer one per jt on jts. # 226,227,228 straight blade centalizers on jts 230,232,234,236,238,240,242,244,2 248,250,252,254,256,258,260,262,264,266,268,270,272,27 4,276,278 280,282,284,286,288,290,292 Total Centralizers: 70 300 joints in pipe shed - 294 total jts. to run / last 6 joints stay out Use Best-o-Life 2000 pipe dope On Wt =11 Ok Block Wt= 75K ().o ~ -\\ c¿ Well: CD2·55 Date: 7/21/2003 LENGTH 34.60 1.59 12087.68 1.31 82.89 2.12 DEPTH TOPS 34.60 36.19 12123.87 12125.18 12208.07 12210.19 12220.00 Supervisor: Don Mickey/Dave Burley ) :Gon(i)coRhillips Ala~ka , ' , , . . ' . ' .. ' . " , .,."" . . :Ø"mClJ1~i:nø :'Rep.ørt Legal Well Name: C02-55 Common Well Name: C02-55 Event Name: ROT - DRILLING Primary Hole Size: 8.500 (in) TMD Set: 12,210 (ft) Date Set: 7/25/2003 Csg Type: Intermediate Casing/Li Csg Size: 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger . , Rot Time Start: Rec Time Start: : Time End: Time End: Type: Cement Casing Volume Excess %: 50.00 Meas. From: Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 63 (gpm) Mud Circ Press: 300 (psi) Report #: Start: 2 7/13/2003 ) Page1of3, Spud Date: 7/13/2003 Report Date: 7/25/2003 End: 10/1/2003 ·:Cørnent:.JOb'Type:· Primary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Ceménter: Jim Thompson Cmtd. Csg: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: . . ~ ~., , I. u ..' Pipe Movement Pipe Movement: No movement RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) ': S,tage. N9: 1· .of 1 :. ,. . . Start Mix Cmt: 22:25 Start Slurry Displ: 22:27 Start Displ: 22:40 End Pumping: 00: 1 0 End Pump Date: 7/25/2003 Top Plug: Y Bottom Plug: Y . . .,. Max Torque: (ft-Ibf) Drag Down: (Ibs) Retums: 0 Total Mud Lost: Cmt Vol to Surf: 650.00 (bbl) (bbl) Disp Avg Rate: Dlsp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.00 (bbl/min) 7.00 (bbl/min) Y 920 (psi) 1,410 (psi) 3 (min) Y Ann Flow After: N Mixing Method: recirculat Density Meas By: densometer .c~4~}~,····. Time Compressive Strength 1: Compressive Strength 2: Type: Non-Disp. LS Density: 9.8 (ppg) Visc: 47 (s/qt) PV/yP: 8 (cp)/16 (lb/100ft2) Gels 10 sec: 8 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Circulating Temperature: (QF) Bottom Hole Static Temperature: (OF) Displacement Fluid Type:Brine Density: 8.8 (ppg) Volume: 458.20 (bbl) "'"i ~'t~ I ".. . ", <~~J~'!\::~\··':';'f:t>";':.. .:: ":~:: '.~'~r,~ )'\1<:'í';'-' ,.~,.;~~':\{<;:'.:.,~.~J,:,;,:~:;:~',:,^:,';:;:,:~":~,,::,,,':,:',.';,.,;;, ,",'~"..' Stage ·'0· '1 ~Iurty N" 1 of 2 ~ ~ "-:"": . .. ' ,-- I)' ',~L-·' :.~ :~'" ~:)'" .' .> ;-.;'; " , '-. .'.. '.:...::~~!".:..,,~.~" .' . .t·,~ I.~....".'.~.:'. }.::"~:':.".""'.' \ ' Description: MUDPUSH XL Class: Cmt Vol: 52.0 (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Printed: 11/7/2003 11 :06:56 AM ') ) ··.·..~~rO~()~?i.UiPs...Alaska Q;'~:'Ifì~~!F1'gRepør:t . Page·2·of3· Legal Well Name: CD2-55 Common Well Name: CD2-55 Event Name: ROT - DRILLING Report #: Start: 2 7/13/2003 Spud Date: 7/13/2003 Report Date: 7/25/2003 End: 10/1/2003 I,' . ,,' ",' SJ.Øø·N9: 1 <Slljrry', No: 2 ot2 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 12,210.00 (fI}o: 10,707.00 (ftJ)mt Vol: 53.0 (bbl) Water Source: Lake Slurry Vol263 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (frIsk) Water Vol: 32.0 (bbl) Other Vol: () Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid loss: (cc) Fluid loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) ... . u ... . . . .. Stage No·: 1· Slurr)iNo:. 20f2 .. Additive$ . ':,., , Trade. Name .. ~YPe· DEFOAMER DISPERSANT conoentration uriits 0.2C % 0.25% 0.4C % 0.02% 0.25 2.0C %BWOC . . ·liquldConc. . . ~. Units D-46 D-65 D167 XE920 D029 D029 LCM LCM .'::.:~ :'~ f':':~~i;:~ ,'~:::. >¡ :.1-:' . ; ;~.::~ :,~ .'! ,.... ~:::;:·Q~$;lijgte$f~·;· " . '.' ·r' .. ,. ; ::: ~i"ertöp '-res,t .:.... ""!' : .. ,~ :.Shoe ·iéšf"': . . Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N ';::¡Jt~!~ê~~~r~~a~I~::'~{!,~;;:",!i';"'i:m¡;'(',~~I~ Tool: N Tool: N f~Q~r'Í1¡·: ·':):¡~:r;:t:-:·:·:i~:;;:'::,,~;·:~:.;:;:~:;;·:·:t.t~'~':\:;; ~::::;'!;:::i::~fÞXi~;, ~'('!/..;':<~:': :::<,":1: ~:;::.. ::;,) /;'.~.~:ij:f.~:~¢{:;F\:>·~.·t~,·:,/.::::: ,..'$'".",.<-:. :Lø9!SuiVeyEv.äluation '.~, '. .. ,. .. .~..... . ".. . ....·.·",·c,··.··..· . ,'. j2~\J.a\:~:t:!\: ".:::} ,< \ L'~/<.;:'" - ,)J:~~: ~ ',:': .- ~ "//.;:.'; :':~...:.: . ~'':'~ ,:,:,- {."-::',: :-.\",\-., ". -:':.. ~,"',; "'~.:'" :' ,:. ,~'" :-'"; ~__~:~_ ". ~:': ";. :...~..:.: /' .~~ ;'~ ; :,~ ~: CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: .. Remarks Pumped 150 bbls of mud w/4 ppb Mix II fine @ 1.S -3.0 bpm 1300-380 psi attempting to establish circ, no returns. Pumped 40 bbls pill with 10 ppb Mix II fine I G seal, no returns - total 190 bbls of mud losses. Unable to reciprocate pipe @ 400K - annulus remained full . throughout. PJSM. Cement 7" casing as follows: Pumped 3 bbls of fresh water and tested lines to 3500 psi. Mixed and pumped 52 bbls of Mud Push XL @ 12.5 ppg - Dropped bottom plug - Mixed and pumped 53 bbls of cement slurry (Class G wI 0.2% D046, 0.25% D06S, 0.02% EX920, 0.4% Printed: 111712003 11 :06:56 AM ) ) ·¡,~:onoGøPHil.lipsAlfîS~~. , Cementing Report . Legal Well Name: CD2-55 Common Well Name: CD2-55 Event Name: ROT - DRILLING Report #: Start: 2 7/13/2003 Spud Date: 7/13/2003 Report Date: 7/25/2003 End: 10/1/2003 D167, 0.25 Ib/sx 0029, 2.0 ppb 0095) @ 15.8 ppg - 4.5 bbls/min 225 psi - Dropped top plug - pumped 20 bbls FW from Dowell - switched to rig pumps and displaced with 8.8 ppg brine - 5 bpm 200 - 660 psi first 343 bbls pumped - increased rate to 7 bpm with spacer at shoe - 374 bbls of brine displaced at midnight (calc to bump 444 bbls). Continue displacing cement w 8.8 ppg brine @ 7 bbls/min. I 830 - 1160 psi - Reduced rate to 3.5 bpm last 10 bbls final pressure 920 psi -bumped plug to 1400 psi - total displacement 458.2 bbls (Used 95% pump output .0836 bbls/stk - calc disp. 463.9 bbls) CIP @ 0010 hrs. Check floats - did not hold. Bumped plug to 1400 psi ( 4.2 bbls pumped) line up to cement unit - check floats, bled back 2 bbls, floats held. Printed: 11 m2003 11 :06:56 AM ConocoPhllUps. Alaska Dally DriUlng Report TMD I TVD I DFS 12,220.0 7,321.0 11.00 I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Doyon 19 Alpine 17,618.0 0 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD Testing BOPE. 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Test BOPE, PU 4" drill pipe - Run bond log or 61/8" assy. 7/14/2003 287,235 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 15.92 10029728 INC AZIM I LAST CASING I NEXT CASING 87.410 150.970 7.000 (in) @ 12,210.0 (ft) 4.500 (in) @ 11,100.0 (ft) I PP I IECDI IMUD DATAl DAILY COST I 0 I CUM COST I WUHTHP FCIT.SOL OIUWAT %SandlMBT Ph/pM PflMf CI .Ca "2$ 5.2/11.4 1 I I 0.2/15.0 9.01 0.1010 40 WELL NAME ) ) P~g(;)t of2 I JOB NUMBER I EVE~DC~DE 124 HRS PROG CD2·55 SUPERVISOR I RIG NAME & NO. Don MickeylDave Burley doyon1 @ppco.co CURRENT STATUS LAST SURVEY: DATE TMD 7/21/2003 12,151.23 DENSITY(ppg) I 9.80 FV PV!YP GELS 47 8/21 11/13 FROM TO 00:00 02:45 02:45 04:00 04:00 08:00 08:00 08:30 08:30 19:30 11.00 19:30 20:00 0.50 20:00 22:00 2.00 22:00 00:00 2.00 HOURS 2.75 1.25 4.00 0.50 CODe CASE P CASE P CASE P CASE P CASE P CASE P CEMENT P CEMENT P TROUBLE SUB RUNC CIRC RUNC CIRC RUNC OTHR CIRC PUMP I REPT NO. I DATE 12 7/24/2003 ICUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 2,076,383 AUTH. LAST BOP PRES TEST 7/16/2003 o UME 1;$ OPERATIONS SUMMARY PHASE INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 DESCRIPTION Run casing from 4572' to 7054' (170 jts total) PUW 245K SOW 145K Circ and cond mud - initial rate 2.9 bpm I 480 psi, final rate 4.5 bpm 1 400 psi. Maintained mud wt. in @ 9.8 ppg, mud wt. out 10.0 . 10.2 ppg. Circ untill 9.9 ppg mud wt. out· total pumped 269 bbls with full returns. PU wt. 245 SO wt. 145 Continue running 7" fl 7054' to 10,354' (250 jts. total) Establish circulation· 4 bblsl min @ 620 psi - lost reutrns after pumping for 10 mins. PU wt. 325 SO wt 160 - continue pumping & attempting to regain returns - lost approx. 120 bbls - fluid level in annulus staying just below flow line Continue runnng 7" casing fl 10,354' to 11550' (279 jts. total) String began excess down drag @ 11565' (15' in on jt # 280) worked casing down fl 11,565' to 12,174' (294 jts. total ran) PU hanger & landing jt.- land 7" casing on FMC fluted mandrel hanger in wellhead wi shoe @ 12,210' & FC @ 12,124' LD fill up tool - MU cement head and lines. Pumped 150 bbls of mud wi 4 ppb Mix II fine @ 1.5 -3.0 bpm 1300-380 psi attempting to establish circ, no returns. Pumped 40 bbls pill with 10 ppb Mix II fine I G seal, no returns - total 190 bbls of mud losses. Unable to reciprocate pipe @ 400K - annulus remained full throughout. PJSM. Cement 7" casing as follows: Pumped 3 bbls of fresh water and tested lines to 3500 psi. Mixed and pumped 52 bbls of Mud Push XL @ 12.5 ppg - Dropped bottom plug - Mixed and pumped 53 bbls of cement slurry (Class G wI 0.2% D046, 0.25% D065, 0.02% EX920, 0.4% D167, 0.25lb/sx D029, 2.0 ppb D095) @ 15.8 ppg - 4.5 bbls/min 225 psi· Dropped top plug - pumped 20 bbls FW from Dowell· switched to rig pumps and displaced with 8.8 ppg brine - 5 bpm 200 - 660 psi first 343 bbls pumped - increased rate to 7 bpm with spacer at shoe - 374 bbls of brine displaced at midnight (calc to bump 444 bbls). 24 HR SUMMARY: Ran 7" casing to 7054' - Circ & condition mud - Ran 7· casing to 10,354' - Circ & lost returns Continue RIH wI 7" csg to 11,565' - Work csg down fl 11,565' to 12174', PU hanger, landed casing in wellhead - attemp to circ - cement casing. Printed: 121912003 3:18:07 PM WELL NAME C02-55 24 HR SUMMARY: coMpANY ConocoPhillips Company Doyon Drilling Inc ACI - Arctic Catering Halliburton - Sperry-Sun Halliburton - Sperry-Sun IT:M Fuel Water, Drilling R~ERVOIR NAME CD2-41 ) ') ConocoPhIlUps,Ala$ka Dally Drilling Report 1 JOB NUMBER I EVENOTDcRoDE 124 HRS PROG I TMD 1 TVD 12,220.0 7,321.0 SERVICE UNITS gals bbls USAGE 1,020 60 PERSONNEL DATA NO. HOURS CpMpANY 2 M-I Drilling Fluids 27 Swaco 5 Dowell 2 FMC Corporation Wellhe 2 MATERIALS I CONSUMPTION ON HAND ITEM -8,441 Water, Potable -9,830 RESERVOIR AND INTERVAL DATA ZONE TOP BASE C02-55 0 0 UNITS bbls P~gJ,2'Øf"?' I DFS I REPT NO. I DATE 11.00 12 7/24/2003 SERVICE NO,', .:tï4:)UF&$ 3 4 2 1 USAGE 120 ON HAND -1,300 COMMENTS Printed: 121912003 3:18:07 PM . .. .' , " , ,: . ..' . .····øønQ~;cJPhll~:I,~S,....·,~~_~~. Dally Drlll'ing: Report I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS CD2·55 ODR 12,220.0 7,321.0 12.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Don Mickey/Dave Burley doyon1 @ppco.co Doyon 19 Alpine 17,618.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD RIH w/ Schlumberger USIT log for cement evaluation 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Run bond log· MU 6 1/8" drlg assy· drill out - FIT - drill 7/14/2003 105,005 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 15.92 10029728 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 7/21/2003 12,151.23 87.410 150.970 7.000 (in) @ 12,210.0(ft) 4.500 (in) @ 11,100.0(ft) ·DENSITY(ppgLI 8.80 tpP,l leçDI IM4DDATAIDAlLY.~()srl 0 I CUM COST I ·FV' PV/YP GELS· WUHTHP Fcrr.SOL .OIUwAT ' %Sand/MBT·. P~pM pflMf CI ·Ca "2S. / / / I / / / / .. ) WELL NAME ) I REPT NO. I DATE 13 7/25/2003 ICUM. TANGO CUM INT ANG W/ MUD o CUM COST WI MUD 2,181,388 AUTH. LAST BOP PRES TEST 7/25/2003 o LIME ES ,. 't=ROMo :: 10: :HOU~S·' .: CO,!;»E· TROUBLE·':;S~B 00:00 00:30 0.50 CEMENT P DISP ·OPERÅTIONS:¡SUMMARY,.:. . . PHASE.. INTRM1 , . 00:30 01:30 1.00 CEMENT P OTHR INTRM1 01:30 02:30 1.00 CEMENT P PULD INTRM1 02:30 03:30 1.00 DRILL P OTHR INTRM1 03:30 05:30 2.00 DRILL P OTHR INTRM1 05:30 10:00 4.50 WELCTL P BOPE INTRM1 10:00 10:30 0.50 DRILL P OTHR INTRM1 10:30 11:30 1.00 DRILL P PULD INTRM1 11:30 16:00 4.50 DRILL P PULD INTRM1 16:00 17:30 1.50 RIGMNT P RSRV INTRM1 17:30 19:30 2.00 DRILL P TRIP INTRM1 19:30 22:30 3.00 WAlTON XtEQI P EQIP INTRM1 22:30 00:00 1.50 LOG Xt DH OTHR INTRM1 .. . PESCRiØTlON·· Continue displacing cement w 8.8 ppg brine @ 7 bbls/min. I 830 - 1160 psi - Reduced rate to 3.5 bpm last 10 bbls final pressure 920 psi -bumped plug to 1400 psi - total displacement 458.2 bbls (Used 95% pump output .0836 bbls/stk - calc disp. 463.9 bbls) CIP @ 0010 hrs. Check floats - did not hold. Bumped plug to 1400 psi (4.2 bbls pumped) line up to cement unit - check floats, bled back 2 bbls, floats held. Pressure test 7" casing to 3500 psi for 30 mins. Rig down cement lines & head - LD landing jt. - casing slips & elevators - long bails Pull thin wall wear bushing - Install & test pack-off to 5000 psi for 15 mins. PJSM - Change top pipe rams bac k to 31/2" x 6" VBR - Change junk sub in TO Set tet plug - Test BOPE - Hydril to 250 & 3500 psi - Pipe rams - bkind rams, kill and choke line valves, choke manifold valves, Top drive IBOP's',rig floor TIW & dart valves to 250 & 5000 psi Performed accumulator closure test - witnessing of test waived by Chuck Scheve & John Crisp AOGCC Rig down test equipment - Pull test plug - set wear bushing PU drilling bails & DP elevator PU motor & AGS, function AGS, LD motor & AGS PU & RIH wI 171 jts (5437') 4" DP for 61/8" section Slip & cut drill line - Service Top Drive. POOH - stand back 4" drill pipe. Schlumberger E-line truck would not start. APC mechanics worked on truck and replaced dead batteries. Logging truck arrived on location @ 2230 hours. Schlumberger crew arrived at Alpine @ 1730 hrs. Spot Schlumberger equipment and rehead from 0.23" line to 0.39" line. 24 HR SUMMARY: Finish displacing cement - test casing 3500 psi 30 min. - RD casing tools - install and test packoff to 5000 psi for 15 min. - Change top rams to 3.5" X 6" - Test BOPE. PU and stand back 171 jts of 4" drill pipe. Wait on loggers. SE~VICE . PER$QN·N,EL'QATA·..' ,.. .:cci~~Å~Y, ConocoPhillips Company Doyon Drilling Inc ACI - Arctic Catering :~O,.· 2 26 5 ·HOµR$; ;...., :.COMPANy Halliburton - Sperry-Sun Halliburton - Sperry-Sun M- Drilling Fluids . . , '. "SERVICE':: >,. .. NQ~ '.'·HO~Å$~~(; 2 2 3 Printed: 1117/2003 11 :05:35 AM ') CD2-55 ..." ",..,,, .'. ," . ':'..., .', ::' ; ,. '., "', ,'''', ," " ',. " , '" ." , ' . " , '.,. ".,. .. " ,',' , " , , '''', ,'. "" " , " ,.,.., .... "". ".. ''', ',"'" ',.,':."';',' "'"," , . . " ,. ... .'.. :;':èÓn~~óPhU'lïþ8, :Äïåskå;··· ::.' C¡dly:·'[)rillh;g. Report I JOB NUMBER I EVENTODCRODE 124 HRS PROG ITMD ITVD 12,220.0 7,321.0 ·p~gè:2:Qf>g WELL NAME I DFS I REPT NO. 12.00 13 I DATE 7/25/2003 COMPANY· Swaco Dowell SERVICE , PE~S.ONNEL:.DAT·~ 'NO.· HÒUR$ COMPANY· 4 Baker 011 Tools 2 SERVICE, NO. HOURS 1 rr:eM . . UNITS gals bbls MATERIALS I CONSUMPTION USAGE· . . QN ¡'¡A~D . ITEM 880 -9,321 Water, Potable 650 -10,480 : UNITS . bbls USAGE 120 : ON HAND -1 ,420 Fuel Water, Drilling ···RESERVOIR NAME· CD2-41 . :":RESa:RYbIFtÄND'I'NTERVAL:DATA ,~ON~ ;:'. . >TQP ... ·BASE,:.. . C02-55 1082 3.5 1090 .. . COMMI;~TS... '. ..: Printed: 11/7/2003 11 :05:35 AM Page 1 of 2 ) ') Well Service Report I Well IIJob Scope IIJob Number ICD2-55 IICEMENT SQUEEZE(206) 110830030101.1 IDate IIDaily Work IIUnit Number 08/30/2003 CEMENT SQUEEZE(206): PERF UPPER CIRC HOLES, SET UNIT #3 K-l CMT RETAINER IDay IIOperation Complete IISuccessful IIKey Person IISupervisor I 0 II False II False II D.S. PAIL II RAUCHENSTEIN I I Field IIAFC# IIcc# IIDaily Cost IIAccum Cost IISigned I I ALPINE II 10029729 I I 33752 II 518486.55 II ? I IInit Tbg Press IIFinal Tbg Press IInit Inner Ann IIFinal Inner Ann IIInit Outer Ann IIFinal Outer Ann I I 0 II 0 II 0 II 0 II 250 II 350 I Daily Summary ITime I 09:00 I 09:05 09:40 09:50 11:23 11:30 12:00 12:45 14:00 14:30 PRE CMT SQUEEZE: PERFORATED UPPER CIRC HOLES AT 11755 Ï\ID-RKB. SET BAKER K-l 7" CE:MENT RETAINER AT 11860' Ï\ID-RKB. [Cement-Poly Squeeze] IILog Entry IlpJSM. FILL CT WI SEAWATER. PT COIL. IISAFETY W ALKDOWN/AUDIT W/ CPAI SAFETY REP. MAKE UP BHA AND GUN ASSY: COIL CONNECTORlCHECK/HYD DISC/XO (6.04'), CBF FIRING HEAD(3.59'), GUN (4.45' TO TS). GUN SPECS: 1 'X 4.5" PF4621 (HMX), 6 SPF (7 SHOTS TOTAL), 60 DEG PHASING (5' X 4-1/2" HSD CARRIER). FLANGE UP LUBRICATOR TO TREE. OPEN 7-5/8" VALVES. PRESSURE TEST AGAINST FORMATION. TOOK -13 BBLS TO FILL UP WELLBORE. PT TO 500 PSI. HELD OK. RIH. IlpU WEIGHT CHECK @ 7489' CTÏ\ID, 18 KIPS. IIADmST ELECTRONIC COUNTER AT FLAG@7926' (TIE IN) RESET ELECTRONIC COUNTER AT 12040' FLAG (TIE IN TO SWS SCMT DATED 7/27/2003). CHECK BALL DIA:METER WI CALIPER (0.625"). PUR TO 11794'. 9-5/8"X7" ANNULUS PRESS=250 PSI, 7"PRESS=0 PSI. PUR TO SHOOT DEPTH W/ TS @ 11755' MD-RKB. LOAD AND LAUNCH BALL. CHOKE BACK 7" RETURN LINE TO APPLY -500 PSI 7" PRESSURE. BALL SEAT @ 27.5 BBLS PUMPED. GUNS FIRED AT 28 BBLS PUMPED. NO CHANGE IN 7" PRESS. 9- 5/8"X7" ANNULUS PRESS=300 PSI. FLAG PIPE (ORANGE W/GRA Y STRIPES). 1111755' Ï\ID-RKB. PU WT 22500 #. PUH. AT SURFACE. RIG DOWN GUN ASSY. ALL SHOTS FIRED. PRESSURE TEST HYDRAULIC DISCONNECT TO 3500 PSI. RIG UP CErvrENT RETAINER RUNNING ASSY: COIL CONNECTOR, DUAL CHECKS, HYDRAULIC DISCONNECT, XO, J-l HYDRAULIC SETIING TOOL, http://anc402/wsr/content/atdbworklog.asp ?ID=CD25 5 8302003091640&Field=KR U 12/9/2003 ) ') Page 2 of 2 ADAPTER KIT, 3BB K-l CEÑlENT RETAINER. MAX OD OF TOOLSTRING= 5.68" K-l BODY. J-l SETTING TOOL SETS W/ 0.5" BALL. 15:07 ADJUSTED SET DEPTH FOR K-l CEMENT RETAINER TO 11860' MD-RKB FROM 11870' MD-RKB BECAUSE OF PROXIMITY TO THE CASING COLLAR AT 11873' MD-RKB. 15:30 IIRIH W/CE:MENT RETAINER AND SETTING TOOL. 17:05 IISLOW DOWN CT TO 70 FPM BEFORE K-l REACHES TOP PERF. 17:08 AT FLAG (12040) RESET ELECTRONIC COUNTER TO 12042.2' MD-RKB (TIE IN TO SWS SCMT DATED 7/27/2003). CALIPERED 0.500" STEEL BALL. PU TO BALL SETIING DEPTH. PU WT 22000#. PUH TO 11905.5' MD-RKB. LOAD AND LAUNCH BALL. PUHTO 11859.6' MD-RKB. PUMP TAKING RETURNS TO TANKS. CT WT=13000#. K-l SET @ 27.9 BBLS PUMPED, 3750 PSI CT PRESS. 17:44 PUT WEIGHT ON K-l TO VERIFY SET (GOOD). PUR, PU WT=20000#. PUMP MINIMUM RATE WHILE POOH. 18:10 IlpU WT CHK @ 9477.3' = 13900#, PUMPING 0.3 BPM. 19:10 IIAT SURFACE. RD J-l RUNNING TOOLSTRING. IService Company· Service IAPC LABOR IBAKER OIL TOOLS EQPT - DOWNHOLE - RENTAL IDOWELL SERVICES - COILED TBG IORBIS CONSULTANT IPIDLLIPS MISC-INDIRECTS PIDLLIPS PAl SUPERVISION ITotal Field Estimate Daily Cost IIAccum Total 4,500.0011 12,000.0011 7,500.0011 2,252.0011 5,500.0011 2,000.0011 33,752.0011 Fluid Summary START; 700 BBLS SEA WATER USED; 200 BBLS SEA WATER http://anc402/wsr/content/atdbworklog.asp ?ID=CD2558302003091640&Field=KR U I ?I ?I ?I ?I ?I ?I ?I 12/9/2003 Page 1 of 2 ) ) Well Service Report IWell IIJob Scope IIJob Number I ICD2-55 IICEMENT SQUEEZE(206) 110830030101.1 I IDate IIDaily Work IIUnit Number I 108/31/2003 IICEMENT SQUEEZE(206): CTU 1 CMT SQZ IIUNIT #3 I IDay IIOperation Complete II Successful IIKey Person IISupervisor I I 0 II True II False II DS-KEY II RAUCHENSTEIN I I Field IIAFC# IIcc# IIDaily Cost IIAccum Cost II Signed I I ALPINE II 10029729 I I 108201 II 518486.55 II ? I IInit Tbg Press IIFinal Tbg Press IIInit Inner Ann IIFinal Inner Ann IIInit Outer Ann IIFinal Outer Ann I I 0 II 0 II 0 II 0 II 350 II 400 I Daily Summary ITime I 00:01 00:56 02: 12 04:43 06:00 07:00 11:00 12:03 13:10 PERFORMED A CMT SQUEEZE WITH 15.8 PPG CLASS G CEMENT FROM 12,100' TO 11,300' CCT:MD WITillN THE 7" CASING. DISPLACED 6 BBLS OF 15.8 PPG CLASS G CEMENT BEillND THE 7" BY 8.5" ANNULUS. DISPLACEMENT BETWEEN PERFORATIONS = 4.3 BBLS, TillS SHOWS A SQUEEZE OF 1.7 BBLS INTO THE FORMATION. LOADED WELL WITH 8.8 PPG BRINE FROM 11,300-2,000' CCT:MD. FREEZE PROTECTED TO 2,000' CCT:MD WITH 6.8 PPG DIESEL. [Cement-Poly Squeeze] IILog Entry IlcONTINUE TO POOH PUMPING KWF FOR PRE-RIG. STBY FOR BRINE TRUCK TO RE-LOAD. CURRENTLY AT 6,505' CT:MD. PUMPED A TOTAL OF 268 BBLS OF BRINE AT TillS TIME. TOP OF BRINE IS CURRENTLY AT 4305' CONTINUE TO TO POOH PUMPING BRINE TO 2,000' CCT:MD. UP WT = 5,000# 3,724# CTP. HOLDING BACK PRESSURE OF 250# FWHP. OOH WHP = 0#. LEA VE RIG SET UP FOR THE CREW TO SLEEP. WELL CAPPED AND TESTED. IloFF LOCATION. IIAOL. PREP FOR PJSM. MAINTENANCE. INSTALL BAKER BHA OF 2.753" CC, 3.361" HYD DISC. (7/8" BALL), 3.136" XIO, 3.136" XIO, 3.115" XIO (TOO MANY CROSS OVERS!! !), 5.246" KL SPRINGS, 3 1/16" PUP JOINT, 5.246" KL SPRING, STINGER. TOTAL TOOL LENGTH = 15.07 3PREP TO BRING PUMPS ON LINE. WT CK @ 11,500' CT:MD. UP WT = 29,000# DWN WT = 7,600. BEGIN PUMPING @ 1.7 BPM 3,400# CTP WHILE PUMPING 30,000# STAB INTO THE CEMENT RETAINER @ 11,839' CTMD. PREP TO INJECT @ MIN RATE THROUGH RETAINER TO ESTABLISH AN INITIAL INJECTION RATE. ABLE TO SHOW 1.2 BPM @ 3,700@ CTP. 150# FWHP. INSPECTING FOR http://anc402/wsr/content/ atdbworklog.asp ?ID=CD255 8312003164250&Field=KR U 12/9/2003 ) ) Page 2 of 2 IlRETURNS. 16:12 BEGIN BIOZAN SWEEP TO NZL. STAGES = 10 BIO, 5 FRESH, 22+ CEMENT, 3 FRESH, 10 BIO, CONTINUE BACK ON RIG WATER UNTIL OTHERWISE NOTED. CURRENT INJECTION PRESSURE = 1.5 BPM @ 3,063# CTP, 114# CWHP. THIS IS WHILE UNSTUNG FROM CEMENT RETAINER. 19:50 BEGIN SECOND BATCH OF CEMENT TO ENSURE THAT WE ARE ABLE TO SQZ A BIT OF CEMÈNT INTO THE FORMATION. BATCH UP 13.5 BBL OF 15.8 PPG CLASS G CEMENT. 21:14 IIBEGIN PRESSURE UP OF WHP TO 500# ON WHP FOR HESITATION. 21:28 PREP TO RAISE SIWHP TO 1,000#. CURRENTLY AT 331#. 465# SICTP. TOTAL FLUIDS PUMPED TO RAISE SIWHP = 1.9 BBL. CURRENT SIWHP = 1,006#. AFTER 20 MIN SIWHP = 989#. 21:51 TAKE SIWHP TO 1,500#. AT 1,300# WHP DROPPED TO 1,250#. SHUT IN WHP AT 1,250 AND CHECK ALL HARD LINE + INJECTOR HEAD DRAIN HOSE. 22:00 TAKE SIWHP TO 1,500#. PREP TO WATCH. NO PRESSURE LOSS IN 20 MIN. BLEED DWN TO 280# FWHP BEGIN TO CIRCULATE 8.8 PPG BRINE FOR EFFECT. 23:59 IlcONTlNUE TO POOH PUMPING 8.8 PPG BRINE FOR KWF. IService Company . Service IAPC LABOR IAPC SERVICES - TRUCKING IBAKER OIL TOOLS EQPT - DOWNHOLE - RENTAL IDOWELL SERVICES - COILED TBG IDOWELL SERVICES - PUMPING ILITTLE RED SERVICES - PUMPING IMI FLUIDS FLUIDS - BRINE IORBIS CONSULTANT IPHILLIPS PAl SUPERVISION PHILLIPS FLUIDS - DIESEL NON-Recoverabl IPHILLIPS MISC-INDIRECTS ISCHLUMBERGER EQPT - DOWNHOLE - RENTAL ITotal Field Estimate Fluid Summary IIDaily Cost IIAccum Total 4,350.0011 2,000.0011 7,500.0011 7,000.0011 41,164.0011 1,960.0011 9,450.0011 2,252.0011 2,500.0011 6,000.0011 16,788.0011 7,237.0011 108,201.0011 I ?I ?I ?I ?I ?I ?I ?I ?I ?I ?I ?I ?I ?I START; 700 SEA WATER 200 DIESEL USED; 450 SEA WATER 150 RIG WATER 150 DIESEL 35 BBLS 15.8 PPG CLASS G CEMENT http://anc402/wsr/content/atdbworklog.asp?ID=CD255831200316425O&Field=KR U 12/9/2003 ) AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) Re: Distribution of Survey Data for Well C02-55 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 15,238.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ""-'·"~~-~b),,<'\. .~ 11-0ct-03 . '"" ~.,; ."., ....~.,. ..'. . rY CY3-- J l~' Sperry-Sun Drilling Services Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-55 Job No. AKZZ0002546011, Surveyed: 29 September, 2003 Survey Report 8 October, 2003 Your Ref: API 501032046300 Surface Coordinates: 5974244.05 N, 371738.44 E (70020' 16.3219" N, 151002'26.6518" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974244.05 N, 128261.56 W (Grid) Surface Coordinates relative to Structure: 198.47 S, 24.35 E (True) Kelly Bushing: 52.40ft above Mean Sea Level Elevation relative to Project V Reference: 52.40ft Elevation relative to Structure: 52.40ft SpI!!!r'I'Y-!lU,! DRILLING SERVices A Halliburton Company ~~~~" .~ ,?Œ5 ~ l \2" D r-..' [;! ~ 9 l-~'.V!,': r- . ~ )r¡ , ,-..- ..... ,..., '.'. ;.~ - ~. r' -, f'r....~· L. ~" t,J ~v ~ '~-. ~~..-- . . Survey Ref: svy274 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-55 Your Ref: API 501032046300 Job No. AKZZ0002546011, Surveyed: 29 September, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -52.40 0.00 0.00 N 0.00 E 5974244.05 N 371738.44 E 0.00 Tolerable Gyro 87.00 0.350 303.000 34.60 87.00 0.14 N 0.22W 5974244.20 N 371738.22 E 0.402 -0.23 173.00 0.500 240.000 120.60 173.00 0.10 N 0.77W 5974244.16 N 371737.67 E 0.537 -0.45 267.00 2,250 210.000 214.57 266.97 1.703 2.05W 5974242.38 N 371736.37 E 1.951 0.54 AK-6 BP _IFR-AK 306.16 2.460 210.000 253,69 306.09 3.103 2.85W 5974241.00 N 371735.54 E 0.536 1.39 394.82 3.810 207.250 342,22 394.62 7.363 5.15W 5974236.78 N 371733.16 E 1.532 4.07 -- 482.89 5.950 208.690 429.97 482.37 13.97 3 8.68W 5974230.23 N 371729.52 E 2.434 8.23 575.78 8.750 216.790 522.09 574.49 23.85 3 15.23 W 5974220.46 N 371722.81 E 3.207 13.87 664.12 11.590 212.010 609.03 661.43 36.76 3 23.96 W 5974207.70 N 371713.86 E 3.351 21.15 753.33 12.200 212.480 696.32 748.72 52.31 S 33.77 W 5974192.32 N 371703.78 E 0.692 30.24 843.44 14.920 209.140 783.92 836.32 70.48 3 44.53 W 5974174.34 N 371692.71 E 3.140 41.20 932.94 18.380 205.650 869.65 922.05 93.273 56.25 W 5974151.75 N 371680.60 E 4.022 55.78 1028.27 22.670 208.110 958.91 1011.31 123.04 3 71.42 W 5974122.25 N 371664.92 E 4.589 74.89 1123.42 27.870 208.340 1044.93 1097.33 158.81 3 90.63 W 5974086.81 N 371645.10 E 5.466 97.40 1218.52 31 .1 60 208.420 1127.67 1180.07 200.033 112.90 W 5974045.99 N 371622.13 E 3.460 123.27 1313.93 33.180 208.690 1208.43 1260.83 244.64 3 137.19 W 5974001.79 N 371597.09 E 2.123 151.19 1409.05 35.650 208.480 1286.90 1339.30 291.85 S 162.90 W 5973955.03 N 371570.57 E 2.600 180.72 1504.39 38.610 209.050 1362.90 1415.30 342.28 S 190.60 W 5973905.08 N 371542.01 E 3.126 212.16 1599.37 38.000 208.540 1437.43 1489.83 393.88 3 218.96 W 5973853.98 N 371512.77 E 0.723 244.31 1695.01 37.610 209.200 1513.00 1565.40 445.21 S 247.26 W 5973803.13 N 371483.60 E 0.588 276.27 1789.45 37.810 209.400 1587.71 1640.11 495.59 3 275.53 W 5973753.25 N 371454.47 E 0.248 307.39 1884.51 38.690 208.410 1662.36 1714.76 547.113 303.98 W 5973702.22 N 371425.15 E 1.128 339.44 1979.59 39.840 209.280 1735.98 1788.38 599.82 3 333.01 W 5973650.02 N 371395.22 E 1.341 372.26 2074,78 41.220 208.680 1808.32 1860.72 653.93 S 362.98 W 5973596.42 N 371364.33 E 1.506 405.88 '_/ 2169.73 40.190 211.080 1880.31 1932.71 707.62 S 393.81 W 5973543.27 N 371332.59 E 1.973 438.72 2264.93 40.350 212.500 1952.95 2005.35 759.92 3 426.23 W 5973491.53 N 371299.28 E 0.979 469.59 2359.96 40,180 213.040 2025.46 2077.86 811.573 459.47 W 5973440.46 N 371265.16 E 0.409 499.49 2455,37 41.070 209.640 2097.88 2150.28 864.61 S 491.76W 5973387.97 N 371231.97 E 2.500 531.08 2550.25 41.870 210.870 2168.98 2221.38 918.88 S 523.42 W 5973334.25 N 371199.38 E 1.203 564.04 2645.41 41 .360 208.300 2240.13 2292.53 973.83 3 554.62 W 5973279.85 N 371167.25 E 1.872 597.81 2740.89 41.240 209.060 2311.86 2364.26 1029.11 3 584.86 W 5973225.09 N 371136.06 E 0.540 632.33 2768.76 41 .060 209.870 2332.85 2385.25 1045.08 3 593.88 W 5973209.28 N 371126.77 E 2.019 642.17 2868.60 41.330 210.900 2407.97 2460.37 1101.80 S 627.14 W 5973153.14 N 371092.54 E 0.731 676.54 2964.10 41.420 209.340 2479.64 2532.04 1156.40 3 658.82 W 5973099.09 N 371059.94 E 1.084 709.78 3059.43 41.380 209.960 2551.15 2603.55 1211.19 S 690.00 W 5973044.84 N 371027.82 E 0.432 743.42 8 October, 2003 - 7:47 Page 2 of7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for A/pine CD-2 - CD2-55 Your Ref: AP/501032046300 Job No. AKZZ0002546011, Surveyed: 29 September, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3155.01 41.000 210.120 2623.07 2675.47 1265.68 S 721.51 W 5972990.90 N 370995.38 E 0.413 776.65 3250.79 40.700 210.390 2695.52 2747.92 1319.79S 753.08 W 5972937.33 N 370962.90 E 0.363 809.52 3346,34 40.730 209.900 2767.95 2820.35 1373.69 S 784.38 W 5972883.98 N 370930.68 E 0.336 842.32 3441.35 41.270 210.280 2839,65 2892.05 1427.62 S 815.63 W 5972830.59 N 370898.51 E 0.626 875.17 3536.77 41 .280 210.340 2911.37 2963.77 1481.96 S 847.40 W 5972776.80 N 370865.82 E 0.043 908.15 3632.24 40.990 210.410 2983.27 3035.67 1536.15 S 879.15 W 5972723.17 N 370833.14 E 0.308 940.98 -. 3727.78 41 .190 210.650 3055.28 3107.68 1590.23 S 911.05 W 5972669.63 N 370800.32 E 0.267 973.67 3823.27 41.280 209.770 3127.09 3179.49 1644.63 S 942.72 W 5972615.79 N 370767.73 E 0.615 1006.74 3918.66 40.420 207.490 3199.24 3251.64 1699.38 S 972.62 W 5972561.56 N 370736.89 E 1.805 1040.95 4014.58 39.600 205.890 3272.71 3325.11 1754.47 S 1000.33 W 5972506.95 N 370708.25 E 1.371 1076.50 4109.70 39.160 205.960 3346.24 3398.64 1808.74 S 1026.71 W 5972453.13 N 370680.94 E 0.465 1111.95 4205.28 38.790 206.090 3420.54 3472.94 1862.77 S 1053.09 W 5972399.57 N 370653.64 E 0.396 1147.18 4300.80 38.530 206.390 3495.13 3547.53 1916.29 S 1079.47 W 5972346.51 N 370626.35 E 0.336 1181.97 4396.33 38.550 207.390 3569.85 3622.25 1969.37 S 1106.39 W 5972293.89 N 370598.53 E 0.653 1216.11 4492.09 38.170 207.690 3644.94 3697.34 2022.07 S 1133.87W 5972241.67 N 370570.15 E 0.442 1249.66 4587.55 38.170 208.430 3719.99 3772.39 2074.13 S 1161.62 W 5972190.10 N 370541.52 E 0.479 1282.51 4683.29 40.420 212.990 3794.09 3846.49 2126.19S 1192.61 W 5972138.57 N 370509.64 E 3.823 1313.84 4779.07 39.690 215.780 3867.41 3919.81 2177.05 S 1227.40 W 5972088.31 N 370473.98 E 2.023 1342.32 4874.52 39.920 216.550 3940.74 3993.14 2226.38 S 1263.46 W 5972039.60 N 370437.08 E 0.570 1368.85 4969.32 42.430 217.100 4012.09 4064.49 2276.34 S 1300.87 W 5971990.30 N 370398.82 E 2.675 1395.29 5064.62 45.080 217.730 4080.92 4133.32 2328.67 S 1340.92 W 5971938.65 N 370357.88 E 2.818 1422.59 5160.24 53.370 217.250 4143.31 4195.71 2386.09 S 1384.94 W 5971882.00 N 370312.89 E 8.678 1452.51 5256.08 57.860 216.030 4197.43 4249.83 2449.55 S 1432.11 W 5971819.36 N 370264.64 E 4.801 1486.27 ~-" 5351 .1 0 60.240 215.240 4246.29 4298.69 2515.78 S 1479.58 W 5971753.95 N 370216.05 E 2.604 1522.34 5446.59 60.880 214.250 4293.23 4345.63 2584.11 S 1526.97 W 5971686.44 N 370167.50 E 1.124 1560.29 5541.76 61.730 213.280 4338.92 4391.32 2653.51 S 1573.36 W 5971617.84 N 370119.92 E 1.264 1599.66 5637.17 62.410 212.240 4383.61 4436.01 2724.40 S 1618.97 W 5971547.74 N 370073.10 E 1.198 1640.71 5732.65 63.040 210.910 4427.37 4479.77 2796.70 S 1663.41 W 5971476.21 N 370027.44 E 1 .403 1683.56 5827.87 63.590 209.970 4470.13 4522.53 2870.05 S 1706.51 W 5971403.61 N 369983.09 E 1.054 1727.96 5923.50 63.390 209.450 4512.82 4565.22 2944.37 S 1748.92 W 5971330.02 N 369939.41 E 0.530 1773.55 6016.89 62.770 209.710 4555.10 4607.50 3016.79 S 1790.02 W 5971258,32 N 369897.08 E 0.709 1818.07 6114.34 62.130 210.260 4600.17 4652.57 3091.63 S 1833.20 W 5971184,23 N 369852.62 E 0.826 1863.75 6209.80 61.160 210.850 4645.51 4697.91 3163.97 S 1875.91 W 5971112.63 N 369808.69 E 1.153 1907.45 6305.28 60.420 211.120 4692.10 4744.50 3235.41 S 1918.81 W 5971041.93 N 369764.57 E 0.813 1950.26 6400.70 59.730 212.460 4739.71 4792.11 3305.70 S 1962.37 W 5970972,39 N 369719.81 E 1.416 1991.75 8 October, 2003 - 7:47 Page 3 of7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-55 Your Ref: API 501032046300 Job No. AKZZ0002546011, Surveyed: 29 September, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 Daft) 6496.46 59.870 212.720 4787.88 4840.28 3375.44 S 2006.95 W 5970903.44 N 369674.05 E 0.276 2032.27 6592.12 60,020 212.860 4835.79 4888.19 3445.04 S 2051.79 W 5970834.61 N 369628.02 E 0.202 2072.55 6687.26 60.240 213.060 4883.17 4935.57 3514.26 S 2096.67 W 5970766.16 N 369581.96 E 0.294 2112.47 6783,02 59.880 214.260 4930.96 4983.36 3583.33 S 2142.67 W 5970697.89 N 369534.80 E 1.149 2151.73 6878.42 59.590 215.130 4979.05 5031.45 3651.08 S 2189.57W 5970630.96 N 369486.75 E 0.844 2189.40 6974.10 59.780 215.060 5027.34 5079.74 3718.66 S 2237.05 W 5970564.20 N 369438.11 E 0.208 2226.65 .~ 7069.54 60.100 215.160 5075.15 5127.55 3786.23 S 2284.56 W 5970497.45 N 369389.45 E 0.347 2263.88 7164,99 59,810 215,310 5122.94 5175.34 3853.72 S 2332.23 W 5970430.79 N 369340.63 E 0.333 2300.96 7260,31 59.580 215.410 5171.04 5223.44 3920.83 S 2379.86 W 5970364.50 N 369291.87 E 0.258 2337.73 7356,33 59.1 00 215.770 5220.00 5272.40 3988.00 S 2427.92 W 5970298.16 N 369242.66 E 0.595 2374.34 7451.62 58,790 215.130 5269.16 5321.56 4054.50 S 2475.27 W 5970232.48 N 369194.18E 0.661 2410.70 7547.15 58.990 215.630 5318.52 5370.92 4121.18 S 2522.63 W 5970166.62 N 369145.69 E 0.495 2447.22 7642.68 59.140 216.100 5367.62 5420.02 4187.59 S 2570.63 W 5970101.04 N 369096.55 E 0.450 2483.19 7738.17 59.430 216.760 5416.40 5468.80 4253.64 S 2619.39 W 5970035.84 N 369046.68 E 0.667 2518.49 7833.35 61.560 215.910 5463.27 5515.67 4320.37 S 2668.46 W 5969969.96 N 368996.47 E 2.369 2554.24 7929.15 61.500 215.630 5508.94 5561.34 4388.70 S 2717.68 W 5969902.48 N 368946.09 E 0.264 2591.33 8022.73 61.570 215.310 5553.54 5605.94 4455.70 S 2765.42 W 5969836.31 N 368897.21 E 0.310 2627.94 8118.30 61.210 214.700 5599.31 5651.71 4524.42 S 2813.55 W 5969768.42 N 368847.91 E 0.675 2665.90 8215.13 60.950 212.220 5646.14 5698.54 4595.12 S 2860.28 W 5969698.53 N 368799.98 E 2.258 2706.25 8310.40 60.350 211.720 5692.83 5745.23 4665.56 S 2904.25 W 5969628.84 N 368754.82 E 0.778 2747.68 8405.85 59.880 212.590 5740.39 5792.79 4735.63 S 2948.29 W 5969559.54 N 368709.58 E 0.931 2788.74 8501.56 59.590 214.470 5788.63 5841.03 4804.53 S 2993.95 W 5969491.43 N 368662.75 E 1.723 2828.02 8596.91 59.500 215.430 5836.96 5889.36 4871.90 S 3041.03 W 5969424.88 N 368614.52 E 0.873 2865.27 ~ 8692.55 59.930 215.310 5885.20 5937.60 4939.25 S 3088.84 W 5969358.36 N 368565.57 E 0.462 2902.16 8787.98 60.220 214.340 5932.80 5985.20 5007.14 S 3136.07W 5969291.28 N 368517.19 E 0.932 2939.81 8883.12 60.300 213.630 5980.00 6032.40 5075.64 S 3182.24 W 5969223.59 N 368469.85 E 0.653 2978.48 8979.25 60.510 213.760 6027.4 7 6079.87 5145.18 S 3228.62 W 5969154.84 N 368422.29 E 0.248 3017.99 9074.47 59.950 214.580 6074.75 6127.15 5213.57 S 3275.04 W 5969087.26 N 368374.71 E 0.951 3056.45 9170.43 59.400 214.080 6123.20 6175.60 5281.97 S 3321.75 W 5969019.67 N 368326.83 E 0.729 3094.78 9264.29 59,320 214.050 6171.04 6223.44 5348.87 S 3366.98 W 5968953.56 N 368280.46 E 0.090 3132.49 9361,39 60.240 214.660 6219.91 6272.31 5418.13 S 3414.33 W 5968885.11 N 368231.93 E 1.092 3171.29 9456.83 60.170 215.340 6267.34 6319.74 5485.98 S 3461.84 W 5968818.09 N 368183.27 E 0.623 3208.76 9552.60 60.140 216.060 6315.00 6367.40 5553.44 S 3510.31 W 5968751.47 N 368133.65 E 0.653 3245.44 9648.03 60.440 216.040 6362.29 6414.69 5620.45 S 3559.09 W 5968685.30 N 368083.74 E 0.315 3281.58 9743.51 60.540 215.660 6409.32 6461.72 5687.80 S 3607.75 W 5968618.79 N 368033.93 E 0.362 3318.07 8 October, 2003 - 7:47 Page 4 of7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-55 Your Ref: API 501032046300 Job No. AKZZ0002546011, Surveyed: 29 September, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 9839.02 60,280 215.590 6456.49 6508,89 5755.31 S 3656.13 W 5968552.12 N 367984.40 E 0.280 3354.83 9934.88 60.080 215.570 6504.15 6556.55 5822.95 S 3704.52 W 5968485.32 N 367934.86 E 0.209 3391.71 10030.44 60.140 215.580 6551.78 6604,18 5890.34 S 3752.72 W 5968418.76 N 367885.52 E 0.063 3428.45 10125.58 60.030 215.380 6599.22 6651,62 5957.49 S 3800.58 W 5968352.44 N 367836.51 E 0.216 3465.14 10221.41 60.300 214.390 6646.90 6699.30 6025.68 S 3848.13 W 5968285.07 N 367787.81 E 0.939 3502.90 '~' 10316.26 60.570 213.900 6693.70 6746.10 6093.96 S 3894.43 W 5968217.60 N 367740.34 E 0.532 3541.32 10411.33 60.160 213.870 6740.71 6793.11 6162.56 S 3940.50 W 5968149.80 N 367693.11 E 0.432 3580.13 10507.10 60.080 213.280 6788.42 6840.82 6231.74 S 3986.42 W 5968081.41 N 367646.01 E 0.541 3619.53 10602.28 64.000 208.420 6833.06 6885.46 6303.90 S 4029.45 W 5968009.99 N 367601.75 E 6.106 3662.92 10697.57 63.740 204.450 6875.04 6927.44 6380.49 S 4067.53 W 5967934.07 N 367562.37 E 3.750 3712.54 10793.14 63.250 202.600 6917.69 6970,09 6458.90 S 4101.67W 5967856,25 N 367526.89 E 1.807 3765.63 10888.43 63.660 201.530 6960.28 7012,68 6537.90 S 4133.69 W 5967777.81 N 367493.53 E 1.093 3820.24 10984,36 65.620 199.930 7001.37 7053.77 6618.97 S 4164.36 W 5967697.28 N 367461.47 E 2.539 3877.31 11079.68 68.250 197.790 7038.71 7091.11 6701.95 S 4192,69 W 5967614.79 N 367431.73 E 3.446 3937.16 11172.86 70.890 194.550 7071.24 7123,64 6785,80 S 4216.98 W 5967531.37 N 367406.01 E 4.318 3999.69 11269,98 72.330 189.040 7101.90 7154.30 6875.97 S 4235.79 W 5967441.53 N 367385.66 E 5,584 4070.37 11365,29 72.720 184.570 7130.54 7182.94 6966,22 S 4246.56 W 5967351.49 N 367373.35 E 4.492 4144.91 11461.37 73.750 180.340 7158.26 7210.66 7058,10 S 4250.49 W 5967259.68 N 367367.85 E 4.349 4224.11 11557.01 76,050 175.610 7183.19 7235.59 7150,35 S 4247.21 W 5967167.40 N 367369.55 E 5.346 4307.03 11651 . 16 77.950 171.410 7204.37 7256.77 7241.47 S 4236.83 W 5967076.11 N 367378.37 E 4.792 4392.30 11748,39 79.830 167.150 7223.12 7275.52 7335.18 S 4219.07 W 5966982.11 N 367394.52 E 4.714 4483.33 11843.27 82.330 162.560 7237.83 7290.23 7425,62 S 4194.58 W 5966891.26 N 367417.46 E 5.457 4574.64 11938.71 83.320 157.650 7249.76 7302.16 7514.63 S 4162.36 W 5966801.71 N 367448.15 E 5.209 4668.34 - 12034.15 86.050 153.340 7258.61 7311.01 7601.07 S 4122.96 W 5966714.61 N 367486.07 E 5.329 4763.15 12129,38 87.100 151.230 7264.30 7316.70 7685.22 S 4078,75 W 5966629.72 N 367528.84 E 2.471 4858.20 12151,23 87.410 150.970 7265.34 7317.74 7704,33 S 4068.20 W 5966610.44 N 367539.06 E 1.851 4880.02 12256.94 86.600 150.420 7270.87 7323.27 7796.38 S 4016.53 W 5966517.51 N 367589.14 E 0.926 4985.56 12352.70 86.110 149.560 7276.95 7329.35 7879,13 S 3968.73 W 5966433.95 N 367635.52 E 1.032 5081.07 12448.17 85.430 150.650 7284.00 7336.40 7961.67 S 3921.28 W 5966350.61 N 367681.55 E 1.343 5176.24 12543.97 87.340 151.670 7290.04 7342.44 8045.42 S 3875.17 W 5966266.09 N 367726.23 E 2,259 5271.83 12638.63 87.160 151.470 7294.58 7346.98 8128.57 S 3830.15 W 5966182.18 N 367769.81 E 0.284 5366.38 12735.06 87.040 150.850 7299.46 7351.86 8212.93 S 3783,70 W 5966097.04 N 367814.82 E 0.654 5462.68 12830.06 86.980 151.330 7304.41 7356.81 8295.98 S 3737.83 W 5966013.22 N 367859.25 E 0.509 5557.54 12924.93 88.760 150.920 7307.94 7360.34 8378.99 S 3692.05 W 5965929.44 N 367903.61 E 1.925 5652.33 13020.25 90.310 151.510 7308.71 7361.11 8462,53 S 3646.16 W 5965845.13 N 367948.07 E 1.740 5747.64 8 October, 2003 - 7:47 Page 5 of7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-55 Your Ref: API 501032046300 Job No. AKZZ0002546011, Surveyed: 29 September, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13116.25 90.990 150.150 7307.62 7360.02 8546.34 S 3599.37 W 5965760.52 N 367993.41 E 1.584 5843.61 13208.95 90.620 150.480 7306.32 7358.72 8626.87 S 3553.47 W 5965679.22 N 368037.93 E 0.535 5936.27 13306.45 90.370 150.140 7305.48 7357.88 8711.57 S 3505.18 W 5965593.71 N 368084.77 E 0.433 6033.73 13402,12 90.000 150.600 7305.17 7357.57 8794.73 S 3457.88 W 5965509.76 N 368130.64 E 0.617 6129.36 13497.59 89.690 150.680 7305.43 7357.83 8877.93 S 3411.07 W 5965425.76 N 368176.01 E 0.335 6224.81 I .~ 13593.23 89.260 150.990 7306.30 7358.70 8961.44 S 3364.47 W 5965341 .47 N 368221.19 E 0.554 6320.43 1 3688.68 89.010 151.340 7307.74 7360.14 9045.05 S 3318.44 W 5965257.08 N 368265.78 E 0.451 6415.86 13784.16 88.830 151.370 7309.54 7361.94 9128.83 S 3272.67 W 5965172.53 N 368310.10 E 0.191 6511.32 13879.66 88.520 152.070 7311.75 7364.15 9212.91 S 3227.44 W 5965087.70 N 368353.89 E 0.801 6606.79 13975.35 88.090 152.420 7314.58 7366.98 9297.55 S 3182.90 W 5965002.30 N 368396.98 E 0.579 6702.44 14070.79 88.090 152.920 7317.76 7370.16 9382.29 S 3139.10 W 5964916.83 N 368439.32 E 0.524 6797.81 14166.4 7 87,960 152.800 7321.06 7373.46 9467.38 S 3095.48 W 5964831.00 N 368481.47 E 0.185 6893.42 14261.75 87,840 153.420 7324.55 7376,95 9552.30 S 3052.42 W 5964745.35 N 368523.08 E 0.662 6988.62 14357.02 90,190 152.420 7326.19 7378.59 9637.11 S 3009.06 W 5964659.82 N 368564.98 E 2.681 7083.85 14452.55 91,540 151.460 7324.75 7377,15 9721.40 S 2964.13 W 5964574.77 N 368608.46 E 1.734 7179.37 14547.72 92.590 151.160 7321.32 7373.72 9804.83 S 2918.47 W 5964490.57 N 368652.69 E 1.147 7274.47 14643.53 92.220 151.400 7317.30 7369.70 9888.78 S 2872.4 7 W 5964405.85 N 368697.24 E 0.460 7370.19 14738.46 93.090 151.320 7312.90 7365.30 9972.00 S 2827.02 W 5964321.86 N 368741.27 E 0.920 7465.01 14834.78 92,900 151.430 7307.87 7360.27 1 0056.43 S 2780.94 W 5964236.65 N 368785.90 E 0.228 7561.20 14930.03 92,530 151.990 7303.36 7355.76 10140.21 S 2735.85 W 5964152.12 N 368829.55 E 0.704 7656.34 15025.85 92.040 151.870 7299.54 7351.94 10224.69 S 2690.80 W 5964066.88 N 368873.15 E 0.526 7752.08 15119.81 91.670 151.960 7296.49 7348.89 10307.55 S 2646.59 W 5963983.28 N 368915.94 E 0.405 7845.99 15201.54 92.960 152.040 7293.19 7345.59 10379.65 S 2608.25 W 5963910.53 N 368953.03 E 1.581 7927.65 ~ 15238.00 92,960 152.040 7291.31 7343.71 1 0411 .81 S 2591.18 W 5963878.08 N 368969.55 E 0.000 7964.06 Projected SUNey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.40' MSL. Northings and Eastings are relative to 2113' FNL, 1491' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US SUNey). Vertical Section is from 2113' FNL, 149T FEL and calculated along an Azimuth of 151.900° (True). Magnetic Declination at Surface is 24.542°(12-Jul-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 15238.00ft., The Bottom Hole Displacement is 10729.40ft., in the Direction of 193.975° (True). 8 October, 2003 - 7:47 Page 60f7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-55 Your Ref: API 501032046300 Job No. AKZZ0002546011, Surveyed: 29 September, 2003 Alaska North Slope North Slope, Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~ij ~} ~} Comment 15238.00 7343.71 10411.81 S 2591.18 W Projected Survey .~ Survey tool program for CD2-55 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0,00 267.00 0.00 266.97 267.00 15238.00 266.97 Tolerable Gyro 7343.71 AK-6 BP IFR-AK ---- 8 October, 2003 - 7:47 Page 70f7 DrillQuest 3.03.02.005 ) AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ') Re: Distribution of Survey Data for Well CD2-55 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 15,238.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~" ~ ~ ~~ '\:)N\~") 803 '-l(~ 11-0ct-03 ~~~: ~\l E: r' ,,", "ì" 2 "'/ t) ¡-, :\ ..~, J \.... i - ~ !.~....I ';,J ;..,. ':1) ~'; , Sperry-Sun Drilling Services Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-55 MWD Job No. AKMW0002546011, Surveyed: 29 September, 2003 Survey Report 8 October, 2003 Your Ref: API 501032046300 Surface Coordinates: 5974244.05 N, 371738.44 E (70020'16.3219" N, 151002' 26.6518" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974244.05 N, 128261.56 W (Grid) Surface Coordinates relative to Structure: 198.47 S, 24.35 E (True) Kelly Bushing: 52.40ft above Mean Sea Level Elevation relative to Project V Reference: 52.40ft Elevation relative to Structure: 52.40ft sper-'I'V-5UI! DRILLING SERVices A Halliburton Company ~ ~ ~,r-.~ ~, 803~110 ~ -~ \~ï=' 'Vt=O GIrT 27 2003 ¡ 'v I ;~~k~ O~¡ & G;a~ Cm¡s. Comm~on PJ1cJ"torage Survey Ref: svy305 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-55 MWD Your Ref: API 501032046300 Job No. AKMW0002546011, Surveyed: 29 September, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DDft) 0.00 0.000 0.000 -52.40 0.00 0.00 N 0.00 E 5974244.05 N 371738.44 E 0.00 Tolerable Gyro 87.00 0.350 303.000 34.60 87.00 0.14 N 0.22W 5974244.20 N 371738.22 E 0.402 -0.23 173.00 0.500 240.000 120,60 173.00 0.10 N 0.77W 5974244.16 N 371737.67 E 0.537 -0.45 267.00 2.250 210.000 214.57 266.97 1.70 S 2.05W 5974242.38 N 371736.37 E 1.951 0.54 MWD Magnetic 306.16 2.460 210.300 253,69 306.09 3.09 S 2.85W 5974241.00 N 371735.53 E 0.537 1.39 394.82 3.810 207.910 342.22 394.62 7.34 S 5.19W 5974236.80 N 371733.12 E 1.529 4.03 '-' 482,89 5.950 208.820 429.97 482.37 13.93 S 8.76W 5974230.28 N 371729.44 E 2.431 8.16 575.78 8.750 217.000 522.09 574.49 23.79 S 15.34 W 5974220.53 N 371722.70 E 3.211 13.76 664.12 11.590 212.240 609.03 661.43 36.66 S 24.12 W 5974207.80 N 371713.70 E 3.350 20.98 753.33 12,200 212.680 696.32 748.72 52.18 S 33.99 W 5974192.46 N 371703.56 E 0.691 30.02 843.44 14.920 209.090 783.92 836.32 70.33 S 44.77 W 5974174.49 N 371692.47 E 3.158 40.95 932.94 18.380 205.720 869.65 922.05 93.12 S 56.50 W 5974151.91 N 371680.36 E 4.012 55.53 1028.27 22.670 207.260 958.91 1011.31 123.01 S 71.44 W 5974122.28 N 371664.90 E 4.535 74.86 1123.42 27.870 207.940 1044,93 1097.33 158.98 S 90.28 W 5974086.64 N 371645.46 E 5.473 97.72 1218,52 31 .1 60 208.530 1127.67 1180.07 200.24 S 112.45 W 5974045.76 N 371622.58 E 3.473 123.68 1313.93 33.180 208.330 1208.43 1260.83 244.92 S 136.63 W 5974001.51 N 371597.64 E 2.120 151.69 1409.05 35.650 208.520 1286.90 1339.30 292.19 S 162,22 W 5973954.68 N 371571.25 E 2.599 181.34 1504,39 38.610 209.050 1362.90 1415.30 342.62 S 189.94 W 5973904.73 N 371542.67 E 3,123 212.77 1599.37 38.000 208.570 1437.43 1489.83 394.20 S 218.31 W 5973853.64 N 371513.42 E 0.715 244.91 1695.01 37.610 209.800 1513.00 1565.40 445.38 S 246.89 W 5973802.95 N 371483.96 E 0.888 276.60 1789.45 37.810 209.750 1587.71 1640.11 495.52 S 275.58 W 5973753.31 N 371454.43 E 0.214 307.31 1884.51 38.690 208.820 1662.36 1714.76 546.85 S 304.36 W 5973702.48 N 371424.77 E 1.106 339.04 1979.59 39.840 209.540 1735.98 1788.38 599.39 S 333.70 W 5973650.46 N 371394.53 E 1.301 371.56 ~ 2074.78 41.220 209.740 1808.32 1860.72 653.15 S 364.30 W 5973597.22 N 371363.02 E 1 .456 404.57 2169.73 40.190 212.350 1880.31 1932.71 706.20 S 396.21 W 5973544.73 N 371330.21 E 2.095 436.34 2264.93 40.350 212.890 1952.95 2005.35 758.03 S 429.38 W 5973493.47 N 371296.15 E 0.403 466.43 2359.96 40.180 213.280 2025.46 2077.86 809.49 S 462.91 W 5973442.59 N 371261.75 E 0.320 496.04 2455.37 41.070 210.030 2097.88 2150.28 862.37 S 495.49 W 5973390.29 N 371228.27 E 2.406 527.33 2550,25 41.870 210.800 2168.98 2221.38 916.55 S 527.30 W 5973336.66 N 371195.54 E 1.000 560.15 2645.41 41 .360 207.990 2240.13 2292.53 971.59 S 558.32 W 5973282.15 N 371163.58 E 2.033 594.09 2740.89 41 .240 208.460 2311.86 2364.26 1027.12 S 588.12 W 5973227.14 N 371132.83 E 0.348 629.03 2768,76 41.060 209,190 2332.84 2385,24 1043.18 S 596.97 W 5973211.23 N 371123.72 E 1.841 639.04 2868.60 41.330 210.270 2407.97 2460.37 1100.28 S 629.58 W 5973154.70 N 371090.14 E 0.762 674.05 2964.10 41.420 209.150 2479.64 2532.04 1155.11 S 660.86 W 5973100.42 N 371057.92 E 0.781 707.68 3059.43 41.380 209.940 2551 .14 2603.54 1209.95 S 691.95 W 5973046,11 N 371025.90 E 0.550 741.42 8 October, 2003 - 7:48 Page 2 of7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-55 MWD Your Ref: API 501032046300 Job No. AKMW0002546011, Surveyed: 29 September, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3155.01 41.000 210.060 2623.07 2675.47 1264.46 S 723.42 W 5972992.14 N 370993.50 E 0.406 774.68 3250.79 40.700 210.320 2695,52 2747.92 1318.61 S 754.92 W 5972938.54 N 370961.08 E 0.360 807.61 3346.34 40.730 210.010 2767.94 2820.34 1372.50 S 786.24 W 5972885.20 N 370928.84 E 0.214 840.39 3441.35 41.270 210.390 2839.65 2892.05 1426.37 S 817.59 W 5972831.87 N 370896.57 E 0.626 873.14 3536.77 41.280 210.360 2911.36 2963.76 1480.68 S 849.42 W 5972778.12 N 370863.81 E 0.023 906.06 3632.24 40.990 210.670 2983.27 3035.67 1534.78 S 881.31 W 5972724.57 N 370831.00 E 0.371 938.76 ~ 3727.78 41 .190 210.820 3055,27 3107.67 1588.75 S 913.41 W 5972671.16 N 370797.98 E 0.233 971.25 3823,27 41 ,280 210.070 3127.08 3179.48 1643.01 S 945.31 W 5972617.45 N 370765.17 E 0.526 1004.10 3918.66 40.420 207.580 3199.24 3251.64 1697.66 S 975.39 W 5972563.32 N 370734.15 E 1.931 1038.13 4014.58 39.600 205.980 3272.71 3325.11 1752.71 S 1003.18 W 5972508.76 N 370705.42 E 1.371 1073.60 4109.70 39.160 206.130 3346.24 3398.64 1806.92 S 1029.69 W 5972455.00 N 370677.99 E 0.473 1108.94 4205.28 38.790 206.350 3420.54 3472.94 1860.85 S 1056.27 W 5972401.54 N 370650.50 E 0.413 1143.99 4300.80 38.530 206.800 3495.13 3547.53 1914.21 S 1082.96 W 5972348.64 N 370622.89 E 0.401 1178.49 4396.33 38.550 208.130 3569,85 3622.25 1967.02 S 1110.41 W 5972296.31 N 370594.54 E 0.868 1212.15 4492.09 38.170 208.040 3644.94 3697.34 2019.45 S 1138.39W 5972244.36 N 370565.67 E 0.401 1245.22 4587.55 38.170 208.380 3719.99 3772.39 2071.44 S 1166.28 W 5972192.86 N 370536.90 E 0.220 1277.94 4683.29 40.420 213.020 3794.09 3846.49 2123.51 S 1197.27 W 5972141.33 N 370505.03 E 3.864 1309.28 4779.07 39.690 215.430 3867.41 3919.81 2174.47 S 1231.92 W 5972090.97 N 370469.51 E 1.790 1337.91 4874.52 39.920 216.370 3940.74 3993.14 2223.97 S 1267.75 W 5972042.09 N 370432.84 E 0.675 1364.70 4969.32 42.430 216.270 4012.09 4064.49 2274.25 S 1304.71 W 5971992.45 N 370395.02 E 2.649 1391.64 5064.62 45.080 217.110 4080.92 4133.32 2327.09 S 1344.10 W 5971940.29 N 370354.74 E 2.847 1419.70 5160.24 53.370 216.990 4143.31 4195.71 2384.83 S 1387.68 W 5971883.30 N 370310.17 E 8,670 1450.11 5256.08 57.860 215.510 4197.43 4249.83 2448.61 S 1434.41 W 5971820.33 N 370262.35 E 4.855 1484.36 .~ 5351.10 60.240 215.230 4246.29 4298.69 2515.06 S 1481.58 W 5971754.70 N 370214.06 E 2.517 1520.76 5446.59 60.880 214.180 4293.23 4345.63 2583.43 S 1528.92 W 5971687.15 N 370165.55 E 1.169 1558.77 5541.76 61.730 212.620 4338.92 4391.32 2653.12 S 1574.87 W 5971618.26 N 370118.42 E 1.693 1598.60 5637.17 62.410 211.450 4383.61 4436.01 2724.58 S 1619.58 W 5971547.57 N 370072.49 E 1.297 1640.58 5732.65 63.040 210.620 4427.37 4479.77 2797.29 S 1663,33 W 5971475,62 N 370027.50 E 1.016 1684.12 5827.87 63.590 209.930 4470.13 4522.53 2870,77 S 1706.22 W 5971402.89 N 369983.36 E 0.868 1728.73 5923.50 63.390 209.940 4512.82 4565.22 2944.93 S 1748.93 W 5971329.47 N 369939.40 E 0.209 1774.03 6016,89 62.770 210.370 4555.10 4607,50 3016.93 S 1790.76 W 5971258.19 N 369896.34 E 0.781 1817.85 6114,34 62.130 211.370 4600.17 4652.57 3091.09 S 1835.08 W 5971184,80 N 369850.75 E 1.122 1862.38 6209.80 61.160 211.560 4645.51 4697.91 3162.74 S 1878.93 W 5971113.91 N 369805.68 E 1.031 1904.94 6305.28 60.420 212,130 4692.10 4744.50 3233.54 S 1922.90 W 5971043.88 N 369760.51 E 0.934 1946.68 6400.70 59.730 213.160 4739.71 4792.11 3303.17 S 1967.51 W 5970975.02 N 369714.72 E 1.182 1987.09 8 October, 2003 - 7:48 Page 3 of7 Dril/Quest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-55 MWD Your Ref: API 501032046300 Job No. AKMW0002546011, Surveyed: 29 September, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6496.46 59.870 213.340 4787.87 4840.27 3372.38 S 2012.89W 5970906.59 N 369668.16 E 0.219 2026.78 6592,12 60.020 213.120 4835.78 4888.18 3441.64 S 2058.26 W 5970838.12 N 369621.61 E 0.253 2066.50 6687.26 60.240 213.570 4883.17 4935.57 3510.56 S 2103.61 W 5970769.98 N 369575.09 E 0.471 2105.93 6783.02 59.880 214.620 4930.96 4983.36 3579.28 S 2150.12 W 5970702.07 N 369527.41 E 1.022 2144.64 6878.42 59.590 215.030 4979.04 5031 .44 3646.92 S 2197.18 W 5970635.25 N 369479.20 E 0.480 2182.15 6974.10 59.780 215.170 5027.34 5079.74 3714.49 S 2244.67 W 5970568.49 N 369430.56 E 0.235 2219.39 .~ 7069.54 60.100 215.160 5075.14 5127.54 3782.02 S 2292,25 W 5970501.79 N 369381.84 E 0.335 2256.55 7164.99 59.810 215.340 5122.93 5175.33 3849.50 S 2339.93 W 5970435.14 N 369333.01 E 0.345 2293.61 7260.31 59.580 214.620 5171.03 5223.43 3916.92 S 2387.11 W 5970368.53 N 369284.68 E 0.695 2330.87 7356.33 59.1 00 215.350 5220.00 5272.40 3984.60 S 2434.47 W 5970301.68 N 369236.17 E 0.823 2368.26 7451.62 58.790 215.340 5269.15 5321.55 4051.18 S 2481.69 W 5970235.91 N 369187.82 E 0.325 2404.75 7547.15 58.990 216.060 5318.51 5370.91 4117.60 S 2529.42 W 5970170.32 N 369138.96 E 0.678 2440.86 7642.68 59.140 216.060 5367.62 5420.02 4183.84 S 2577.65 W 5970104.91 N 369089.60 E 0.157 2476.57 7738.17 59.430 215.900 5416.40 5468.80 4250.28 S 2625,88 W 5970039.31 N 369040.24 E 0,336 2512.46 7833.35 61,560 215.250 5463.27 5515.67 4317.65 S 2674,07 W 5969972.77 N 368990.91 E 2.315 2549.20 7929.15 61.500 215.140 5508.94 5561.34 4386.47 S 2722.61 W 5969904.79 N 368941 .20 E 0.119 2587.04 8022.73 61,570 216.080 5553.54 5605.94 4453.35 S 2770.51 W 5969838.74 N 368892.17 E 0.886 2623.48 8118.30 61.210 215.240 5599.30 5651.70 4521.52 S 2819.42 W 5969771 .42 N 368842.09 E 0.859 2660.57 8215.13 60.950 212.630 5646.14 5698,54 4591.83 S 2866.73 W 5969701.93 N 368793.59 E 2.374 2700.31 8310.40 60.350 212,100 5692.83 5745.23 4661.97 S 2911.18 W 5969632.56 N 368747.94 E 0,795 2741.24 8405.85 59.880 213.310 5740.39 5792.79 4731.60 S 2955.90 W 5969563.70 N 368702.05 E 1.204 2781.61 8501,56 59.590 215.370 5788.63 5841.03 4799.86 S 3002.52 W 5969496.25 N 368654.26 E 1.883 2819.86 8596.91 59.500 216.370 5836.96 5889.36 4866.46 S 3050.68 W 5969430.48 N 368604.97 E 0.909 2855.93 ~/ 8692.55 59.930 216.210 5885.20 5937.60 4933.03 S 3099.56 W 5969364.76 N 368554.95 E 0.472 2891.63 8787,98 60.220 214.700 5932.80 5985.20 5000.40 S 3147.53 W 5969298.22 N 368505.84 E 1 .405 2928.46 8883.12 60.300 215.030 5980.00 6032.40 5068.18 S 3194.76 W 5969231.26 N 368457.46 E 0.313 2966.01 8979.25 60.510 214.800 6027.48 6079.88 5136.72 S 3242.60 W 5969163.54 N 368408.45 E 0.302 3003.94 9074.47 59.950 215.390 6074.75 6127.15 5204.35 S 3290,12 W 5969096.74 N 368359.78 E 0.797 3041.21 9170.43 59.400 214.860 6123.20 6175.60 5272.09 S 3337.78 W 5969029.82 N 368310.97 E 0.746 3078.52 9264.29 59.320 214.740 6171.04 6223.44 5338.41 S 3383,87 W 5968964.30 N 368263.76 E 0.139 3115.31 9361,39 60.240 215.330 6219.91 6272.31 5407.10 S 3432.03 W 5968896.44 N 368214.42 E 1.083 3153.22 9456.83 60.170 215.780 6267.34 6319.74 5474.49 S 3480.19 W 5968829.89 N 368165.12 E 0.416 3189.98 9552.60 60.140 216.490 6315.00 6367.40 5541.57 S 3529.18 W 5968763.65 N 368114.99 E 0.644 3226.09 9648.03 60.440 216.560 6362.29 6414.69 5608.18 S 3578.51 W 5968697.90 N 368064.53 E 0.321 3261.61 9743.51 60.540 215.890 6409.32 6461.72 5675.21 S 3627.61 W 5968631 .72 N 368014.29 E 0.620 3297.61 8 October, 2003 - 7:48 Page 4 of7 Dríl/Quest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-55 MWD Your Ref: API 501032046300 Job No. AKMW0002546011, Surveyed: 29 September, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9839,02 60.280 215.770 6456.49 6508.89 5742,55 S 3676.23 W 5968565,22 N 367964.52 E 0.293 3334.11 9934.88 60.080 215.160 6504.16 6556.56 5810.28 S 3724.49 W 5968498.32 N 367915.12 E 0.590 3371.13 10030.44 60.140 215.620 6551.78 6604.18 5877.82 S 3772.47 W 5968431.61 N 367865.99 E 0.422 3408.11 10125,58 60.030 215.610 6599.22 6651.62 5944.86 S 3820.49 W 5968365.40 N 367816.83 E 0.116 3444.63 10221.41 60.300 214.340 6646.90 6699.30 6012.98 S 3868.14 W 5968298.11 N 367768.02 E 1.184 3482.27 10316.26 60.570 213.940 6693.70 6746.10 6081.26 S 3914.44 W 5968230.63 N 367720.56 E 0.464 3520.70 .-./ 10411.33 60.160 214.270 6740.71 6793.11 6149.68 S 3960.77 W 5968163.01 N 367673.06 E 0.526 3559.23 10507.10 60.080 213.030 6788.42 6840.82 6218,81 S 4006.78 W 5968094.69 N 367625.87 E 1.126 3598.53 10602,28 64.000 208.4 70 6833.06 6885.46 6291.05 S 4049.69 W 5968023.19 N 367581.74 E 5.904 3642.05 10697,57 63.740 204.530 6875.04 6927.44 6367.59 S 4087.86 W 5967947.32 N 367542.27 E 3.722 3691.59 10793.14 63,250 202.780 6917.69 6970.09 6445.92 S 4122.17 W 5967869.58 N 367506.62 E 1.717 3744.53 10888.43 63.660 201.980 6960.28 7012.68 6524.74 S 4154.63 W 5967791.32 N 367472.82 E 0.866 3798.77 10984.36 65,620 200.490 7001.37 7053.77 6605.54 S 4186.01 W 5967711.08 N 367440.06 E 2.4 79 3855.26 11079.68 68.250 198.480 7038.71 7091.11 6688.21 S 4215.25 W 5967628.92 N 367409.41 E 3.373 3914.42 11172.86 70.890 195.120 7071.24 7123.64 6771.78 S 4240.46 W 5967545.79 N 367382.78 E 4.409 3976.27 11269.98 72,330 189.550 7101.90 7154.30 6861.78 S 4260.12 W 5967456.14 N 367361.58 E 5.640 4046.39 11365,29 72.720 185.110 7130.53 7182.93 6951.92 S 4271.71 W 5967366.21 N 367348.45 E 4.462 4120.45 11461.37 73.750 180.670 7158.26 7210.66 7043.77 S 4276.34 W 5967274.45 N 367342.25 E 4.553 4199.29 11557.01 76.050 176.030 7183.19 7235.59 7136.03 S 4273.66 W 5967182.16 N 367343.35 E 5.265 4281.94 11651.16 77.950 172.080 7204.37 7256.77 7227.25 S 4264.15 W 5967090.79 N 367351.30 E 4.559 4366.89 11748.39 79.830 167.830 7223.12 7275.52 7321.17 S 4247.50 W 5966996.60 N 367366.34 E 4.705 4457.58 11843.27 82.330 163.620 7237.83 7290.23 7411.98 S 4224.38 W 5966905.42 N 367387.90 E 5.114 4548.57 11938.71 83,320 159.150 7249.76 7302.16 7501.69 S 4194.16 W 5966815.20 N 367416,58 E 4.761 4641.94 -~ 12034.15 86.050 154.380 7258.60 7311.00 7588.97 S 4156.68 W 5966727.29 N 367452.56 E 5.740 4736.59 12129.38 87,100 151.420 7264.29 7316.69 7673.59 S 4113.38 W 5966641.94 N 367494.41 E 3.293 4831.63 12151,23 87.41 0 151.190 7265.34 7317.74 7692.73 S 4102.90 W 5966622.62 N 367504.56 E 1.766 4853.45 12256.94 86.600 151.690 7270.86 7323.26 7785.45 S 4052.43 W 5966529.05 N 367553.44 E 0.900 4959.01 12352.70 86.110 149.830 7276.95 7329.35 7868.83 S 4005.75 W 5966444.88 N 367598.68 E 2.005 5054,55 12448.17 85.430 151.670 7283.99 7336.39 7951.90 S 3959.23 W 5966361.03 N 367643.77 E 2.050 5149,74 12543.97 87.340 152.670 7290.03 7342.43 8036.45 S 3914.60 W 5966275.74 N 367686.95 E 2.249 5245.34 12638.63 87.160 152.680 7294.58 7346.98 8120.45 S 3871.20 W 5966191.01 N 367728.91 E 0.190 5339.88 12735.06 87.040 150,980 7299.46 7351.86 8205.34 S 3825.73 W 5966105.34 N 367772.92 E 1.765 5436.19 12830.06 86.980 152,690 7304.41 7356.81 8288.98 S 3780.96 W 5966020.96 N 367816.26 E 1.799 5531.05 12924.93 88.760 151.490 7307.94 7360.34 8372.75 S 3736.58 W 5965936.44 N 367859.19 E 2.262 5625.85 13020.25 90.310 152,570 7308.71 7361.11 8456.93 S 3691.88 W 5965851.51 N 367902.45 E 1.982 5721.17 8 October, 2003 - 7:48 Page 50f7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for A/pine CD-2 - CD2-55 MWD Your Ref: AP/501032046300 Job No. AKMW0002546011, Surveyed: 29 September, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13116.25 90.990 151.320 7307,62 7360.02 8541.64 S 3646.73 W 5965766.03 N 367946.14 E 1 .482 5817.16 1 3208.95 90.620 151.050 7306,32 7358.72 8622.85 S 3602.06 W 5965684.07 N 367989.42 E 0.494 5909.84 13306.45 90.370 150.240 7305.48 7357.88 8707.83 S 3554.26 W 5965598.29 N 368035.75 E 0.869 6007.31 13402.12 90.000 150.970 7305.17 7357.57 8791.18 S 3507.31 W 5965514.14 N 368081.28 E 0.855 6102.96 13497.59 89.690 152.120 7305.43 7357.83 8875.12 S 3461.82 W 5965429.44 N 368125.32 E 1.248 6198.42 13593.23 89,260 152.000 7306.30 7358.70 8959.61 S 3417.01 W 5965344.20 N 368168.68 E 0.467 6294.06 ~' 13688.68 89.010 151.900 7307,74 7360.14 9043.84 S 3372.13 W 5965259.22 N 368212.11 E 0.282 6389.50 13784.16 88.830 153.540 7309.54 7361.94 9128.68 S 3328.38 W 5965173.64 N 368254.41 E 1.728 6484.95 13879.66 88.520 153.960 7311.75 7364.15 9214.31 S 3286.15 W 5965087.30 N 368295.16 E 0.547 6580.37 13975.35 88.090 153.970 7314.58 7366.98 9300.25 S 3244.17 W 5965000.65 N 368335.67 E 0.449 6675.96 14070.79 88.090 153.980 7317.76 7370.16 9385.96 S 3202.32 W 5964914.23 N 368376.05 E 0.010 6771.28 14166.47 87.960 153.050 7321.06 7373.46 9471.55 S 3159.67 W 5964827.93 N 368417.22 E 0.981 6866.87 14261.75 87.840 154.940 7324.55 7376.95 9557.12 S 3117.93 W 5964741.66 N 368457.50 E 1.986 6962.01 14357.02 90.190 153.890 7326.19 7378.59 9643.03 S 3076.79 W 5964655.06 N 368497.16 E 2.702 7057.17 14452.55 91.540 151.160 7324.75 7377.15 9727.77 S 3032.73 W 5964569.58 N 368539.77 E 3.188 7152.67 14547.72 92.590 150.450 7321.32 7373.72 9810.79 S 2986,34 W 5964485.78 N 368584.73 E 1.332 7247.76 14643.53 92.220 151.220 7317.30 7369.70 9894.38 S 2939.69 W 5964401.40 N 368629.94 E 0.891 7343.47 14738.46 93.090 152.650 7312.90 7365.30 9978,05 S 2895.08 W 5964316.98 N 368673.12 E 1.762 7438.29 14834.78 92.900 152.360 7307.87 7360.27 10063,38 S 2850.67 W 5964230.90 N 368716.06 E 0.360 7534.48 14930,03 92.530 151.610 7303.36 7355.76 10147.37 S 2805.98 W 5964146.16 N 368759.30 E 0.877 7629.62 15025.85 92.040 152.320 7299.54 7351.94 10231.88 S 2760.98 W 5964060.89 N 368802.85 E 0.900 7725.36 15119,81 91.670 152.020 7296.49 7348.89 10314,93 S 2717,14 W 5963977.11 N 368845.27 E 0.507 7819.27 15201.54 92.960 151.800 7293.19 7345.59 10386.97 S 2678.69 W 5963904.42 N 368882.48 E 1.601 7900.93 "-"" 15238.00 92.960 151.800 7291.31 7343.71 10419.06S 2661.48 W 5963872.04 N 368899.14 E 0.000 7937.34 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.40' MSL. Northings and Eastings are relative to 2113' FNL, 1497' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 2113' FNL, 1497' FEL and calculated along an Azimuth of 151.900° (True). Magnetic Declination at Surface is 24.542°(12-Jul-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 15238.00ft., The Bottom Hole Displacement is 10753.62ft., in the Direction of 194.329° (True). 8 October, 2003 - 7:48 Page 60f7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-55 MWD Your Ref: API 501032046300 Job No. AKMW0002546011, Surveyed: 29 September, 2003 North Slope, Alaska Alaska North Slope Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 15238,00 7343.71 10419.06S 2661.48 W Projected Survey ---- Survey tool program for CD2-55 MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 267.00 0.00 267.00 266.97 15238.00 266.97 Tolerable Gyro 7343.71 MWD Magnetic .~ 8 October, 2003 - 7:48 Page 70f7 DrillQuest 3.03.02.005 ~e: C02-55 (203-118) approval to Commence Injection. ) ) Subject: Re: CD2-55 (203-118) approval to Commence Injection. Date: Fri, 21 Nov 2003 13:15:03 -0900 From: Tom Maunder <tom_maunder@admin,state.ak.us> To: "Crabtree, C L" <C.L.Crabtree@conocophillips.com> CC: "Hanson, Kelli L" <Kelli.L.Hanson@conocophillips.com>, "Alonzo, Chris" <Chris.Alonzo@conocophillips.com>, Alpine Lead Operators <alp1 006@conocophillips.com> Cliff, et al: I have looked back at the file and the assessments of the original cement job and the squeeze are there. The well has been completed with the straddle to isolate the squeeze perforations. The "1320 plot" indicates that there are no other well bores penetrating the Alpine within that distance. Based on the available information, you have approval to commence injection into the well. The IA should have been "MITed" when the well was completed. If that was not done, CPAI should conduct an MIT to verify the integrity of the wellbore prior to placing the well in service. Please make arrangements with the Inspectors to witness an MIT on the well when one of them is next out to Alpine. Please call with any questions. Tom Maunder, PE AOGCC "Crabtree, C L" wrote: > Tom > > We should have C02-55 ready for injection soon. This was the well that we squeezed and subsequently ran a bond log across. The present condition has been documented in conversations with...yºyªnd in the sundry notice request to're-srïine drilling operations in order to drill the hárizontal section of the wellbore. --- > --- . > Of the items submitted for a normal approval to begin injection, tt would appear the only item you do not have is the "1320"plot. I have attached this below. As discussed, our plan is to run a temp log on the well after it has been on line long enough to stabilize injection and operating temperatures. ~ > > Best Regards > > Cliff Crabtree > Alpine Subsurface Development - ConocoPhillips Alaska, Inc. > Office Telephone: (907) 265-6842 > Mobile Telephone: (907) 240-5357 > > «C02-55 1320 injector plot.pdf» > > ------------------------------------------------------------------------ > > > > Name: C02-55 1320 injector plot.pdf C02-55 1320 injector plot.pdf Type: Acrobat (application/pdt) Encoding: base64 Description: C02-55 1320 injector plot.pdf Tom Maunder <tom maunder@admin.state,ak,us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 11/21/2003 1 :15 PM Well Name: Drilling Supervisor: C02-55 I Rig: Don Mickey PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 7/25/2003 I Pump used: I Cement Unit I... ".. Pumping down annulus. Hole Depth 10,707 Ft-MD 6,932 Ft-TVD 1·( PressurelnteqrRvTest Mud Weight: 9.8 ppg Inner casing 00: 7.0 In. 125,000 75,000 14.5 ppg 588 psi Desired PIT EMW: Estimates for Test: 0.6 bbls I· 1·1 EMW = Leak-off Pressure + Mud Weight = 848 + 9.8 0.052 x TVD 0.052 x 2407 EMW at 2797 Ft-MD (2407 Ft-TVD) = 16.6 1000 . o UJ a: :> en 500, en UJ a: a. o 4 6 Barrels 10 12 .....CASING TEST .....LEAK-OFF TEST Comments: . FIT fLOT 15.9 ppg EMW prr 15 Second Shut-In Pressure, psi 626 '--.~ o. ... f\.1 t-\.~"', YJ (ù (s \ t; :.:-:. :.:.:. .:::~ ':::::~... :'::+t::;~~:::::;:::¡:::_ ~~=*;t::u.~~u~~~~~~ 14 0 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point I Volume Input Barrels ... 0.1000 Bbls/Strk ... .. Casing Test Pumping Bbls psi r~\' .;'~~¡::: ,,~ ~~"...~~,\ ~ ~~:' 1 \ '~I" '-1 I~"'~ ~ \'.'~ ". k~\~' ,"~ ~ :ß~~ I ' ~~ !,W;t¡, 0 ~ ~ I ~,~,~~s, ~~\~' ~\ , ~ ' ~, ~' " , I I¡~\~"'~'~"~" ,\ l,~',~~ \ ,.~.I .~, ~o,,· "'~:\..~~'\I., .; I" M '~f~j'l¡ 'If 'I~\\¡ II~' ,,'~~', " ~f~~~..v.~~',\~ '1:' ~.~ ~,l~ ¡I ,v l¡l~\J'1 I . !:¡',L~~11 ~~~~~I \ ,~;~~'§ N~~ t ' .lu~~ ~\~~~~, , , , ; t~~~ ~~~ ~~~ .~I ~,,~i ~I ,~~I ~~ ,~'I~~lì~1 '~~.' '" ..~,~;,¡ . ~ ~ ~ ~ I ~'~..:.' ..~, :Ò.rÒ~'11:.rl~' I ~~ ~~~ii:1 ~.' ~"I~~~Ø~~~:~~" ~ '~' ..~\ '~~, ~~~: ~ ~~~.. :,I..!~~,h"', "~', . ~ ,'l", 't:..~., ~~~s-,,'~~ ~,>\\ ~J\I~';;';II, .~~~.,~ . .,,,,,-,.1,,.. ~ , ~i1~' ::~ .... '~'!"'~"'''''''~' .I~ ~/. ~ I¡ ~,I ~\lul_'ì ..,.:,$'¡;~,,,,,~~ ~¡;''4!.,\...,~...., ~"I'I' ~~)Þy:o\ "~'~'.... ' . I ~ ! ~ì .' ~," . .~ ~~\ hhl,! I ,~ l' ,I I" ,'~~ ~' \1 I~~~ ~~'~~ ~~ ~~r ~~l.\\~'~,~, ~,~ "~ :~~ ~~" 111 ~ 'i, ..~)J :'h ~g.,...-..:: ..'. '~:t\"¡\ r ~ ,,''''~~\.g~ ~I I~~~ I~~."'" ~ ~ i .~"'!~ I~I \I'!~ '~~~'i~ ~.§ ,\~ ~ n _'~ ')'" Slll . \1 f :~~..~~~~~ ;:~ "i~.AL~, ~,L I I .!.~, ~~ "";,~~ ~' "';ì ....~, ,.~, ~'~~'-' ~ I' ~ ~.h . ~\~ ,\!~~~~'!+'~( IMtri~· ~'''~rF~~~~~ !~ . ¡ . ~ u !I. p ~ ,~t~ !,.~~d)~~I'i,~ I""'~ ~~ I~' 'I~ '''I~ I , ¡~.g.,,3 , I ;~' ~~~.: ~\ .. ...... ~. '~~ :;:"'W~' §).,¡,1,' ~ 'Þ~'~ " ::\,\, "p~ I . ."tt.~'~..,",I~~. I I,,~~ M.....'(>,",~~~~·lo ~f..\\ ~'!:.'~: ~~~l.........\,~ ìt ~)~ ~' ~"'Il~\~~, ~" ¡.M·I ·II~I.~ 1.!oI, .,!", ~~I..~~ ~"" o=r.' ~~(.' h(~\ I I.. ~~, I~~~,,' .~~. .$!~ ~~ !'I:..~,~~ I., ~ . t;~~':. ~F t'~~":~' .,~~ wi L:.~~~' I",~~~ h~'~~"" , I ,I (~O~ ~'}$~~, . ::~[!J:t ;'N\ ' d .~ .~~ I . '.~ Volume Pumped 0.0 Bbls Shut-in Min psi o 0 1 0 2 0 3 0 4 0 5 0 6 0 7 0 8 0 9 0 10 0 15 0 20 0 25 0 30 0 Volume Bled Back _Bbls Pump Rate: 0.5 Bbl/min ... Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: 18-1/2" l. Casing Shoe Depth RKB-CHF: 36.6 Ft 2,797 Ft-MD 2,407 Ft-TVD CasinQ Size and Description: I 9-5/8" 36#/R J-55 BTC Chanqes for Annular Adequacy Test Enter outer casing shoe test results in comments Casing Description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. Pressure integrity Test Pumping Bbls psi o 0 0.5 76 1 131 1.5 182 2 237 2.5 288 3 338 3.5 384 4 429 4.5 475 5 520 5.5 565 6 606 6.5 646 7 692 7.5 722 8 752 8.5 787 9 813 9.5 848 10 838 10.5 752 11 712 11.5 702 12 697 12.5 682 13 671 r~\· ~\~ ~ ~ \:>~ r ::.\ ~ \~\ ~ ~L ~\~~\~~ ~~\~\~ \~ ~ \~ ~"~"I, II ~~ ~'.., .':!E ~~~~,~ \~~~:~~~ ~~~'~~\t~'i Volume Pumped 13.0 Bbls Shut-in Min psi o 641 0.25 626 0.5 606 1 576 1.5 550 2 35 2.5 --s2õ 3 505 3.5 495 4 485 4.5 475 5 464 5.5 459 6 448 6.5 444 7 439 7.5 429 8 424 8.5 419 9 414 9.5 A09 10 J Volume Bled Back ~~Bbls ~ ~ o o o ..... ........ :£ "€ o ~ ::E' E o U) -9000- .L....'" Nmnc ,NI-S I ) Northing WELL DETAILS Eusting Lotitodo Longitude Slot C02-55 -396.86 49.00 5974244.050 371738.440 70°20' 16.322N \5\ °02'26.652W N/A \\1 -5000-"" ¡llipS .\ -6000-:'''' . -10000-'····.. -11000-" -12000-)2-43 V4 Plan: CD2-43 (wp02) VIS i -13000- I -6000 I -5000 I -4000 I -3000 West(-)/East(+) [1000ftJin] I -2000 I -1000 I o ") ') E9CB- II ($ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 October 16, 2003 RE: MWD Formation Evaluation Logs - CD2-55, AK-MW-2546011 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. J ~ \ ~ 1- API#: 50-103-20463-00. I:." ' ~~~\'(\ ~ 10/09/03 Schlumberger NO. 2997 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine ~ Well Job# Log Description Date BL Color Prints CD CD2-55 ~?-t \ >i CD2-40õn..~-;!91 á 23439 23440 SCMT SCMT 09/20/03 09/09/03 1 1 '~' N '"~ '!t G..L D- ¡~.~.=.-~ 1;. t.-í!- 1'''"''. . .u o ~ '~;¡ ~ 1"0 SJGNE~~~_~'<::i ~~~ DATE: Þ.laska v,; ,_ J<¡ ¡;;:, '-JcHnmtS~0!1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~......... -~ ~ 09/25/03 Schlumbepgep NO. 2974 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine ~ Color Well Job# Log Description Date BL Prints CD 80:3 - ~ CD2-30 23438 SCMT 09/16/03 1 -:¡j 4D2-55 23424 SCMT 07/27/03 1 é) Q3 -i \ CD2-55 23425 US IT 07/26/03 1 - fR"-· ~ctCI\J~r1 ª ., !b". k.a V 6. ~ SIGNE~\~ J'Y\. ~ '- Q è't ~'::, ~ DATE: S~? 23 2(\iY~ AiÐska O~·~ ~~ Ge3 Cans. C{ifnmi~ðtcn Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. ThankX~Œ'~e ~ ~~.iY\~ ConocoPhillips Alaska, Inc. ) Post' Office Box 100360 . Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ) ..~ ConocoPhillips September 23, 2003 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval - Resume operations after Temporary Shutdown of Drilling Operations C02-55 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for Sundry Approval to resume drilling operations after a temporary shutdown of drilling operations on well C02-55. The well encountered drilling fluid losses at 12,220 ft. MD or 7230 ft. TVD. The losses were controlled and 7" casing was set at 12,210 ft. MD. Due to fluid losses and lack of pressure differential observed during cementing operations, a cement quality log was run per regulation 20 AAC 25.30 (5). The SCMT log confirmed the absence C)f adequate zonal isolation through the Alpine C sand. - Doyon 19 was moved off and remedial work was performed by wireline and coil tubing operations. Perforations were shot, and a cement squeeze was performed. The well has been cleaned out and re- logged, confirming cement between thø perforations. A bridge plug has been set by wireline at +1- 2000' MD. It is planned to return to the well with Doyon 19, clean out 7" casing, drill 6-1/8" horizontal, and complete the well as an injector. Please find attached Form 10-403, Application for Sundry Approvals, and the proposed program for returning to the well, a proposed completion schematic, and an email from Cliff Crabtree regarding zonal isolation. If you have any questions or require further information, please contact Vern Johnson 265-6081 or Chip Alvord at 265-6120. Sinc~ly, /. /~'c;. ( __ Vern Johnson Drilling Engineer Attachments SEj? 2 3 'lüD~' cc: C02-55 Well File 1 Sharon Allsup Drake Chip Alvord Cliff Crabtree Steve Moothart ATO 1530 A TO 868 ATO 848 ATO 844 Nancy Lambert Lanston Chin Anadarko - Houston Kuukpik Corporation ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATIION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown D D D 1. Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 52.7' MSL 8. Property Designation: ADL 380075 / 387207 / ALK N/A ') D Repair well D D Suspend Pull Tubing 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 12220' 7321' 12220' Casing Length Size Structural Conductor 7T 34" x 16" Surface 2760' 9.625" Intermediate Production 121731 7" Liner Perforation Depth MD (ft): 11883'-11884" 11775' Packers and SSSV Type: None Printed Name G. L. Alvord .//Q. {-~ Signature ') b ~ ~ I) "::, % ~ Plug Perforations Perforate D D Variance D Annular Dispos. D Time Extension D Other D Re-enter Suspended Well 0 /.. Permit to Drill Number: 203-118 / 303-211/303-232 6. API Number: Stimulate Perforate New Pool 4. Current Well Class: Development D Stratigraphic D Exploratory D Service 0 50-1 03-20463-00 9. Well Name and Number: C02-55 10. Field/Pools(s): Colville River Field / Alpine River Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 7321' 11860' MD Burst Collapse 1141 114' 279T 24061 1 221 0' 73201 Perforation Depth TVD (ft): 72951_72951, 72801 Packers and SSSV MD (ft): Tubing Size: None Tubing Grade: None 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. <11 ~ '"" ~ ~\>tt f' 9/23/2003 \3t.~ Date: Tubing MD (ft): None None 13. Well Class after proposed work: Exploratory 0 Development D 15. Well Status after proposed work: Oil D Gas D WAG 0 GINJ D Service 0 Plugged D WINJ D Abandoned D WDSPL D Contact Vern Johnson @ 265-6081 Title Alpine Drilling Team Leader Phone 265-~ C. /2...0 Date q,j:L~ ( 0 5 COMMISSION USE ONLY Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~~·o3 --~~3 Plug Integrity D BOP Test ø Mechanical Integrity Tes~ 'I~ l.·c'...... r ,........ ~= ;; l:~~~. Location Clearance D !)'.~' rt: Other: ~Sct:)~~\ """''\. f\., ~~~ ~ ~~ \c:- ~ \- SEP ! 3 20æ Subsequent Form Required: ~ ~ Approved by: ~"ì ~OMMISSIONER BY ORDER OF THE COMMISSION Date: r~J ORIGINAL ') ) 1. Drilling ProQram: Move on Doyon 19. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. ND tree. NU and Test BOP to 5000 psi. Pick up bridge plug retrieval tool and RIH picking up 4" drill pipe. Bridge plug at +/- 2000 ft MD. Latch on and pull out of hole with retrieval tool and bridge plug. Pick up cleanout assembly including mill tooth bit, stabilizers collars and HWDP, and RIH. V \Q.~ \~ ~~c;.\ ~~~d : . ~,,"'<:>~~Ò~\\'\"\.~"(;)4t Clean out Kl cement retainer (11860' WLM wireline measured depth, 11851' MD corrected to LWD logs). Cleanout~ cement, float equipment and 20 ft of new hole. ... \. \ ~ ~~r ~ ,", ~ ~ ">~ 'TE;-.,,>\~ ~t.~~ Perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off to drill ahead is 11.5 ppg EMW. Displace well to Flo-Pro drill in fluid, and POOH. M/U the drilling assembly and RIH (GR/RES/PWD/DIR). Drill6-l/8" horizontal section to well TD at 17685' MD / 7370' TVD. Displace well to brine (plan to use seawater for makeup water) and pull out to casing shoe. Continue to pull out of hole and lay down BHA. Run 4-Y2", 12.6 #, L-80 tubing with XN nipple (with standing valve installed), straddle packers, X nipple, gas lift mandrel with dummy valve, Camco DB Nipple (3.812" ID). Land hanger. Back out landing joint. Install2-way check with rods. MlU landing joint and test hanger seals to 5000 psi. Nipple down BOP. Install wellhead adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2-way check with lubricator. Reverse circulate in 9.2 ppg inhibited brine and sufficient diesel to fill the tubing plus provide 2000' TVD of diesel freeze protection on the annulus. Pressure up on tubing to 4000 psi to set Baker Premier packers. Test tubing to 3500 psi. /30min. Test casing annulus to 3500 psi / 30 min. Set BPV and secure well. Move rig off CD Note: A coil tubing unit will return to the well and pull the standing valve prior to preparing the well for injection. ') Completion Schematic CD2-55 Top perforations 11755' (WLM) 11747' Depth shifted to LWD . 16" Conductor to 114' 4-1/2" Camco OS Nipple (3.812') at 2000' TVD = 2257' MD 9-5/8" 36 ppf J··55 STC Surface Casing @ 2797' MD /2407' TVD cemented to surface 4-1/2" 12.6 ppf L-80 I BT M tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" DRIFT ID) wI dummy ) Updated 9/17/03 (WP04) Packer Fluid mix: 9.2 PPQ KCllnhibited Srine with 2000' TVO diesel cap TubinQ suspended with diesel Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco DS6 nipple 2258' 2000' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco KSG2- GLM 60° inc (3.909" 10) 10500' 6837' 4-1/2", 12.6#/ft, 1ST-Mod Tubing HES "XD(3.81")-67º inc 11040' 7076' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) Baker Premier Packer 70° inc 11140' 7113' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Baker Premier Packer 11900' 7297' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (1) HES "XN" (3.725")-84º inc w/standing valve 11960' 7304' 4-1/2", 12.6#/ft, 1ST-Mod 10' pup joint WEG 11972' 7306' \ "'.. Bottom perforations 11883' (WLM) \'" 11874' Depth shifted to LWD ............. Baker Premier Packer below ·.......-.......E>0ttom perforations ......_--:;i Top Alpine at 11885' MD /7296' TVD ~ Planned Well TD at 17685' MD /7370' TVD 7" 26 ppf L-80 STC Mod ProdJction Casing @ 12210/7320 TVD @+/- 88º ) ) Clifford L Crabtree 09/23/2003 11 :45 AM To: Vernon T Johnson/PPCO@Phillips cc: Christopher J. Alonzo/PPCO @ Phillips, Hai L HuntlPPCO Subject: CD2-55 isolation squeeze results Vern With the assistance of Mike Kasecky of Schlumberger, I have reviewed the results of the recent post squeeze SCMT on CD2-55 and have concluded that the Alpine is adequately isolated. A quick review of the reasoning behind this statement fQllows: The primary cement job appears to have placed cement across most of the Alpine interval open to the wellbore. The SCMT conducted on 7/27/03, while Doyon 19 was still on the well, shows cement up to approximately 11,912' NJD. The top of the Alpine hydrocarbon is at 11,6901 MD (72441 TVD ss) . It was somewhere néar the top of the formation that we lost mud circulatión upon drilling into the Alpine. It appears that this same interval imbibed some portion of the cement that we circulated in the primary cement job. Although the logging tool was not able to go below 12,066' MD, it is reasonable to assume there is cement from the T' casing shoe at 12,2101 MD up to 11,9121 MD. /' An isolation squeeze was recommended because there was no discernible cement above the top of the Alpine. A plan was developed to conduct the squeeze with coiled tubing after Doyon 19 was removed. A coil assisted circulation squeeze was conducted between two sets of perforations (11,7551 - 11,8841 MD) on 8/31/03. Pump in rates through the lower set of squeeze perfšëêrtainly suggested that the cement below the injection point was holding pressure. It was for this reason that we elected to conduct the coil circulation squeeze.v""We subsequently drilled out the cement left in the casing to the cement retainer at 11860· MD and after several cleanout attempts were able to obtain an SCMT log across much of the squeezed interval. Post squeeze (9/20/03), an SCMT logging tool was tractored into the well and bond readings were obtain starting from at about 11,830' MD up. The post squeeze bond log indicates that cement was lifted to about 11,7261 MD or slightly above the upper squeeze perforations at 11,7551. There is cement of variable strength in thè 7" x OH annulus from 11,726' MD down to 11,780' MD. The amplitude readings suggest strength over 250 psi. Mike Kasecky documented his review of the squeeze cement as follows: "Working backwards looking for compressive strength 15 mv in 7" casing with standard neat cement we are looking at something greater than 250 psi. However please remember that this assumes no microannulus. The microannulus affeet could be hindering us for 5 to 10 millivolts easily. The key on this log after squeeze is to see that we improved 40+ feet of what was basically freepipe reading 60+ millivolts. I do think we have a microannulus. Looking at the interval that cement was squeezed into. the VDL shows formation arrivals. It didn1t pre squeeze. The VDL also shows pipe arrivals. This is classic in a microannulus. " One must also ask why, following a circulation squeeze, do we see cement near the downstream (upper) perforations and yet not see indications of cement closer the upstream (lower) perforations? We1ve concluded that after the circulation squeeze, some of the squeeze cement gravitated back into the casing and settled into the casing below the bottom set of squeeze perforations. The fluid that was in the casing concurrently moved into the annular space that the cement originally occupied. In summary, we believe the combination of the primary cement and the squeeze cement will adequately ~) ) isolate the Alpine from shallower permeable intervals and keep injected sea water in the Alpine. We've also recommended a straddle pack completion arrangement that will isolate the squeeze perforations from future injection pressure. Given these measures, 11m reasonably certain we will have a finished well suitable for injection service. Cliff Crabtree ConocoPhillips Alaska Inc.- Alpine Subsurface Development Office: (907) 265-6842; Cell: (907) 240-5357 Email: c.l.crabtree@conocophillips.com; Fax:: (907) 265-1515 ;CMT 9/20/03 CD2-55 ) ) Subject: SCMT 9/20/03 C02-55 Date: Mon, 22 Sep 2003 10:31 :59 -0800 From: "Clifford L Crabtree" <C.L.Crabtree@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "Christopher J. Alonzo" <Chris.Alonzo@conocophillips.com>, "Vernon T Johnson" <Vern.Johnson@conocophillips.com> Tom Vern and I are going to give you a call to discuss this log this am. Cliff Crabtree ConocoPhillips Alaska Inc.- Alpine Subsurface Development Office: (907) 265-6842; Cell: (907) 240-5357 Email: c.l.crabtree@conocophillips.com; Fax:: (907) 265-1515 ----- Forwarded by Clifford L Crabtree/PPCO on 09/22/2003 10:30 AM ----- Nina M Woods 09/22/2003 05:55 AM To: Clifford L Crabtree/PPCO@Phillips, Michael Kasecky/PPCO@Phillips, Hai L Hunt/PPCO@Phillips, Vernon T Johnson/PPCO@Phillips cc: Subject: SCMT 9/20/03 CD2-55 (See attached file: CD2-55 _ SCMT _9-20 .zip) Nina Woods Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 c. \) )-- 5 S- )O~ -\.~ ~ Name: CD2-55_SCMT _9-20.zip ~ CD2-55 SCMT 9-20.zip Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 _ \ ~m , 1 of 1 9/24/20038:04 AM . SÇMT 109 . · (..'V,^-SS dO~-\.\.'b Subject: SCMT log Date: Mon, 22 Sep 200311 :08:56 -0800 From: Clifford L Crabtree <C.L.Crabtree@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Here is the first pass before the squeeze on 2-55 Cliff Crabtree ConocoPhillips Alaska Inc.- Alpine Subsurface Development Office: (907) 265-6842; Cell: (907) 240-5357 Email: c.l.crabtree@conocophillips.com; Fax:: (907) 265-1515 ----- Forwarded by Clifford L Crabtree/PPCO on 09/22/2003 11 :08 AM .---- Michael Kasecky 09/22/2003 10:56 AM To: Clifford L Crabtree/PPCO@Phillips cc: Subject: SCMT log ----- Forwarded by Michael Kasecky/PPCO on 09/22/2003 10:55 AM ----- Vernon T Johnson 07/28/200308:58 AM To: Michael Kasecky/PPCO@Phillips cc: Subject: SCMT log Vern Johnson 907-265-6081 (w) 907 -265-1515 (fax) 907-748-3906 (Cell) Vern .Johnson@conocophillips.com ----- Forwarded by Vernon T Johnson/PPCO on 07/28/2003 08:58 AM ----- Doyon 19 Company Man 07/27/2003 11 :39 AM To: Chip Alvord/PPCO@Phillips, Vernon T Johnson/PPCO@Phillips cc: Subject: SCMT log Chip & Vern, Here is the SCMT log C02-55 1of2 9/24/2003 8:03 AM SCMT 109 . . (See attached file: Scmt_VDL_lmage_057.zip) Don Doyon 19 Drilling Supervisors Guy Whitlock 1 Don Mickey Rig phone 670-4300 fax 670-4301 --.,.--.,.-.... . ... .. ., - _n . . Name: Scmt_ VOL -'mage _ 057 .zip : ~;?-º!.TILY'pI,,_IJnage_O_!jZ.zipi Type: Zip Compressed Data (application/x-zip-compressed)' " "Encoding: base64 2of2 9/24/2003 8:03 AM J ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown 0 o o ) 1. Type of Request: o Repair well 0 o o Alter casing 0 o Abandon Suspend Change approved program Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 52.7' MSL 8. Property Designation: ADL 380075/387207/ ALK N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 12220' 7321' 12220' Casing Length Size Structural Conductor 77' 34" x 16" Surface 27601 9.625" Intermediate Production 121731 7" Liner Perforation Depth MD (ft): None Packers and SSSV Type: None 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 ) Plug Perforations Perforate 0 o Stimulate Perforate New Pool 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 AUG 1 (\11 'l]1,1J Áh 1{1f76 2003 fli;¡ Variance {\i'~íi':\ib;J:~'i Annular Dispos.O ) I,L ~ .: ..,' ~,':I ,..,,"~ .\,;' -I:) '~,µ Time Extension 0 Other r:ï1 tE. ~.;:) ~~ oç«-iõ.\\o Re-enter Suspended Well 0 5. Permit to Drill Number: 203-118 6. API Number: 50-103-20463-00 9. Well Name and Number: C02-55 10. Field/Pools(s): Colville River Field / Alpine River Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 7321' MD TVD Burst Collapse 1141 1141 2797' 2406' 12210' 7320' Perforation Depth TVD (ft): None Packers and SSSV MD (ft): 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. 8/15/2003 Date: Printed Name H;i ~unt fOr! Mooney -AI ~,~ ' Signature Tubing Size: None None 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact Title Wells Engineer Phone 265-6912 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Tubing Grade: None Tubing MD (ft): None Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Hai Hunt @ 265-6912 Date 8/1 2/2 OOS Sundry Number: 303·~"3;;)... ~ ',Y13·~~ Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: ~ 5"OO~';\ ~'\ ~\",^VIM \SCJ? +~""\, c.q'M~~+~o.\ ~ \, \0 \.<>.'J. ~\Co\.,,::J Subsequent Form Required: '-\ () 'ì c::.. -\- ~ \ \. c.ö \I"\.~ \ c -\- Ì'Ð V'\ Approved by: 14 ~~ --L-- Form 10-403 Revised 2/2003 RBDMS Bfl COMMISSIONER BY ORDER OF THE COMMISSION U ,-\ I 'J J ¡,~ /\ l~ AUG 1 .~ 2003 Date: '8//1/D~ SUBMIT IN DUPLICATE '\ " ) Hai Hunt Wells Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6912 ConocJP'hillips CD2-55 Remedial Cement Squeeze Procedure Outline ~ \0".>-\ ,-,t- L \ U .\. \: ~ ~ c. ~ \.. c:,," ~ \)...) f(: d c:..~ "'""c ~ Background Ð +- """" -\--0 0 ~ ~ \ 'f':.....(:- Drilling operations on C02-55 were suspended aífer a c~ment bond I~g snowed lack of cement behind the 7" intermediate casing. Drilling installed the tree and moved off the well until a remedial cement job is completed. Remedial Cement Squeeze Job Scope . The 7" casing will be perforated at ,....11,883 MD (1 ft, 6 SPF) . An injectivity test will be done. Depending on the level of injectivity and reservoir communication, one of the following procedures will be followed: Case 1: Circulation to surface can be established. A drillable bridge plug will be set in close proximity below the casing perforations and coiled tubing will be used to squeeze cement behind the 7" casing. Case 2. Circulation to the surface cannot be established and the leakoff rate is small. Perforations will be added to the 7" casing at ,....11,755 MD. A drillable bridge plug will be set below the bottom perforations at ,....11,900' MD and a drillable cement retainer will be set between the perforations at ,....11,870'. Coil tubing will stab into the cement retainer, squeeze cement out the bottom perforations, up the 8-1/2" hole behind the 7" casing, and back into the 7" through the upper perforations. Case 3. Circulation to the surface cannot be established and the leakoff rate is absorbed by the reservoir. Perforations will be added to the 7" casing at ,....11,755 MD. A drillable bridge plug will be set below the bottom perforations at ,....11,900' MD. Coil tubing will be used to squeeze cement out the 7" and down to the formation. Aggregate may be added to the cement mix. · The cement job will be pressure tested after a sufficient curing time has passed. · The cement, bridgeplug and retainer will be milled out by the drilling rig. · A follow-up cement bond log will be run. ~. The d~illing rig will complete the well. --I ~ ai Hunt) Wells Engineer CPAI Drilling and Wells HH/skad ) ) ConocóP'hillips ConocoPhillips Alaska, Inc. Post Office Box 100360 , Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 28, 2003 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approvéil- Temporary Shutdown of Drilling Operations CD2-55 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for Sundry Approval to temporarily shutdown drilling operations on well CD2-55. The well encountered drilling fluid losses at 12,220 ft. MD or 7230 ft. TVD. The losses were controlled and 7" casing was set at 12,210 ft. MD. Due to the losses and lack of pressure differential observed during cementing operations, a cement quality log was run per regulation 20 AAC 25.30 (5). The CMT log confirmed the absence of adequate zonal isolation through the Alpine C sand. It is requested that dispensation be granted for suspension of this well, to allow non-rig remediation. Doyon rig 19 would then move to CD2-40 and commence drilling the horizontal injector. It is planned to return to CD2-55 and finish drilling the well after all isolation issues have been addressed. Please find attached Form 10-403, Application for Sundry Approvals, and the proposed program for securing the well. If you have any questions or require further information, please contact Zane Kuenzler at 265-1308 or Chip Alvord at 265-6120. ," \..... T'\. ,\ ,þ.~, \, ~,',_ . ~~,_ , rt I', . ,\\" \'\,. '\ t .',' c-...., \.t.....~~,~ ¡",,'\~\Ð"~'.c~ \"",1( '........ "-'Q~,,,.~,:c~u ""-k. \"'~'- '~5" '\J..J t '" - "'-V ~:.."\ c. \"' "".) \",;\ \,~. . , ~" ~t ",--, \ \_ ~ C" "-~ --- ì ~ \" \ ~\''i' þ..,\-,~lJ¡~'~\"i,I;".J'~~,t.1 ~V.J,\>~+J'~ \'J f,'~, '-,-~,.. '\ \\~~ -r .' \. ~ "",'. ~>("-,>,Jf(-_(f_'"U?-_ '"C~. \ "':>D $~ V\~~"' ''-,j(:'S. r~ ~'-J "'> ~Q-_(_~.... ~s,., ~ ~~ ,( ~ ,:~<.~.~.~~~~~~~~"'\~ \a:.~~~ ~ '~~ ~~1r~ ~~\ ~'ê. ~'i0 \1è""~ <'}L\,,^Qrî\--\-:-\!~''t"'> G\>~~,?~~-\..~,: R'è\CJ5\~~'Þö''-P~'' M '\-,? c \ \C) ~ ""a ,,=-~( (, \~ ~ ',; L~'\ \ ') v.::P ,:-"- ,,~Qç ú... \~ '-~ ~~ \3.~~ \. ~ l, \ " (I. . . ' ~ $<)., ~ C.D\ \ \ > ~~\;,\, ~"ç, .~.~ ~C>:- ~'::'; (( \\-c\~\ö'l · ,,\<të. ''I ~,\\ ~ S0\ \- ,., \c\.~J~EIs,:V;;;'::'o Q\>.þ.,. ~~2-51 Well File I Sharon Allsup Drake ATO 1530 J! '.. q. 'T] ,.G2!1\ \ '1/)"'1 Chip Alvord A TO 868 Cliff Crabtree A TO 848 Steve Moothart A TO 844 Sincerely, ~~~b} Drilling Engineer Attachments Nancy Lambert Lanston Chin Alas¡·,::' Anadarko - Houston Kuukpik Corporation ) ) 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown 0 o o Abandon Suspend Perforate 0 o o Repair well 0 D o Alter casing 0 o Plug Perforations Stimulate Change approved program Pull Tubing Perforate New Pool 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): 52' RKB 8. Property Designation: ADL 380075 / 387207 / ALK N/A 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 Variance 0 Annular DisPos,O Time Extension 0 Other 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 203-118 6. API Number: 50-103-20463-00 9. Well Name and Number: C02-55 Perforation Depth TVD (ft): N/A Packers and SSSV MD (ft): packer @ 8398', nipple @ 495' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJO 10. Field/Pools(s): Alpine PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) 7321' MD TVD 11. Total Depth MD (ft): 12220' Casing Structural Conductor Surface Intermediate Production Total Depth TVD (ft): Effective Depth MD (It): 7321' 12220' Length Size 77' 2760' 30" X 16" 1141 1141 9.625" 2797' 2406' 7" 12210' 7320' 121731 Liner Perforation Depth MD (ft): N/A Packers and SSSV Type: Tubing Size: N/A 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Yes Commission Representative: T. Maunder 17, I hereby certify that the foregoing is true and correct to the best of m~' knowledge. Printed Name C. Alvord <-..... Title Signature Z -:- lJ' 71-...-1 f 0 or Phone 7/28/2003 Date: 7/28/03 Contact Alpine Drilling Team Leader 265-6120 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test D Location Clearance 0 Junk (measured): Burst Collapse Tubing Grade: N/A Tubing MD (ft): N/A Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Zane Kuenzler @ 265-1308 'Z¡:JJG,',«ft Date 7/2-9/03 SUndry:;;,.. a I \ \. r"-'~'" ¡.....~ / rt_:!!~~ ¡:';'"--"\. Other: ~~~'to..\ 'uNL'Io..\'O\'-S \ð ~ OJ'\,\O~ \Jì ~ ,-\~Y:>--'SI)~' ;:)p~\\~\~~~~J \ ~ \ }U L L-' . .' L J U " Subsequent Fonn Required: l--\'(I ~ ~ ,~.-- '-~ \C'" \ '--"-~ \ ~ ¿, " , Approved by: BY ORDER OF THE COMMISSION COMMISSIONER OrIginAl ~~ ~J Sarah PalIn ORIGINAl ;." RBDMS BFt Form 10-403 Revised 2/2003 i~ PI Date: ;l'-c:2 ~-t23 jUt S <J 1.IIß SUBMIT IN DUPLICATE ) ') Temporary Halt to Drilling Operations Program: 1. POOH, lay down 4" drillpipe. 2. Displace with 8.8 ppg brine and sufficient diesel for 2000' :MD freeze protection. 3. Nipple up tree and pressure test to 2500 psi. 4. RDMO Doyon 19. 5. Change out tree with 7-1/16" fully opening valve, to allow access for non-rig remediation. 6. Return to CD2-55 when all zonal isolation issues have been resolved. ) ~.,j "F .1., Ä\ TI ¡-Ç r[ì II~ (l0~ ffi\ ~ If( 111\ / ell) lLiì1 u.l, \...0 l LID ~1lUæ; ~U~ AI1ASKA OIL AND GAS / CONSERVATION COMMISSION ¡ ¡ ) FRANK H. MURKOW5KI, GOVERNOR 333 W. -pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 C. Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit, CD2-55 ConocoPhillips Alaska, Inc. Permit No: 203-118 Surface Location: 2113' FNL, 1497' FEL, SEC. 2, TIIN, R4E, UM Bottomhole Location: 1131' FSL, 2346' FWL, SEC~ 14, TIIN, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~'7 ~S Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED thisZ 7 day of June, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section . 1a. Type of Work: Drill ~ Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: N6A- ¿lz." Iz..001 ') } STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 20.005 Redrill U ExploratoryU Development Oil U Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: U Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 CD2-55 6. Proposed Depth: 12. Field/Pool(s): MD: 17578' TVD: 7370' Colville River Field 7. Property Designation: 1 b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 2113' FNL, 1497' FEL, Sec. 2, T11N, R4E, UM Top of Productive Horizon: 1038'FSL,377'FEL,Sec.10, T11N,R4E, UM Total Depth: 1131' FSL, 2346' FWL, Sec. 14, T11N, R4E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371738 16. Deviated wells: Kickoff depth: 400 18. Casing Program Size Hole 42" Casing 16" 9.625" 12.25" 8.5" 7" N/A 4.5" 19 Total Depth MD (ft): Casing Structural Conductor Detailed Operations Intermediate Production Liner Perforation Depth MD (ft): ALK 380075 / 387207 8. Land Use Permit: Alpine River Pool 13. Approximate Spud Date: 7/7/2003 ./ ADL N/A 9. Acres in Property: 2560 14. Distance to Nearest Property: 377' FSL Sec. 10 10. KB Elevation 15. Distance to Nearest y- 5974244 Zone- 4 (Height above GL): 52 feet Well within Pool: C02-58, 31 17. Anticipated Pressure (see 20 AAC 25.035) / Max. Downhole Pressure: 3335 psig / Max. Surface Pressure: 2598 psig Setting Depth Quantity of Cement Top Bottom c. f. or sacks MD TVD MD TVD (including stage data) 37' 37' 114' 114' 37' 37' 2835' 2390' 523 sx AS Lite & 230 sx LiteC rete 37' 37' 1207~' 7322' 190 sx Class G 32' 32' 11160' 7143' ft. Maximum Hole Angle: 90° Specifications Weight Grade Coupling Length 62.5# H-40 Weld 77 36# J-55 BTC 2798 26# L-80 BTC-M 12042 12.6# L-80 IBT-mod 11128 PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Length Cement Volume MD TVD Size Perforation Depth TVD (ft): 20. Attachments: Filing Fee 0 Property Plat D BOP Sketch U Diverter Sketch 0 Drilling Program ~ Seabed Report D Time v. Depth Plot U Drilling Fluid Program 0 Date: Shallow Hazard Analysis U 20 AAC 25.050 requirements [2] 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best òf my knowledge, Printed Name Signature C. Alvord /J~,~OZ Contact Zane Kuenzler @ 265-1308 Title Alpine Drilling Team Leader Phone 2 cÞ S" - G ( 2.." Date' ll.4-l ".5 PreDared bv Sharon Al/suD-Drake Commission Use Only Permit to Drill API Number: Permit Approval . Þ See cover letter Number: 203-11g' 50- /03- 20 Y~3-Cð Date: 0 41 . S for other requirements Conditions of approval: Samples required 0 Yes ~o Mud log required 0 Yes .~ No Hydrogen sulfide measures 0 Yes ~ No Direction~1 survey required RYes 0 No T-e.-st- "Bo VË tø ~OOO P V:. ¡\-\I:' T) ~~t ?,~{;.,~ t"j v-eQ~~~4<:,.,.", ¡¡¡'"'''' I,: Other: Pw ~A-1\-'- 1.~, O~~ (k](1...)) a.iVe.-v t-~...,.. .,.ve.--6~t'-<..~t- ~ ~ ~,~¢4t:~j fe.v ~ ÆttL 7&&..irldl?e!(t4WdðÎÌe<.L-jL~ 4~ W4,~ ~iN'-~ i ~ wcJ,,~ ..l,_ -vi'" 19 1;Jf. U BY ORDER OF J U N :t 5 Approved by: ~ Ruedrich COMMISSIONER THE COMMISSION Date: Form 10-401 Revised 2/2003, Submit in Duplicate f' 'i~~~ Z003 ~~ê'3 ,: !~~ar - I y, I "01-;'fríL.:1.¥~( L-¥~ Lc::Jw 0\J~ OF 'i \.., u , It ff,.0 , .~ C02-55 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) ,12-1/411 Hole 19-518" CasinÇJ 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 ~-1/2" Hole 17" CasinÇJ Interval Event Risk Level Abnormal Pressure in low. Surface Formations >2000' TVD Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low Mitigation Strategy Monitor cellar continuously during interval. Gyro single shots, traveling cylinder diagrams Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries Mitigation Strategy BOPE drills, Keep mud weight above 9.6 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 7001 of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/8" Hole 1 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 (ECD) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 8.8 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers i'; "r " ') ) Alpine: CD2-55 Procedure 1. Move on Doyon 19. / ---/ 2. Drill 12- %" hole to the surface casing point as per the directional plan. 3. Run and cement 9-5/8" surface casing. /' 4. Install and test BOPE to 5000 psi. /' 5. Pressure test casing to 2500 psi. / 6. Drill out 20' of new hole. Perform leak off test. 7. Pick up and run in hole with 8-1/2" drilling BHA. 8. Drill8-Y2" hole to intermediate casing point in the Alpine Sands. (LWD Program: GR/RES/PWD) 9. Run and cement 7" casing as per program. Top of cement> 763 feet MD above Alpine reservoir. Carry /' out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protectcasinQ annulus and casing. 10. BOPE test to 5000 psi. 11. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. /- 12. Drill 6-1/8" horizontal section to wel TO (LWD Program: GR/RES/PWD). 16. Circulate the hole clean and pull out of hole. 17. Run 4-Y2, 12.6#, L-80 tubing with DB nipple, gas lift mandrel(s), and packer. Land hanger. /' 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. // 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi 130 mins. /' 22. Set BPV and secure well. Move rig off. OR f'.,~ 111./ ,~ , " -",' ~'.,:::,; ~I,~ IUI~ ~~ ,i ~ .~ ", ".:~ , . ¡ \/~ ~ '. ;,1:21 Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.05Q._(b)) is provided in following attachments. C02-58 will be the closest well to C02-55. Well separation i~3W ft at 200 ft MD. Accounting for survey uncertainty, the ellipse-to-ellipse separation is 27.3 ft at 200 ft Mer: DrillinÇl 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 PumpinÇl Operations: Incidental fluids developed from drilling operations on well CD2-55 will bJ~ injected into a permitted annulus on C02 pad or the class 2 disposal well on CD1 pad. /' The C02-55 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. Upon completion of CD2-55 form 10-403, Application for Sundry Operations, will be filed. Annular pumping ..-- of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. 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 Colvill~ Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2390') + 1,500 psi = 2,990 psi Pore Pressure = 1,081 psi Therefore Differential = 2991 - 1081 = 1910 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 850;0 of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi 0, ri~c r~ ,,~ d J.r L , ) ) CD2-55 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 V2" Section - 6 1 18" point -12 %" Density 8.8 - 9~6 ppg 9.6~ 9.0-9.3 ppg PV 10 - -'" 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 ± 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 ± 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. 0.0' ~)" c.,~ ~, ! :} i' '.1 ,',1 !" 1,f ~1 i ,I í:j i~,~_ CD2~55 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. / gal) (psi) (psi) 16 114/114 10.9 52 53 95/8 2835 I 2390 14.5 1081 1563 7" 12079 I 7322 16.0 3313 2598 ".- N/A 17758 / 7370 16.0 3335 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]0 Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft o = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] 0 = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1081 - (0.1 x 2390') = 842 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] 0 = [(14.5 x 0.052) - 0.1] x 2390 = 1563 psi OR ASP = FPP - (0.1 x D) = 3313 - (0.1 x 7322') = 2581 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3335 - (0.1 x 7369') = 2598 psi 0,", '''' I!,; ,,''', I " I il ~..Ä,ij¡".I " ~I~) ) ) Colville River Field C02-55 Injection Well Completion Plan 16" Conductor to 114' Updated 06/09/03 . 4-1/2" Camco DS Nipple (3.812') at 2000' TVD = 2303' MD 9-5/8" 36 ppf J-55 STC Surface Casing @ 2835' MD /2390' TVD cemented to surface Packer Fluid mix: 9.? PPQ KCI Srine with ?OOO' TVD diesel cap 4-1/2" 12.6 ppf L-80 1ST M tubing run with Jet Lube Run'n'Seal pipe dope TubinQ suspended with diesel Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Cameo DB6 nipple 2303' 2000' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco KSG2- GLM (3.909" ID) 1 0948' 7058' 4-1/2", 12.6#/ft, 1ST-Mod Tubing (2) Baker S3 Packer wI millout extension 11048' 71001 4-1/2", 12.6#/ft, 1ST-Mod Tubing (1) HES "XN" (3.725")-68.2° inc 11148' 7139' 4-1/2", 12.6#/ft, 1ST-Mod 10' pup joint WEG 11160' 7143' / TOe @ +1- 10950' MD 17059' TVD (>763' MD above top Alpine) Camco KBG-2 GLM (3.909" DRIFT ID) wi dummy Baker S3 Packer WI millout extension at +1- 11048' MDI \'~~~1 00' TVD <200' TVD from top of Alpine ~""':"'f:~~"j;c'i~ Well TD at 175781 MD I 73701 TVD Top Alpine at 11713' MD / 7291' TVD 7" 26 ppf L -80 STC Mod Production Casing @ 12079 / 7322' TVD @+/- 872 O f·~ p .1\, ~~, ~A L ' ~ ' ", ~ - , " , ,"' ,) i ' " '~. , ~1 \,,~ cd ;1 '," 'J ' Alpine, CD2-55 Well Cementing Requirements 95/8" Surface Casin~ run to 2835' MD / 2390' TVD Cement from 2835' MD to 2335' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2335' to surface with Arctic Set Lite 3. Assume 300 % excess annular volume in permafrost and 50 % excess below the permafrost (1561' MD). Lead slurry: System: Tail slurry: System: (2335'-1561') X 0.3132 ft3/ft X 1.5 (50% excess) = 363.6 ft3 below permafrost 1561' X 0.3132 ft3/ft X 4 (300% excess) = 195~bove permafrost Total volume = 363.6 + 1955.6 = 2319.2 fe =~x @ 4.44 fe/sk 523 Sx ArcticSet Lite 3 @ 10.7 PPO yielding 4.44 fe/sk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% SOOI accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 felft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 ft3/ft = 34.7 fe shoe joint vol~k~ Total volume = 234.9 + 34.7 = 269.6 ft3 =~,( @ 1.17 ft3/sk 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % SOOI accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casin~ run to 12079' MD I 7322' TVD Cement from 12079' MD to +/-10950' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40 % excess annular volume. Slurry: System: (12079' - 10950') X 0.1268 ft3/ft X 1.4 (40% excess) = 200.4 fe annular vol. 80' X 0.2148 fe 1ft = 17.2 ft3 shoe joint volu?:-'I Total volume = 200.4 + 17.2 = 217.6 ft3 =>~"Sx @ 1.15 ft3/sk 190 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fel 1 By Weight Of mix Water, all other additive.s are BW~,..,. ..1::,ì"m.,.' eR-~ .,? I" ~JMM 4:1'\ Sperry-Sun Drilling: Services _"":7 Alaska North SIOp8~@'i,"" North Slope, ¡J.láska CD2- (Wþ(J3) ~ 'C) :J'<c3 c;) posal Report .:-~ ,-- :ì 6 June, 2003 Surface Coordinates: 5974244.05 N, 371738.44 E (7010 20' 16.3219" N, 15110 02' 26.6518" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 52.0Off above Mean Sea Level ---- =t~:Jr!:I. 1\I'·Y:-§I .., Q}Bl¡;J;JBI§:'::,::rf{.:B:'2I~:lr. ~.mlhit.m:fl ë:"Ò"pany Proposal Ref: pro250 ~ End Oir, Start sail.@ 42.9°: 1620 ft MO,1500 ftTVO 00.00 , ------------~---_....-_- nù¡:" €tmalro~[ 1 ')<;2. DO 9 Sl8in Cs Pt ,J ~5t8'¡ Casing Pt ,.. Drill out 8-112" Hole: 2835 ft MD, 2390 ft TVD ~~~:~:M D ~ 3500.00 Allow natura! Build of 0.75°/1 OOft ,Ç..,"\ 3000 - ¡I Begin Dir@4.0000/100ft:4687.91ftMD,3581.94ftTVD- 3000 ~-<::.;,.:::';:~ . 4o/íOO \\ 0~ "ê;f 0 g , D\f @ 1\J'iJ <~0' ç,- :\~ g A\\' ßeQ\í\ 72.91 1t ...t:> 91° ~ " I \ sail' í036 '. "\'Lûõ9t\t~~~·TÎ·\N-f\"E. .JiY·Çyv <:':J~'ò "5 ¡ E-í\Ò 0 \fI \)\1. "'\.. see K'-. ,,<: r¡"Ý) c /. i~\) ee9 iJ\1\ he. 'e'. r,,'? '};':> :: Qj 7900.00 íarg:''J~r\. fNL, 239. . 6-'\/'ò" \,\0\ v;¡'ò'<:i.{§>· ~Q 1'j I . ,(451· ße9\t\ 1'1t> .:... ~ !1-" '" (f) I ~ 9 ~\ ,., 1'2.90 \\ <2< ,$;/ 'bÝ) . ç:F' 6000 - ¡ i~O~~.~tMD ! , L1~~~;0 \\ ~O, cl~(; ~... -:,:\~~-. 7322,01' TVD }b200.00 "fß 'òtf-. Q ~ D~ eo I . ,'f ~ ",:>\;' Alpine D. 726.fJ){} . 2100.00 13700.00 15300.06 16900,6<> ,. . ~ ~ ~. - ~ """1T"""" -. - Xï;;'i;~¡,-(~ ¡]ý-¡:(¡f.)"''''-'. U~2;55,,'~::~i:'..,\ "I CD2-55 (wp03) ,. o ScaJe: 1inch = 3000ft 3010~¿~c~.:jr;+~:j;,'"7;;;;:~'¡'\3~Òg n 90100 ~:~~:'j~:~;iii~~: ./ ConocoPhillips ConocoPhillips Alaska, Inc. Colville River Unit Alpine (CD2 Pad) CD2-55 (wp03) ~i '+ Well: Reference is True North Current Well Properties C02-55 Horizontal Coordinates: Ref. Global Coordinates: 5974244.05 N, 37173B.44 E Ref Structure: 19B.47 S, 24.35 .E Ref. Geographical Coordinates: 70020' 16.3219" N, 151002' 26.651 B" W 2113' FNL & 1497' FEL, SEC 2 - T11 N - R4E a RKB Elevation: North Reference: Units: 52.00f! above Mean Sea Level True North Feet (US Survey) ~?1 Vertical Section (2113' FNL, 1497' FEL) _ _~-4.I ~~~.~ o 3000 6000 9000 /"HI (::>11:"{ n7' FNI .i 14Q7' ;::F¡ ~F(": ') - T ~ 1 N - R4F1 I o --:: Begin Oir @ ~1ÕOft (in 12=1/4" Hole): 3õõtïMÕ, 3'õõft'Tvo- - - - - 0 ::J (j) ~ N l1) II OJ ~ ç£ ~ ë. Q) o ~ u t Q) > DrillQuest 3,03.02.002 Eastings(2113' FNL, 1497' FEL) -300n 0 I Scale: 1 inch = 3000ft I SHL (2113.07' FNL & 1497' FEL, SEC 2 - T11N ··.þ14E).._,. 0------ . Begin Dir @ 3.25c/100ft (in 12-1í4" Hole) : 300ft MD, 300ft End Dir, Start Sail @ 42.90: 1620 ft MD,· 500 ft TVD 9-5/8" Casing Pt ... Drill out 8-1/2" Hole: 283511 MD, 2390 ft TVD Allow natura! Build 0" 0.75°/100ft o Begin --"'&3e -of Perin/lfr0st \60Lo ;~i~~~;t 2390'j' TVD 3800.00 ¡ - -3000 -3000 - o o o CO) I' .J:::: Ü C ::J LU LL r-.. ~ (¡j ~ (f) - -6000 -I z LL 7in Csg Pt 12079.00' MD 7000.00 7322.01' TVD ·~:=~~~~~~:-:-,1fJþl{fFfPn~ FL· '~·"¿'~;'ï;~ .~?~:~~¡~':;; 7325.ß9.:2.{;f! TH), 51 ·-r!!5.(>J i1' <=d 1- -9000 ~ ~ 7339.68 I ~ CD::-55 Joe! J ~% ,; ;;;;~lj(~~(i:l'~~/l~f;::ij; S. 2131.98 w Target Toe: 15863.8ft MD, 7356.5511 TVD b353.67 I {2824.47' FNL, 3639.33' FEL. Sec. 14-T11 N-R4E} I -12000 - - -12000 TO at 17568.52 f tMD,7253.88 ftTVD (" 500ft extensi '" C\I V; 0) c: :.ë: t:: o Z Target (Heel) Begin Dir, 12069 tt MD, 7291 ft (4576.33ft FNL, 239.91ft FEL Sec10-T11N-R4E 7" Csg Pt ... Begin 6-1/8" Hal 12070 11 M D, 7290 ft TVD -9000 - 7367.66 I Scale: 1 inch = 3000ft -3000 o Eastings(2113' FNL, 1497' FEL) S, 21313S ;1 spel'I'Y-SUI1 ~l.Bl~j::..I·r!t§=M'- ~J~J~L\lIç~§_~ .À H>i!lIîburton c:ompan)' DrillQuest 3.03.02.002 Page 2 of 11 6 June, 2003 - 11 :20 Sperry-Sun Drilling Services Proposal Report for CD2-55 (wp03) Revised: 6 June, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings EastinQ;§" Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) ,(U) ""11£1[;<> CO/100ft) 0.00 0.000 0.000 -52.00 0.00 0.00 N 0.00 E 5974244.05 N 371738.44. E 0.00 SHL (2113.07' FNL & 1497' FEL, 5974244.05 ~J"' SEC 2 - T11 N - R4E) 100.00 0.000 0.000 48.00 100.00 0.00 N 0.00 E ' 371738.44.E 0.000 0.00 200.00 0.000 0.000 148.00 200.00 0.00 N 0.00 E 5974244.05 N, 371738.44 E 0.000 0.00 300.00 0.000 0.000 248.00 300.00 0.00 N 0.00 E 5974244.05 N .;~i;jl1738.44 E 0.000 0.00 Begin Dir @ 3.25°/1 OOft (in 1" -</4" 400.00 3.250 209.000 347.95 399.95 2.48 S 1'~~;!~ 371737.02 E 3.250 1.54 Hole) : 300ft MD, 300ft TVD _' 500.00 6.500 209.000 447.57 499.57 371732.78 E 3.250 6.16 600.00 9.750 209.000· 546.55 ,598.55 371725.72 E 3.250. 13.83 700.00 13.000 209.000 644.58 696.58 21':ltJew 5974204.91 N 371715.86 E 3.250 24.54 a 800.00 16.250 209.000 741 .32 793.32 34.1 Šf"ilk 5974183.04 N 371703.25 E 3.250 38.26 900.00 19.500 209.000 836.48 888.48 49.02 W 5974156.46 N 371687.91 E 3.250 54.93 ~ . ~-1 '. _1J 1000.00 22.750 209.000 929.75 981".75 . t19.gS;<S 66.49 W 5974125.25 N 371669.90 E 3.250 74.50 ~Çc:J.~~ !iF 1100.00 26.000 209.000 1020.83 1072.83 "šffãg S 86.50 W 5974089.50 N 371649.28 E 3.250 96.91 ~:'..) 1200.00 29.250 209.000 1109.41:' : 1161.4l 196.60 S 108.98 W 5974049.34 N 371626.12 E 3.250 122.10 .~~ 1300.00 32.500 209.000 119523 1247.23 241.48 S 133.85 W 5974004.90 N 371600.48 E 3.250 149.97 --.:.:.c.. 1400.00 209.000 : 1278.00, 1330.00 290.54 S 161.05 W 5973956.31 N 371572.45 E - ~-:J 35.750 3.250 180.43 ~-~~ ~, 0" . ','::;.¡., 1500.00 39.000 209.000;;;';';, 135~;,,~6 '1¡¡~$;~;1409.46 343.62 S 190.47 W 5973903.74 N 371542.12 E 3.250 213.40 ~.-- 1600.00 42.250 209.000;:;}> 1433E35~' 1485.35 400.56 S 222.03 W 5973847.35 N 371509.59 E 3.250 248.76 1619.90 42.897 209.000 '':i;~tf~ã:bO 1500.00 412.33 S 228.56 W 5973835.69 N 371502.86 E 3.250 256.08 Base of Permafrost 1620.00 42.900 209.000 1448.07 1500.07 412.39 S 228.59 W 5973835.63 N 371502.83 E 3.250 256.11 End Dir, Start Sail @ 42.9° : 1620 ft MD,1500 ftTVD 1690.88 42.900 209.000 1500.00 1552.00 454.60 S 251.99 W 5973793.83 N 371478.71 E 0.000 282.32 Base Permafrost 1700.00 42.900 209.000 1506.68 1558.68 460.02 S 255.00 W 5973788.45 N 371475.61 E 0.000 285.69 '~ 1800.00 42.900 209.000 1579.93 1631.93 519.56 S 288.00 W 5973729.49 N 371441.60 E 0.000 322.67 1900.00 42.900 209.000 1653.19 1705.19 579.10 S 321.00 W 5973670.53 N 371407.58 E 0.000 359.64 2000.00 42.900 209.000 1726.44 1778.44 638.64 S 354.00 W 5973611.56 N 371373.57 E 0.000 396.62 2100.00 42.900 209.000 1799.70 1851.70 698.17 S 387.00·W 5973552.60 N 371339.55 E 0.000 433.59 2200.00 42.900 209.000 1872.95 1924.95 757.71 S 420.01 W 5973493.63 N 371305.54 E 0.000 470.57 2300.00 42.900 209.000 1946.20 1998.20 817.25 S 453.01 W 5973434.67 N 371271 .52 E 0.000 507.54 2400.00 42.900 209.000 2019.46 2071 .46 876.78 S 486.01 W 5973375.71 N 371237.50 E 0.000 544.52 2500.00 42.900 209.000 2092.71 2144.71 936.32 S 519.01 W 5973316.74 N 371203.49 E 0.000 581 .49 2600.00 42.900 209.000 2165.97 2217.97 995.86 S 552.01 W 5973257.78 N 371169.47 E 0.000 618.47 DríllQuest 3.03.02.002 Page 3 of 11 6 June, 2003 - 11 :20 Sperry-Sun Drilling Services Proposal Report for CD2-55 (wp03) Revised: 6 June, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Easting§ Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2700.00 42.900 209.000 2239.22 2291 .22 1055.40 S 585.02 W 5973198.81 N 371135.46E 0.000 655.44 2800,00 42.900 209.000 2312.48 2364.48 1114.93 S 618.02 W 5973139.85 N 371101.44 E 0.000 692.42 2834.84 42.900 209.000 2338,00 2390.00 1135.68 S 629.52 W 5973119.31 N 371089.59 E 0.000 705.30 9-5/8" Casing Pt ... Drill out 8-1/2" Hole: 2835 ft MD, 2390 ft TVD 9 5/8in Casing 2836.21 42.910 209.000 2339.00 2391.00 1136.49 S 629.97 W 5973118.50 N 371089.13 E 0.750 705.81 Allow natural Build of 0.75°/1 2900.00 43.389 209.000 2385.54 2437.54 1174.65 S 65t.12 W 5973080.71 N 371067.33 E 0.750 729.50 3000.00 44.139 209.000 2457.76 2509.76 684;65 W. 5973020.80 N 371032.76 E 0.750 767.07 3100.00 ¿lA.8S9 209.000 2529.07 2581.07 718:64 W 5972960.07 N 370997.73 E 0.750 805.16 3200.00 45.639 209.000 2599.45 2651.45 753:n8W 5972898.54 N 370962.23 E 0.750 843.74 3300.00 46.389 209.000 2668.90 2720.90 787.96W 5972836.22 N 370926.28 E 0.750 882.82 t~:J 3400.00 47.139 209.000 2737.40 2789.40 823.28 W 5972773.11 N 370889.88 E 0.750 922.39 :::''J 3500.00 47.889 209.000 2804.94 2856.94 859.03 W 5972709.24 N 370853.03 E 0.750 962.45 3600.00 48.639 209.000 2871.51 2923.51 S 895.21 W 5972644.60 N 370815.74 E 0.750 1002.98 3700.00 49.389 209.000 2937.10 2989.10 1681.02 S 931.81 W 5972579.21 N 370778.02 E 0.750 1043.98 3800.00 50.139 209.000 3001.69 3053.69 1747.79S 968.81 W 5972513.09 N 370739.87 E 0.750 1 085.45 3900.00 50.889 209.000 3065.28 3117.28 1815.29 S 1006.23 W 5972446.24 N 370701.31 E 0.750 1127.37 . ~~'::...'at 4000.00 51.639 209.000'\< 3127·,85 Y3179.85 1883.51 S 1044.05 W 5972378,67 N 370662.33 E 0.750 1169.74 4100.00 52.389 209.000 " 3189;40 3241 .40 1952.44 S 1082.26 W 5972310.40 N 370622.94 E 0.750 1212.55 ¡-r~ 4200.00 53.139 209.000 ; {i324-9:91 3301.91 2022.08 S 1120.86 W 5972241.44 N 370583.16 E 0.750 1255.79 ~ 4300.00 53.889 209.000 3309.37 3361.37 2092.40 S 1159.83 W 5972171.80 N 370542.99 E 0.750 1299.46 4400.00 54.639 209.000 3367.78 3419.78 2163.39 S 1199.19W 5972101.49 N 370502.43 E 0.750 1343.55 4500.00 55.389 209.000 3425.12 3477.12 2235.05 S 1238.91 W 5972030.52 N 370461.49 E 0.750 1388.05 4600.00 56.139 209.000 3481.38 3533.38 2307.35 S 1278.99 W 5971958.91 N 370420.17 E 0.750 1432.96 4687.91 56.798 209.000 3529.94 3581.94 2371.44 S 1314.51W 5971895.44 N 370383.56 E 0.750 1472.76 Begin Dir @ 4.0000/100ft : 4687.91 MD, 3581.94ft TVD 4700.00 56.700 209.566 3536.57 3588.57 2380.26 S 1319.46 W 5971886.70 N 370378.46 E 4.000 1478.21 4800.00 55.990 214.296 3592.01 3644.01 2450.88 S 1363.45 W 5971816.85 N 370333.27 E 4.000 1519.79 4813.26 55.909 214.929 3599.43 3651 .43 2459.92 S 1369.69 W 5971807.92 N 370326.87 E 4.000 1524.82 4900.00 55.909 214.929 3648.05 3700.05 2518.82S 1410.82 W 5971749.73 N 370284.74 E 0.000 1557.40 5000.00 55.909 214.929 3704.10 3756.10 2586.71 S 1458.24 W 5971682.66 N 370236.17 E 0.000 1594.96 5100.00 55.909 214.929 3760.15 3812.15 2654.61 S 1505.65 W 5971615.58 N 370187.60 E 0.000 1632.52 5200.00 55.909 214.929 3816.20 3868.20 2722.51 S 1553.07 W 5971548.51 N 370139.03 E 0.000 1670.08 OrillQuest 3.03.02.002 Page 4 of 11 6 June, 2003 - 11 :20 Sperry-Sun Drilling Services Proposal Report for C02-55 (wp03) Revised: 6 June, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northings Eastings Northings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) 1ft) (0/10Oft) 5300.00 55.909 214.929 3872.25 3924.25 2790.40 S 1600.48 W 5971481.43 N 370090A6E 0.000 1707.64 5400.00 55.909 214.929 3928.30 3980.30 2858.30S 1647.90W 5971414.35N 370041.89E 0.000 1745.20 5500.00 55.909 214.929 3984.36 4036.36 2926.20 S 1695.32 W 5971347.28 N· 369993.32 E 0.000 1782.76 5600.00 55.909 214.929 4040.41 4092.41 2994.10 S 1742.73 W 5971280.20 N 369944.75 E 0.000 1820.32 5700.00 55.909 214.929 4096.46 4148.46 3061.99S 1790.15W 5Q7121,3:13N "";D~896.18E 0.000 1857.88 5800.00 55.909 214.929 4152.51 4204.51 3129.89 S 1837.57 W 5971146;05N 369847.61 E 0.000 1895.44 '-' 5900.00 55.909 214.929 4208.56 4260.56 3197.79 S 1884.98 W ' '597'1078.97 N 369799.04 E 0.000 1933.00 6000.00 55.909 214.929 4264.61 4316.61 3265.68 S," 19~tJO W~;~xNii~;,5911011:90 N 369750.47 E 0.000 1970.56 6100.00 55.909 214.929 4320.66· 4372.66 3333.5ªi~¡!!ìi;k '197tl~ W '\};;#;&5970944.82 N 369701.90 E 0;000 2008.12 6200.00 55.909 214.929 4376.71 4428.71 3401.48 S 2027:f!q~ 5970877.75 N 369653.33 E 0.000 2045.68 --=<:~:~t~~i;,~· 6300.00 55.909 214.929 4432.76 4484.76 3469.37 S 2074.65 W' 5970810.67 N 369604.75 E 0.000 2083.24 a 6400.00 55.909 214.929 4488.81 4540.81 3537.27 S 2122.06 W 5970743.59 N 369556.18 E 0.000 2120.81 ~. 6500,00 55.909 214.929 4544.86 4596.86- :' ,3605.17 S 2169.48 W 5970676.52 N 369507.61 E 0.000 2158.37 ~~~<"'<,J 6600.00 55.909 214.929 4600.92 4652.92 ' Wi' 3678f67 S 2216.90 W 5970609.44 N 369459.04 E 0.000 2195.93 ~'- "D... 6700.00 55.909 214.929 4656.97\ "'4708.97, 3740.96 S 2264.31 W 5970542.37 N 369410.47 E 0.000 2233.49 ~"~.'" -' ~~... j ... ,. .' I"~,': . - -- 6800.00 55.909 214.929 4713.02:, 4765.02' 3808.86 S 2311.73 W 5970475.29 N 369361.90 E 0.000 2271.05 6900.00 55.909 214.929J' 4769.0'1 4821.07 3876.76 S 2359.14 W 5970408.21 N 369313.33 E 0.000 2308.61 7000.00 55.909 214.929;t;>\ 482&;'l2' ,,;;§;t4877.12 3944.65 S 2406.56 W 5970341.14 N 369264.76 E 0.000 2346.17 ,,_~ 7100.00 55.909 214.929ti;~:;},48~1~17"' 4933.17 4012.55 S 2453.98 W 5970274.06 N 369216.19 E 0.000 2383.73 ~~'-_ 7200.00 55.909 214.929'!;;i~,!~ª7':22 4989.22 4080.45 S 2501.39 W 5970206.99 N 369167.62 E 0.000 2421.29 7300.00 55.909 214.929 4993.27 5045.27 4148.34 S 2548.81 W 5970139.91 N 369119.05 E 0.000 2458.85 7400.00 55.909 214.929 5049.32 5101.32 4216.24 S 2596.22 W 5970072.83 N 369070.48 E 0.000 2496.41 7500.00 55.909 214.929 5105.37 5157.37 4284.14 S 2643.64 W 5970005.76 N 369021.91 E 0.000 2533.97 7600.00 55.909 214.929 5161.42 5213.42 4352.03 S 2691.06 W 5969938.68 N 368973.34 E 0.000 2571.53 "--' 7700.00 55.909 214.929 5217.48 5269.48 4419.93 S 2738.47 W 5969871.61 N 368924.77 E 0.000 2609.09 7800.00 55.909 214.929 5273.53 5325.53 4487.83 S 2785.89 W 5969804.53 N 368876.20 E 0.000 2646.65 7900.00 55.909 214.929 5329.58 5381.58 4555.73 S 2833.31 W 5969737.45 N 368827.62 E 0.000 2684.21 8000.00 55.909 214.929 5385.63 5437.63 4623.62 S 2880.72 W 5969670.38 N 368779.05 E 0.000 2721.77 8100.00 55.909 214.929 5441.68 5493.68 4691.52 S 2928.14 W 5969603.30 N 368730.48 E 0.000 2759.33 8200.00 55.909 214.929 5497.73 5549.73 4759.42 S 2975.55 W 5969536.22 N 368681.91 E 0.000 2796.89 8300.00 55.909 214.929 5553.78 5605.78 4827.31 S 3022.97 W 5969469.15 N 368633.34 E 0.000 2834.45 8400.00 55.909 214.929 5609.83 5661.83 4895.21 S 3070.39 W 5969402.07 N 368584.77 E 0.000 2872.01 8500.00 55.909 214.929 5665.88 5717.88 4963.11 S 3117.80 W 5969335.00 N 368536.20 E 0.000 2909.57 8600.00 55.909 214.929 5721.93 5773.93 5031.00S 3165.22W 5969267.92N 368487.63E 0.000 2947.13 8700.00 55.909 214.929 5777.98 5829.98 5098.90 S 3212.64 W 5969200.84 N 368439.06 E 0.000 2984.69 DríllQuest 3.03.02.002 Page 5 of 11 6 June, 2003 - 11 :20 Sperry-Sun Drilling Services Proposal Report for CD2-55 (wp03) Revised: 6 June, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) ftt} (°/1 o Oft) 8800.00 55.909 214.929 5834.04 5886.04 5166.80 S 3260.05 W 5969133.77 N 368390A9 E 0.000 3022.25 8900.00 55.909 214.929 5890.09 5942.09 5234.70 S 3307.47 W 5969066.69 N 368341.92 E 0.000 3059.81 9000.00 55.909 214.929 5946.14 5998.14 5302.59 S 3354.88 W 5968999.62 N 368293.35 E 0.000 3097.37 9100.00 55.909 214.929 6002.19 6054.19 5370.49 S 3402.30 W 5968932.54 N 368244.78 E 0.000 3134.93 9200.00 55.909 214.929 6058.24 6110.24 5438.39 S 3449.72 W 5968865.46 N 368196.21 E 0.000 3172.49 9300.00 55.909 214.929 6114.29 6166.29 5506.28 S 3497.1 3 W 5968798.39 N 368147.64 E 0.000 3210.05 9400.00 55.909 214.929 6170.34 6222.34 5574.18S 3544.55 W 5968731.31 N 368099.07 E 0.000 3247.61 9500.00 55.909 214.929 6226.39 6278.39 5642.08 S 3591.97 W 5968664.24 N 368050,50 E 0.000 3285.17 9600.00 ' 55.909 214.929 6282.44- 6334.44 5709.9ï"§i 363~;38 W 5968597,16 N 368001.92· E 0.000 3322.73 9700.00 55.909 214.929 6338.49 6390.49 5777 .8TS 3686.80W 5968530.08 N 367953.35 E 0.000 3360.29 c::J 9800.00 55.909 214.929 6394.54 6446.54 5845.77 S 3734.21 W 5968463.01 N 367904.78 E 0.000 3397.85 9900.00 55.909 214.929 6450.59 6502.59 5913.67.8 3781.63 W 5968395.93 N 367856.21 E 0.000 3435.41 =~~1 10000.00 55.909 214.929 6506.65 6558t65 5981 .56.S 3829.05 W 5968328.86 N 367807.64 E 0.000 3472.97 10100.00 55.909 214.929 6562.70 6614.70~ 6049;46 S 3876.46 W 5968261.78 N 367759.07 E 0.000 3510.53 10200.00 55.909 214.929 6618.75 6670.75 6117.36 S 3923.88 W 5968194.70 N 367710.50 E 0.000 3548.09 ) 10300.00 55.909 214.929 ;6674.80 6726.80 6185.25 S 3971.29 W 5968127.63 N 367661.93 E 0.000 3585.65 -" 10387.46 55.909 214.929/; 6723.82 6775.82 6244.64 S 4012.76 W 5968068.96 N 367619.45 E 0.000 3618.50 End of Sail - 10387ft; Begin Dir @ 4°/100ft 10400.00 56.044 214.346 673qt84 6782.84 6253.19S 4018.67 W 5968060.51 N 367613.40 E 4.000 3623.26 ie=- 10500.00 57.220 209.767 F'p!Ã$5:S6 6837.86 6323.95 S 4062.96 W 5967990.52 N 367567.91 E 4.000 3664.82 10600.00 58.557 205.316 6839.03 6891.03 6399.03 S 4102.09 W 5967916.12 N 367527.50 E 4.000 3712.63 10700.00 60.044 200.997 6890.10 6942.10 6478.07 S 4135.87 W 5967837.67 N 367492.38 E 4.000 3766.44 10800.00 61.667 196.811 6938.82 6990.82 6560.68 S 4164.13 W 5967755.56 N 367462.70 E 4.000 3826.00 10900.00 63.415 192.755 6984.94 7036.94 6646.45 S 4186.74 W 5967670.18 N 367438.63 E 4.000 3891.01 11000.00 65.273 188.825 7028.25 7080.25 6734.97 S 4203.58 W 5967581.96 N 367420.27 E 4.000 3961.16 11100.00 67.231 185.014 7068.53 7120.53 6825.82 S 4214.59 W 5967491.32 N 367407.72 E 4.000 4036.12 11200.00 69.277 181.313 7105.59 7157.59 6918.53 S 4219.69 W 5967398.70 N 367401.03 E 4.000 4115.50 11300.00 71 .399 177.713 7139.25 7191.25 7012.68 S 4218.87 W 5967304.56 N 367400.24 E 4.000 4198.93 11400.00 73.589 174.202 7169.34 7221.34 7107.78 S 4212.13 W 5967209.35 N 367405.35 E 4.000 4286.00 11500,00 75.835 170.771 7195.71 7247.71 7203.39 S 4199.50 W 5967113.54 N 367416.34 E 4.000 4376.29 11570.51 77 .448 168.393 7212.00 7264.00 7270.85 S 4187.10 W 5967045.88 N 367427.59 E 4.000 4441 .64 Top Alpine 0 Alpine 0 DrillQuest 3.03.02.002 Page 6 of 11 6 June, 2003 - 11 :20 Sperry-Sun Drilling Services Proposal Report for CD2-55 (wp03) Revised: 6 June, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Easting§" Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) {!l)'+~IJI¡\h (0/1 OOft) 11600.00 78.129 167.407 7218.24 7270.24 7299.04 S 4181.05 W 5967017.60 N 367433.15 E 4.000 4469.35 11700.00 80.462 164.100 7236.82 7288.82 7394.25 S 4156.87 W 5966921.98 N ' '367455~7t E 4.000 4564.73 11713.40 80.777 163.661 7239.00 7291.00 7406.95 S 4153.20 W 5966909.22 ~, 367459.16E 4.000 4577.66 Top Alpine C ......;,:%~~;:::;<:, Alpine C 11800.00 82.826 160.839 7251.35 7303.35 7488.57 S 4127.06 W 5966827.17N"",¡~7483.89 E 4.000 4661 .97 11900.00 85.213 157.611 7261.77 7313.77 7581.54 S 4091.79 W 5966733.61 N; "w"3'S7517.57 E 4.000 4760.60 40~1!,21 W -- '5.96664r.n N '-' 12000.00 87.614 154.406 7268.03 7320.03 7672.70 S 367556.58 E 4.000 4860.13 12078.24 89.499 151.906 7270.00 7322.00 7742.47 S 4011;~0 W'@wwiW;;5966571.40 N 367590.70 E 4.000 4938.31 Target (Heel) Begin Dir, 12078 ft M[ 7322 ft TVD (4576.33ft FNL, 239;9- FEL, Sec1 0- T11 N -R4E 'C:) 12079.00 89.499 151.906 7270.01 7322.01 5966570.72 N 367591 .05 E 0.000 4939.07 7" Csg Pt... Begin 6-1/8" Hole: 120' ft MD, 7322 ft TVD --.r:J 7322:19' 7in Casing ~ 12100.00 89.499 151.906 7270.19 4005.65 W 5966552.03 N 367600.62 E 0.000 4960.07 ~~~ 12200.00 89.499 151.906 7271 .06 7323.06 ' 3958.56 W 5966463.02 N 367646.19 E ¡-Ç'" -, 0.000 5060.07 -~.: .) ~~- ~.-'J 12300.00 89.499 151.906 7271.94 7323.94 7938.10 S 3911.47 W 5966374.01 N 367691.77 E 0.000 5160.06 12400.00 89.499 151.906 7272::81 7324.81 8026.32 S 3864.38 W 5966285.01 N 367737.34 E 0.000 5260.06 12500.00 89.499 151.9060;~~ 7273.69:' }325.69 8114.53 S 3817.29 W 5966196.00 N 367782.91 E 0.000 5360.06 ~ 12600.00 89.499 151.906: ' 727 4.56>l~-1~iii>7326.56 8202.75 S 3770.20 W 5966106.99 N 367828.49 E 0.000 5460.05 ti "'-.--- 12700.00 89.499 151.906 7275~fJ4 7327.44 8290.96 S 3723.11 W 5966017.99 N 367874.06 E 0.000 5560.05 ,vtk:;j~'-"" 12800.00 89.499 151.906 7276.31 7328.31 8379.17 S 3676.02 W 5965928.98 N 367919.64 E 0.000 5660.05 12900.00 89.499 151.906 7277.19 7329.19 8467.39 S 3628.93 W 5965839.97 N 367965.21 E 0.000 5760.04 13000.00 89.499 151.906 7278.06 7330.06 8555.60 S 3581.84 W 5965750.96 N 368010.78 E 0.000 5860.04 13100.00 89.499 151.906 7278.93 7330.93 8643.82 S 3534.75 W 5965661.96 N 368056.36 E 0.000 5960.03 13200.00 89.499 151.906 7279.81 7331.81 8732.03 S 3487.66 W 5965572.95 N 368101.93 E 0.000 6060.03 '-~ 13300.00 89.499 151.906 7280.68 7332.68 8820.25 S 3440.57 W 5965483.94 N 368147.51 E 0.000 6160.03 13400.00 89.499 151.906 7281 .56 7333.56 8908.46 S 3393.48 W 5965394.94 N 368193.08 E 0.000 6260.02 13500.00 89.499 151.906 7282.43 7334.43 8996.68 S 3346.39 W 5965305.93 N 368238.65 E 0.000 6360.02 13600.00 89.499 151.906 7283.31 7335.31 9084.89 S 3299.30 W 5965216.92 N 368284.23 E 0.000 6460.01 13700.00 89.499 151.906 7284.18 7336.18 9173.10 S 3252.21 W 5965127.92 N 368329.80 E 0.000 6560.01 13800.00 89.499 151.906 7285.06 7337.06 9261.32 S 3205.12 W 5965038.91 N 368375.38 E 0.000 6660.01 13900.00 89.499 151.906 7285.93 7337.93 9349.53 S 3158.03 W 5964949.90 N 368420.95 E 0.000 6760.00 14000.00 89.499 151.906 7286.80 7338.80 9437.75 S 3110.94 W 5964860.89 N 368466.52 E 0.000 6860.00 14100.00 89.499 151.906 7287.68 7339.68 9525.96 S 3063.85 W 5964771.89 N 368512.10 E 0.000 6960.00 14200.00 89.499 151.906 7288.55 7340.55 9614.18S 3016.76 W 5964682.88 N 368557.67 E 0.000 7059.99 Dri/lQuest 3.03.02.002 Page 7 of 11 6 June, 2003 - 11:20 Sperry-Sun Drilling Services Proposal Report for CD2-55 (wp03) Revised: 6 June, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Rate Section Comment (tt) (tt) (tt) (tt) (tt) (ft) (0/100tt) 14300.00 89.499 151.906 7289.43 7341 .43 9702.39 S 2969.67 W 5964593.87 N 368603.25 E 0.000 7159.99 14400.00 89.499 151.906 7290.30 7342.30 9790.61 S 2922.58 W 5964504.87 N 368648.82 E 0.000 7259.98 14500.00 89.499 151.906 7291.18 7343.18 9878.82 S 2875.49 W 5964415.86 N 368694.39 E 0.000 7359.98 14600.00 89.499 151.906 7292.05 7344.05 9967.03 S 2828.40 W 5964326.85 N 368739;97 E 0.000 7459.98 14700.00 89.499 151.906 7292.92 7344.92 10055.25 S 2781.32 W 5964237.85 N ;(p68785.54 E 0.000 7559.97 14800.00 89.499 151.906 7293.80 7345.80 10143.46 S 2731~.23 W 5964148.84 N 368831.12 E 0.000 7659.97 14900.00 89.499 151.906 7294.67 7346.67 10231.68 S 268Þ;.14èW 5964059,83 N 368876.69 E 0.000 7759.96 15000.00 89.499 151.906 7295.55 7347.55 10319.89 S 264Ø;P5 Wi 5963970.82 N 368922.26 E 0.000 7859.96 15100.00 89.499 151.906 7296.42 7348.42 10408.11S 2592t"96 W 5963881 .82 1'J 368967.84 E 0.000 7959.96 15200.00 89.499 151.906 7297.30 7349.30 10496.328 2545.8xW 5963792.81 N 369013.41 E 0.000 8059.95 15300.00 89.499 151.906 7298.17 7350.17 10584.54 S 2498.78 W 5963703.80 N 369058.99 E 0.000 8159.95 C) 15400.00 89.499 151.906 7299.05 7351.05 10672.75 S 2451.69 W 5963614.80 N 369104.56 E 0.000 8259.95 15500.00 89.499 151.906 7299.92 7351.92 10760.96 S 2404.60 W 5963525.79 N 369150.13E 0.000 8359.94 ':1:-'< o ..,.) 15600.00 89.499 151.906 7300.79 7352.79 1 0849;18 S 2357.51 W 5963436.78 N 369195.71 E 0.000 8459.94 '~; 15700.00 89.499 151.906 7301.67 7353.67 10937.39 S 2310.42 W 5963347.78 N 369241 .28 E 0.000 8559.93 ~} 15800.00 89.499 151.906 7302.54 7354.54 11025.61 S 2263.33 W 5963258.77 N 369286.86 E 0.000 8659.93 .~ -'"~. 15900.00 89.499 151.906 7303.42 7355.42 11113.82 S 2216.24 W 5963169.76 N 369332.43 E 0.000 8759.93 ~ 16000.00 89.499 151.906 7304.29 7356.29 11202.04 S 2169.15W 5963080.75 N 369378.00 E 0.000 8859.92 ~~-'C_ _ ~~ 16078.33 89.499 151.906 7304.98 7356.98 11271.13S 2132.26 W 5963011.04 N 369413.70 E 0.000 8938.25 Target Toe: 16078 ft MD, 7357 ft X;;· .~ TVD (2824.47' FNL, 3639.33' FEL, Sec. 14-T11 N-R4E) 16100.00 89.499 151.906 7305.17 7357.17 11290.25 S 2122.06 W 5962991.75 N 369423.58 E 0.000 8959.92 16200.00 89.499 151.906 7306.04 7358.04 11378.47 S 2074.97 W 5962902.74 N 369469.15 E 0.000 9059.92 16300.00 89.499 151.906 7306.92 7358.92 11466.68 S 2027.88 W 5962813.73 N 369514.73 E 0.000 9159.91 16400.00 89.499 151.906 7307.79 7359.79 11554.89 S 1980.79 W 5962724.73 N 369560.30 E 0.000 9259.91 16500.00 89.499 151.906 7308.66 7360.66 11643.11 S 1933.70 W 5962635.72 N 369605.87 E 0.000 9359.90 16600.00 89.499 151.906 7309.54 7361 .54 11731.32 S 1886.61 W 5962546.71 N 369651.45 E 0.000 9459.90 16700,00 89.499 151.906 7310.41 7362.41 11819.54S 1839.52 W 5962457.71 N 369697.02 E 0.000 9559.90 16800.00 89.499 151.906 7311.29 7363.29 11907.75 S 1792.43 W 5962368.70 N 369742.60 E 0.000 9659.89 16900.00 89.499 151.906 7312.16 7364.16 11995.97 S 1745.34 W 5962279.69 N 369788.17 E 0.000 9759.89 17000.00 89.499 151.906 7313.04 7365.04 12084.1 8 S 1698.25 W 5962190.68 N 369833.74 E 0.000 9859.88 17100.00 89.499 151.906 7313.91 7365.91 12172.40 S 1651 .1 6 W 5962101.68 N 369879.32 E 0.000 9959.88 6 June, 2003 - 11 :20 Page 8 of 11 DrillQuest 3.03.02.002 2836.21 4687.91 10387.46 11570.51 11713.40 Allow natural Build of 0.75°/1 o Oft Begin Dir @ 4.000°/1 OOft: 4687.91ft MD, 3581.94ft TVD End of Sail - 10387ft; Begin Dir @ 4°/100 ft Top Alpine D Top Alpine C 2391 .00 3581.94 6775.82 7264.00 7291 .00 1136.49 S 2371.44 S 6244.64 S 7270.85 S 7406.95 S 629.97 W 1314.51 W 4012.76 W 4187.10 W 4153.20 W 0.00 300.00 1619.90 1620.00 2834.84 SHL (2113.07' FNL & 1497' FEL, SEC 2 - T11 N - R4E) Begin Dir @ 3.25°/100ft (in 12-1/4" Hole): 300ft MD, 300ftTVD Base of Permafrost End Dir, Start Sail @ 42.9°: 1620 ft MD,1500 ftTVD 9-5/8" Casing Pt ... Drill out 8-1/2" Hole: 2835 ft MD, 2390 ft TVD 0.00 300.00 1500.00 1500.07 2390.00 0.00 N 0.00 N 412.33 S 412.39 S 1135.68 S 0.00 E 0.00 E 228.56 W 228.59 W 629.52 W Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) '~ Comment í{---- Comments ~~"'~~ PI~ned TortuòsitY' i~ 1 .187°/1 OOft and the Directional Difficulty Index is 6.3. The Along Hole Displacement is The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 2113' FNL, 1497' FEL and calculated _?12ng an Azi Based upon Minimum Curvature type calculations, at a, MeasurectDepth of 1757'8:33ft., The Bottom Hole Displacement is 12674.82ft., in the Dir~tion 01:186.459° (True). ~) ~-~-~J All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates areJ;,~lative t, Vertical depths are relative to RKB = 52' MSL. Northings and Eastings are relativ~.f.\g¡~îJ13' FNL, Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone ~f TD at 17578 ft MD ,7370 ft TVf'"' (1500ft extension) 6.132in Open Hole ~ '. 369924.89 E 369970.47E 370016.04 E 370061.61 E ",ßf0097.31 E Alaska North Slope Measured Sub-Sea Vertical Depth Inct. Azlm. Depth Depth (ft) (ft) (ft) 17200.00 89.499 151.906 7314.78 7366.78 17300.00 89.499 151.906 7315.66 7367.66 17400.00 89.499 151.906 7316.53 7368.53 17500.00 89.499 151.906 7317.41 7369.41 17578.33 89.499 151.906 7318.09 7370.09 5962012.67 N." 5961923.66 N : 5961834.66 N,. 5961745.65 N.· 5961675.93N " 12260.61 S 12348.82 S 12437.04 S 12525.25 S 12594.35 S 1604.07 W 1556.98 W 1509.89 W 1462.80 W 1425.92 W 10059.88 10159.87 10259.87 10359.87 10438.19 0.000 0.000 0.000 0.000 0.000 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastin (ft) (tt) Dogleg Vertical Rate Section (0/100ft) Comment North Slope, Alaska Sperry-Sun Drilling Services Proposal Report for CD2-55 (wp03) Revised: 6 June, 2003 DrmQuest 3.03.02.002 Page 9 of 11 9 5/8in Casing 7in Casing 6.132in Open Hole 2390.00 7322.01 <Run-TD> 2834.84 12079.00 <Run-TD> Casing Detail To Measured Vertical Depth Depth (ft) (ft) Profile Penetr'ation Poi n t Measured Vertical Depth Depth Depth Northings Eastings Formation Name (ft) (ft) (ft) (ft) (ft) 1552.00 1500.00 454.60 S 251.99 W Base Permafrost 7264.00 7212.00 7270.85 S 4187.10 W Alpine D 7291 .00 7239.00 7406.95 S 4153.20W Alpine C 7742.48 S 7743.15 S 11271 .13 S 12594.35 S Target (Heel) Begin Dir, 12078 ft MD, 7322 ft TVDf(4576.33ft FNL, 239.91ft FEL, Sec1 0-T11 N-R4E 7" Csg Pt... Begin 6-1/8" Hole: 12079ft MD, 7322 ft TVD Target Toe: 16078 ft MD, 7357 ft TVD (2824.47' FNL, 3639.33' FEL, Sec. 14-T11 N-R4E) TD at 17578 ft 4015.90 W 4015.54 W 2132.26 W 1425.92 W <Suriace> <Suriace> 7370.09 6 June, 2003 - 11:20 <Suriace> <Suriace> 17578.33 Fro m Measured Vertical Depth Depth (ft) (ft) 0.000 359.020 0.000 359.020 0.000 359.020 CasinQ details -~-- ¡j 1500.00 7212.00 7239.00 Formati on Plane (Below Well Origin) Sub-Sea Dip Up-Dip (ft) Angle Dim. 7322.00 7322.01 7356.98 7370.09 Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) F a ~~ """,Df'<.;J Formation Tops 12078.24 12079.00 16078.33 17578.33 Measured Depth (ft) Comments (Continued) North Slope, Alaska Sperry-Sun Drilling Services Proposal Report for CD2-55 (wp03) Revised: 6 June, 2003 Alaska North Slope c::.) £-.;.-, ~tI."¡ J~ Sperry-Sun Drilling Services Proposal Report for CD2-55 (wp03) Revised: 6 June, 2003 Alaska North Slope TarQets associated with this wellpath Target Name Tar g e t&~Bjn"t - TVD Northings ' (ft) '(ft) , 7357.00 Mean Sea Level/Global CoordiElates: 7305.00 Geographical Coordfnates:Ùi!@1 Target Radius::' : 100.00ft CD2-55 (Toe) CD2-55 (Heel) Mean Sea:L'iêv Id'iGoordinãfeS',< , Geogråphical'Ç;oordinates: , Tárget Radius: 6 June, 2003 - 11 :20 Page 10 of 11 ate s Eastings (ft) , '.11270.17 S 2131.98 W 5963012.00 N 369414.00 E 70018'25.4688" N 151003' 28.8324" W 7322.00 7741.87 S 4015.61 W 7270.00 5966572.00 N 367591.00 E 700 19' 00.1646" N 151004' 23.8238" W 100.00ft Target Shape Circle Circle North Slope, Alaska Target Type Current Target ,~/ Current Target ---- DrillQuest 3.03.02.002 <:::) -=-v-".. -.-" GF~ ~ -'I ~__ ¡î-- Sperry-Sun Drilling Services North Reference Sheet for Alpine CD-2 - CD2-55 Alaska North Slope Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot Source: Snyder, J.P., 1987, Map Projections - A Working Manual Projection method is Transverse Mercator or Gauss Kruger Projection Central Meridian is -150.000° Longitude Origin: 0.000° Latitude Origin: 54.000° False Easting: 500,OOO.000ft. False Northing: O.OOOft. Scale Reduction: 0.99990000 Datum is North American Datum of 1927 (US48, AK, HI, and Canada) Spheroid is Clarke - 1866 Equatorial Radius: 6,378,206.400m. Polar Radius: 6,356,583.800m. Grid Coordinates of Well: 5974244.05 N, 371738.44 E Geographical Coordinates of Well: 70° 20' 16.3219" N, Grid Convergence at Surface is -0.980° Magnetic Declination at Surface is 24.587° (27 May, 6 June, 2003 - 11 :20 Grid North True North Â 10.980° I 124.587° I Magnetic North Magnetic Model: Date: Declination: Inclination/Dip: Horizontal Component: Northerly Component: Easterly Component: Vertical Component: Total Field Strength: . Hole Direction Grid North is 0.980° West of TrueNorth (Grid Convergence) Magnetic North is 24.587° East of True North (Magnetic Declination) Magnetic North is 25.567° East of Grid North (Magnetic Convergence) To convert a True Direction to a Grid Direction, Add 0.980 degrees To convert a Magnetic Direction to a True Direction, Add 24.587 degrees To convert a Magnetic Direction to a Grid Direction, Add 25.567 degrees Page 11 of 11 North Slope, Alaska IGBGCF02 27 -May-03 24.587 80.582 9397 n T 8545 n T 3910 nT 56655 nT 57429 nT DrillQuest 3.03.02.002 WEILPATH DETAILS CO2-55 lUg: Doyon 19 Ref. Datum: 52' MSL 52.0001I v.S""". Oñgin Oñgin SLutin¡: AngSc +NI-S +EI-W From TVD 186,46° 0.1)00 0.000 0,000 COMPA>;)" DETAILS Phillips Aluk>. lno. Engir=ring Kupunk CakWation Method: Mininum Curva[D.re Error Sy"""" ISCWSA Scm Mdhod: TRY CyInda Nonh Em>< Surf-= EIipticaI + Casing Warning McIhod: Rules Hued ANTI-COWSDN SETIINGS Interpolation Method: MD Interval: 100.000 Depth RaI1gC from 36.100 To.: 13283.800 MaxinnmRange: 1??oo.000 Refereou: Plan: C02-55 ("I'Û2) Sic< NM LoÛlude Lonpude 7O"W'16.322N ISI"02'2(j,652W WElL DETAILS NortJUn& Eutm¡ 597424-4,05 371738,44 +EJ-W 49,002 +N/·S ·39¡Hð2 Name. Prtlim: cm· From Co.lour To. MD 0-200 200 - 300 300 - 400 400 - 600 600 ~,,'_.~_.- 800 800 1000 1000 - 1500 1500 - 2000 2000 --- 3000 3000 - 4000 Tool CB-GYRO-BS MWD SURVEY PROGRAM Deplh Fm Depth To. Survey /Plan 36.100 700.000 Planned: CD2-55 (wp02) V5 700.000 17363.S77 Planned: CO2-55 (wp02) V5 From Calaur TaMD , -20.0 0-200 200 - 300 .~ 300 - 400 400 - 600 600 800 -15.0 800 HXXJ 1000 - 1500 1500 -':Woo- 2000 *,-~--'--- 3000 -10.0 ~-- ~ .. )-' -," -S.O ___-~. _,.~ n -0 27~ 90 ~ : U_.:__.~";__.. -S.O \ ~ Prelim, Coo-56(C . . -10.0 24 .' 120 ---- -15_0 -20.0 Travelling Cylinder Azimuth (IFO+AZI) [deg] vs Centre to Centre Separation [lOftfm] CD2-55 (wp02) 1M o OLeg TFace VSec 0.00 0.00 0.000 0,00 0,00 0.000 3.00 0.00 743.165 0.00 0.00 7540,999 9.00 -72.52 8145.100 C02-55 (H..,t) 3.00 0.00 8214.387 0,00 0,00 11439.387 C02-55 (Toe) 0.00 0.00 12674.720 to Centre Separation [50ftfm] Target Au TVD 0,00 36,100 0,000 0.000 0.00 300,000 0,000 0,000 209.54 1859.850 -702,821 -398.322 209.54 7080.425 -7131.629 -4041.830 151.90 7322.000 -7742.525 -4015.879 151.90 7324,552 -7816,740 -3976,258 151.90 7357.000 -11271.097 -2132.076 151.90 7369.429 -12594,285 -1425.663 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre IsJ09 SECTION OET AILS +N/-S +FJ-W MO h1c 36.100 0.00 300,000 0,00 2125.312 54.76 11172.915 54.76 11863.756 87.00 11947,930 89.53 15863.877 89,53 17363,877 89,53 S 1 2 3 4 5 6 7 8 =I~ -75 -50 r~"'" . '~ -·....~:'IF__,e -25 j -0 _..~ -25 -50 -75 -1M Sperry-Sun Anticollision Report CÒnlpmîy: Field: Reference Site: Reference Well: Reference Well path: Phillips Alaska Ino, Colville River Unit Alpine C02 Plan: C02-55 Plan: C02-55 Däte: 6/6/2003 Time: 14:05:40 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan: C02-55, True North 52' MSL 52.0 Db: Oracle GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 of reference Interpolation Method: MO Interval: 100.000 ft Depth Range: 36.100 to 17578.388 ft Maximum Radius: 1954.229 ft Reference: Error Model: Scan Method: Error Surface: Plan: C02-55 (wp03) & NOT PLANNED P1JGRM ISCW SA Ellipse Trav Cylinder North Ellipse + Casing Casing J>oints HôleSiie Name in 2834.844 2390.000 9.625 12.250 95/8" 12069.306 7321.904 7.000 8.500 7" 17569.338 7370.046 0.000 6.125 Open Hole Plan: C02-55 (wp03) Date Composed: 8/28/2002 Goo-Pilot Plan Version: 14 Principal: Yes Tied-to: From Well Ref. Point Summary <------------------7'-', Offset Wellpath Offset Cti~Ctr' 'No7Go Site ' Well l\1D DiStaDce " Area ft ft ft Alpine CO2 C02-32 C02-32 PB1 VO 299.100 300.000 229.838 5.358 224.480 Pass: Major Risk Alpine CO2 C02-32 C02-32 VO 299.100 300.000 229.838 5.358 224.480 Pass: Major Risk Alpine CO2 C02-33 C02-33 V2 299.949 300.000 220.032 5.059 214.974 Pass: Major Risk Alpine CO2 C02-33 C02-33A V1 299.949 300.000 220.032 5.012 215.020 Pass: Major Risk Alpine CO2 C02-33 C02-348 V1 299.949 300.000 220.032 5.059 214.974 Pass: Major Risk Alpine CO2 C02-34 C02-34 V3 200.091 200.000 210.523 4.037 206.487 Pass: Major Risk Alpine CO2 C02-34 C02-34PB1 V2 200.091 200.000 210.523 4.037 206.487 Pass: Major Risk Alpine CO2 C02-35 C02-35 V1 312.204 300.000 198.915 5.488 193.428 Pass: Major Risk Alpine CO2 C02-35 C02-35A V1 299.296 300.000 198.968 5.235 193.733 Pass: Major Risk Alpine CO2 C02-36 C02-36P81 V5 391 .556 400.000 188.424 6.663 181.770 Pass: Major Risk Alpine CO2 C02-36 C02-36 V5 391.556 400.000 188.424 6.663 181.770 Pass: Major Risk Alpine CO2 C02-37 C02-37 V16 299.424 300.000 179.520 5.810 173.711 Pass: Major Risk Alpine CO2 C02-38 C02-38 V5 392.272 400.000 170.150 6.520 163.640 Pass: Major Risk Alpine CO2 C02-39 C02-39 V1 392.775 400.000 156.229 6.453 149.849 Pass: Major Risk Alpine C02 C02-39 C02-39PB1 VO 391.943 400.000 156.234 6.440 149.866 Pass: Major Risk Alpine CO2 C02-41 C02-41 V9 299.739 300.000 137.898 5.354 132.544 Pass: Major Risk AlpineC02 C02-42 C02-42 VO 299.949 300.000 129.899 5.024 124.875 Pass: Major Risk Alpine CO2 C02-42 C02-42PB1 VO 299.949 300.000 129.899 5.024 124.875 Pass: Major Risk Alpine CO2 C02-44 C02-44 V15 299.499 300.000 110.095 5.605 104.490 Pass: Major Risk Alpine CO2 C02-45 C02-45 V5 299.293 300.000 101.199 5.365 95.835 Pass: Major Risk Alpine CO2 C02-46 C02-46 V2 299.388 300.000 89.631 5.099 84.532 Pass: Major Risk Alpine C02 C02-47 C02-47 V2 3277.669 3400.000 167.018 107.385 73.123 Pass: Major Risk Alpine CO2 C02-48 C02-48 V1 299.749 300.000 70.120 5.733 64.388 Pass: Major Risk Alpine CO2 C02-49 C02-49 V1 396.772 400.000 57.922 6.407 51.540 Pass: Major Risk Alpine CO2 CO2-50 C02-50 V2 299.568 300.000 50.784 5.945 44.839 Pass: MajorHisk Alpine CO2 CO2-50 C02-50PB1 V2 299.568 300.000 50.784 5.945 44.839 Pass: Major Risk Alpine CO2 CO2-51 C02-51 V8 299.957 300.000 41.948 6.216 35.733 Pass: Major Risk Alpine C02 Plan: C02-31 PLAN: C02-31 (GR Horz) 299.980 300.000 240.004 5.963 234.041 Pass: Major Risk Alpine CO2 Plan: C02-31 Plan: C02-31 (ST Core) 299.980 300.000 240.004 6.072 233.931 Pass: Major Risk Alpine CO2 Plan: C02-31 Prelim: C02-ERO 1 VO P 480.352 500.000 238.290 7.799 230.523 Pass: Major Risk Alpine CO.2 Plan: C02-31 Prelim: C02-ERO 2 VO P 299.954 300.000 239.882 5.954 233.928 Pass: Major Risk Alpine CO2 Plan: C02-31 Prelim: C02-ERO 3 VO P 390.020 400.000 240.528 7.039 233.490 Pass: Major Risk Alpine CO2 Plan: C02-31 Prelim: C02··ERO 5 VO P 480.334 500.000 238.676 7.815 230.891 Pass: Major Risk Alpine CO2 Plan: C02-31 Prelim: C02··ERO 6 VO P 299.954 300.000 239.743 5.938 233.805 Pass: Major Risk Alpine CO2 Plan: C02-31 Prelim: C02·:ERO 7 VO P 390.032 400.000 240.147 7.011 233.137 Pass: Major Risk Alpine CO2 Plan: C02-43 C02-43 (GR Core Pilot) 299.980 300.000 119.941 6.047 113.894 Pass: Major Risk Alpine CO2 Plan: C02-43 C02-43 (ST Core) V7 PI 299.997 300.000 120.111 6.090 114.021 Pass: Major Risk Alpine CO2 Plan: C02-43 Plan: C02-43 (GR Horz) 299.997 300.000 120.111 6.090 114.021 Pass: Major Risk Alpine CO2 Plan: C02-43 Plan: C02-43 (ST Horz) 299.980 300.000 119.941 6.047 113.894 Pass: Major Risk Alpine CO2 Plan: CO2-52 C02-52 V3 Plan: CO2-52 398.446 400.000 29.655 6.957 22.699 Pass: Major Risk Alpine CO2 Plan: CO2-54 C02-54 VO Plan: A 15 (p 299.996 300.000 10.281 6.263 4.018 Pass: Major Risk Alpine CO2 Plan: CO2-58 C02-58 (Rig) V4 199.994 200.000 31.047 3.698 27.350 Pass: Major Risk Alpine CO2 Plan: CO2-58 C02-58 P81 V2 Plan: CD 300.000 300.000 30.005 6.151 23.854 Pass: Major Risk Alpine CO2 Plan: CO2-58 C02-58 ST1 V2 Plan: C 199.994 200.000 31.047 3.650 27.398 Pass: Major Risk Alpine CO2 Plan: CO2-58 C02-58 V7 Plan: CO2-58 300.000 300.000 30.005 6.260 23.745 Pass: Major Risk Alpine CO2 Prelim: C02-30 C02-30 VO Plan: C02-30 389.698 400.000 250.994 7.466 243.532 Pass: Major Risk 0 . . ) Sperry-SUD Anticollision Report ) Cørtlþlittyi ' ,m¢ldt,:.·..'.·' ':. , .1,{~f~r~nç~SiÏê: >J,'{(#re~~eW~lI: : .. .'., " i R.¢f¢~en~~\V~.lp~(IÏ: ,. , . .. .... , ..',.. Phillips ;Alas~å .Inc.. ,,' ,polvUleRiver Unit :All?ir1~ GP2 · ·Plån:CP2~55 PI~n:Cq2-55 ' . , , "'..",, '" ,,'. . .".... . '. . .... ~atei . ,Q/ô~~?93 ", .., ':',. .' '., .,?~~: '14:95:~~, .'. ,.. ,.... .}~~~ei ,., .' ',.,.,:, ~:;:~~~~~1~~:~~~~~;¢:" , ., ·'~~~~~~~gP2.55'T~~~ NQrtþ. "Db:, Qråçle 2 S~y . ' ., , , ' , " " '" ".. . . " " "" ,. " . , . :;~t;~2_++~H-:+~t~:~t;~I~eqp~tb :'R~t'~r~nce ..·örfset ". .':.::\~:..'.'.:!..~:.¡ CD2-40 va Plan: CD2-4011200.000 14071.189 C02-53 VO Plan: C02-53 399.005 4,00.000 C02-56 V1 Plan: C02-56 400.348 400.000 CD2-57 VO Plan: C02-57 400;856 400.000 ··.··~~~i:~~;¡...~~~~: 309.403 565;631 -224.505 20.225 7.468 12.761 ' 10.227 7.515 2.714' 20;245 7.456 12.792 , , . ..... .. .. ..... .... . ..... .. .... .... ... '.., . .. .. ..... o ... ... W~~~g..,.'· Alpine CD2 Alpine CD2 AlpineCD2 Alpine C02 Prelim: C02-40 Prelim: C02-53 Prelim: C02-56 Prelim: CD2-57 FAIL: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major,Risk Site: Alpine C02 Well: CD2-32 Wellpath: C02-32 PB1 VO . ,. . , ',¡' ..~ê~~f~J)¢4VJ) ," " .. .. ",' 'If: :. .,..':> ft·'" 36.100' ,36.100 99.100 99.100 199.100 ,199.100 299.100 299.100 389.565 389.547 .' .' <Offset. ,. :.lVID:: .. " .,' .TVD' " '. .' .'1(>' , 'ff ..,.,. 37.000 37.000 100.000 100.000 200.000 200.000 300.000 300.000 400.000 399.999 , , , ~~~.~M~J~~::~s." : :;: :!'/.;: ::.: :~~~::.·:>·:y>:·: ::. ;:..:: :::r::. ): ;::: >.¡: ::::: .. ~':~f~:'· '.' 'o~~rt:T;~~ITJ~~~~¡)~~i~~~! 0.000 0.000352.96 352;96 0.071 0.035 352.96 352.96 0.297 o~ 106 352.95 352.95 0.524 O~ 180 352.92 352.92 0;542 ,0;253 353.22 144:22 Rule Assigned: Major Risk Iilter-SiteError: 0.000 'ft Çtî:;'ëtr:::N"ø~GØNI()~þj~ ':~¡Sh~~~":~f~~i;i:: ~ .:~~~~ti~~·,'· ·",~t~n~",.,,:, 229.823 0.912 228.911 Pass 229.823 1.81,7 228,.006 Pass 229~826 3.583 226.243 ' Pass .229.838 5;358224:480 Pass 231:819 6.494 225.329 Páss 479:563 479;252 500.000 499.997 0.424 0.330 354;16 145;16 237;815 7;263 23Ø.5,57'··, pass 568.69.9 567;659 600.000 599.99,3 0.390 00409 355:65 1.46;65 24708(54 .8:221 239.687 Pass 656.620 654;1~2 700.000 699.984 0.491 0.491 357.55 148.55 261<920 9.548 '252.524 Påss 742.986 738,.339 800.00.0 799.969 0.694 0.581 -0.29 150.71 280.055 11;1.52 269;212 l1ass 827.432 819.599 900.000 89.9.948 0:912 0.673 1;96 ,152.96 302.657 12.791 290.353 Pass 909.594 897:519 tOÖO.OOO 999;927 1;075 " 0;720 4.18 155.18 329.984 14J34 316;500 ' Pass 98.9;471 972;Q29 1100~000 1099;875 1;264 0;75ß 6.19·' 157.19 361.265 15.511 346.728 Pass 1067;385 1043;381 1200.000 1199.676 1.585 0.854 7.68 158.68 395.601 17.417 379.766 Päss 1143..019 1111:256 130.0.000 1299.334 L980 0.987 8.88 159.88 433.204 19.562 415.978 Päss 1216.531 1175.798 1400.000 1398.735 2.427 1.146 9.77 "160.77 473.377 21 .862 454.716 "Pass 1288.278 1237;324 1500.000, 1497.635 2.923 1.342 10.31 1.61.31 515;078 24.331 ,·494.901 Pass 1358:554 1296;083 1599;990 1595.718 3.461 1.581 10.52 161.52 557.462 27.002 535:665 PáSs 1427;700 1352;354 1700.00.0 1692.606 4;021, 1.886 10.45 161:45 599;652 29.893 576;094 ., Þa.ss 1500..000, 1.409.459 1800.000 1787.635 4.641 2;272 9:98 160.98 641.927 33.138 616.301 pass 1561;979 1456.930 1900.000 1880.671 5.215 2.732 9.24 160.24 684.648 36.352 656.860 Pass 1629.523 150.7.051 2000;000 1971.768 5.854 3.257 8.33 159.33 728.238 39.934 697.939 Pass 1718;817 1572.463 210.0.000 2060.418 6;725 3.864 7.19 158.19 770,672 44;554 736.992 Pass 1808.425 1638.104 2200.000 2146.516 7.601 4.540 5.84 156.84 810.926 49.371 773.503 Pass 1898.354 1703;981 2300.000 2230.702 8.483 5.252 4.41 155.41 849.478 54.318 808.012 Pass 1988.965 1770.357 2400.000 2313.385 9.374 5;962 3.01 154.01 886.032 59 ;283 840.374 Pass 2079.773 1836.878 2500.000 2395.656 10.267 6.552 1.69 152.69 922.372 63.959 872.694 Pass 2170.442 1903.297 2600.000 2478.127 11.160 7.078 0.48 151.48 959.586 68.473 905.973 Pass 2261.271 1969.833 2700.000 2560.788 12.055 7.599 359.39 150.39 997.045 72.980 939.475 Pass 2352.196 2036.440 2800.000 2643.421 12.951 8.227 358.38 149.38 1034.635 77.762 972.833 Pass 2443.385 2103.240 2900.000 2725.715 13.850 8.949 357.43 148 .43 1071.765 82.794 1005.477 Pass 2534.900 2170.279 3000.000 2807.645 14.753 9.702 356.53 147.53 1108.267 87.920 1037.380 Pass 2626.659 2237.495 3100.000 2889.267 15.659 10.436 355.67 146.67 1144.315 93.016 1068.826 Pass 2718.097 2304.478 3200.000 2970.635 16.562 11.127 354.84 145.84 1181.069 97.988 1101.019 Pass 2809.075 2371.123 3300.000 3051.831 17.460 11 .838 354.02 145.02 1218.861 103.001 1134.142 Pass 2892.551 2432.124 3400.000 3132.975 18.287 12.549 353.26 144.26 1256.647 107.782 1167.496 Pass 2973.036 2490.375 3500.000 3214.046 19.094 13.259 352.58 143.58 1294.452 112.228 1201.259 Pass 3053.249 2547.844 3600.000 3294.778 19.906 14.026 351.95 142.95 1332.683 117.103 1235.048 Pass 3132.972 2604.377 3700.000 3375.233 20.721 14.742 351.36 142.36 1371.849 121 .855 1269.886 Pass 3211.991 2659.828 3800.000 3456.110 21.536 15.313 350.84 141.84 1412.730 126.233 1306.814 Pass 3290.451 2714.309 3900.000 3537.381 22.355 15.941 350.39 141.39 1454.861 130.776 1344.890 Pass 3368.625 2768.011 4000.000 3618.567 23.179 16.642 350.00 141.00 1497.349 135.500 1383.190 Pass 3446.349 2820.824 4100.000 3699.555 24.006 17.325 349.63 140.63 1540.477 140.185 1422.189 Pass 3523.640 2872.766 4200.000 3780.371 24.835 18.015 349.30 140.30 1584.190 144.888 1461.776 Pass o "'; · ff t~" ; I, .,~ t¡} I , .~. ~ ~ ~.~.. ~ ;1 I' " ., .. ~ DrillQuest ; [I ~ (' J1 - ·.1:'",<: 1,. ~. :/ ,~ ~ I 6 June, 2003 - 14:35 MD I Delta ' Inclin. Azimuth TVD N::>rthings Eastings I Dogleg T oolface VS (152°) (ft) I MD (ft) (0) (O) (ft) (ft) (ft) (°/1 OOft) (0) (ft) 1 0.00 0.000 0.000 0.00 0.00 0.00 0.00 :2 300.00 300.00 0.000 0.000 300.0,0 0.00 0.00 0.000 0.000 0.00 ~ ... n' .......n .",.. ," . 3 1620.00 1320.00 42.900 209.000 1500.07 412.39 S 228.59 W 3.250 209.000 256.11 .._~D.~·..._._.~....___. 4 2834.84 1214.84 42.900 209.000 2390.00 1135.68 S 629.52 W 0.000 0.000 705.30 ._.,_._-~.--,._.__..... 5 4687.91 1853.07 56.798 209.000 3581.94 2371.44 S 1314.51 W 0.750 0.000 1472.76 ......_._...._--_.~~_..~ 6' 4813.26 125.35 55.909 214.929 3651.43 2459.92 S 1369.69 W 4.000 101 .845 1524.82 ..-..-..~-,_....__...- 7 10387.46 5574.20 55.909 214.929 6775.82 6244.64 S 4012.76W 0.000 0.000 3618.50 ........~_.......__._.~.....__.. '8t' , 12078.24 1690.78 89.499 151.906 7322.00 "7742.47 S 4015.90 W 4.000 285.493 4938.31 9t 16078.33 4000.09 89,499 151.906 7356.98 1l271.13S 2132.26W 0.000 ,0.000 ,m'.~ '8938~2'5: 10 17578.33 1500.00 89.499 15.~ .906 7370.09 12594.35~ 1425.92 W _. o.OO.QL__ 0.000 -~-1~õ438.2Ö-1 $pet",¥--Sul'IlJrl'llt!lg_l)"içes PropøsaJLoCSflJata- CD2"'55~eEJ2;..55 (wp03) Spej - y-Sun Drilling St,. 'vices Proposal Global Data - CD2-55 - CD2-55 (wp03) MD : Delta Inclin. Azimuth TVD Northings Eastings Dogleg Toolface VS (153(» (H) . MD (ft) ((») (0) (H) (ft) (ft) (°/1 DOH) (0) (ft) _~_,______ 0.00 ______ 0.000 0.000 ____:~3_:~~___~~~~44.05_~___~?~?.?8.44 E _/ 0.00 _~____~~~~O 300.00 __,__~:9~~.__ 0.000 248.00 5974244.05 N 371738.44 E ____0.000_ 0.0001 0.00 3 1620.00 1320.00 42.900 209.980 1448.07 5973835.63 N 371502.83 E _ 3.250 209.980 256.11 4 2834.84 1214.84 42.900 209.980 2338.00 5973119.31N 37108959E 0000 0000 705.30 1_. 5 4687.91 1853.07 56.798.?<!.9c~0_3!i29.~ 5971895.44 N 370383:~ Iõ _. o:n¡o _.__~0I:)11472.76 ~ 6' 4813.26 125.35 55.909 215.909 3599.43 5971807.92N 370326.87E 4.000 101.8451 1524.82 1·- 8¡ - -~~K~~i~::i~ -i~:::~~H{~~f~%~~~{~ii1~-~~J~~~:~~ -~.. ~:~6 . -2~:~ ~:::~~ l __9! ,,__ _!~C!!~ .3~_.~Q.~~~Q~_.~~:499_____152.886 _~~04.:~~___~~?~~1_ !.:04 !'! _~~~41 ~?~.!. ~ -~:.O :OO~ _ 0.000! 8938.25 I ~_~_ ,_ _~.!~?_~ .~.~ _ 1 ~~~ :00 ~_... ~~:~~,~., _! ~?,~~,?:...?.3! ~ :~~l 586167~:9~ .~_ 3?~~~?31_ ~_ 0.000 0.000 _.. ~~~~~ :?_~_ 6 June, 2003 - 14:36 _0' ~, [~ " ,~, ~" ..~þ ~j ;!~ l11' /-"."\ ;:.~ DrillQuest , ConocoPhillips Alaska, Inc. ") , Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ) 'Y ConocoPhilIi pS June 9, 2003 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-55 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the Alpine CD2 drilling pad. The intended spud date for this well is July 7,2003. It is intended that Doyon Rig 19 be used to drill the well. CD2-55 will be drilled to penetrate the Alpine reservoir horizontally. After setting 1'1 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 diverter. There have been 38 wells drilled on CD1 pad and 35 surface holes drilled on CD2 pad with no significant indication of gas or shallow gas hydrates. All of the wells on CD2 have surface casing shoes within a 2000' radius of the planned surface casing shoe of CD2-55. It is also requested that the packer placement requirement be relaxed to place the completion packer /200ft TVD above the Alpine formation. This will place the completion at a maximum inclination less than 65° and allow access to the completion with standard wireline tools for future intervention. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 1 0-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser setup which replaces diverter. r"",:¡, 2"""'" {"'~ ì/"'"" ~ ¡} ,·1 ~.,,,.,, \' ~..." " ~ ~ \\, 1'1."",,, '~,.,,,t (t""", ~ ') r:, "/1,,003 JUN ;,,¡u þJastw fl' G~ OR'G'NAL If you have any questions or require further information, please contact Zane Kuenzler at 265-1308 or Chip Alvord at 265-6120. Sincerely, Y~~(t" Zane Kuenzler Drilling Engineer Attachments cc: CD2-20 Well File / Sharon Allsup Drake Chip Alvord Vern Johnson Cliff Crabtree Steve Moothart Nancy Lambert Lanston Chin ATO 1530 ATO 868 ATO 802 ATO 848 ATO 844 Anadarko - Houston Kuukpik Corporation e-mail: Tommy_Thompson @anadarko.com ~.'~., ~.... . CH' A· "'S' ..' .... E·' . Chase Manhattan Bank USA,N.A.. Valid Up To 5000. ., Dollars M~' . ·CP2-S§ '~_.c~c._u~.'~"m. ~^- 4# 7d~ ':0 iI I. I. 00 I." ...: 2 I.a do 00.. 2 7 25 7'" 100 51. '/ S.K. ALLSUP-DRAKE 1051 CONOCOPHILLlPS 711 G STREET-AT01530 /(" '7/ I .., /:'v'\3 ANCHORAGE AK99501 DATE ....JUf1-/2.-~ CA::A./ 62-14/311 PAY TO THE· . .....;;[........·.:.11.......·.··..·...1I.....&.......·....·..0·..·.f.....,·.··..A...:·....·.utS.·......·..··..·.·.·.....·.G:·. 11-........... Z,f1.·.........cxq·.: ". c.c.·.. ." . ~$ (00.00 ORDER OF . I ¡;ì~ / ?/ . /) ------ae.. .~. c::>h1 ~ ~~/oaL>Oa:ARS ~ 5?Z':~ /-...... Alaska Oil & Gas Corn;, Cmr¡¡iÜ~;s¡on Anchorage RECF~" ~F'=<O . ~ 'I t:~_. P.: t ~ ~I .!.f ~ ~";¡ '>1 ~ ~" .-'--~~ JUN 2 5 Z003 ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMtTTAL LETTER WELLNAME(!l<.å (!))2-~ PTD# 2-CJ 3- / ('f{" CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to· be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates 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. PTD#: 2031180 Administration o o Appr Date SFD 6/26/2003 Engineering Appr Date WGA 6/26/2003 Geology Appr SFD Date 6/26/2003 Geologic Commissioner: ()rs Company _C-º-~'o_C_QPHILLlPS AtAS.~lhLC Well Name: j;_O_LVll.lEJ11~UNIT G..D.2:..5_5 Program Â~B Well bore seg Field & Pool _..QQLV1LLE RIVER, AL.e.LNE..01L-=-120100 Initial Class/Type _SFR / 1WINJ GeoArea _89.0 Unit .5.(>-3.6.0__ On/Off Shore _QrL.- Annular Disposal P~(mit fee attache_d. . . . _ _ _ . _ _ . . _ _ _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ _ _ . . . . . . . _ Y~$ _ _ . _ . _ . . . _ . . . _ _ . _ . _ . . . . . . _ _ _ _ _ _ _ . _ _ . . . . . _ . _ . . . . . . _ . . . . . . . . . . . _ _ _ . .Leas.e.number .apRropriate. . . . . . . . . . . . . . . _ _ . . _ . . _ _ . . _ _ _ . . _ _ . _ _ _ _ . . . Y~$ . _ . . . . . . . . . . . . . . . _ . . . _ . . . . . . . _ _ . . . . . . . . . _ . . . . . . . . . . . .. .. . . . _ . . . . .. _ . . . _ . . . . .U.niq~e well. n.arn~ .aru:j ou.mb.er . . . . . . . _ _ _ _ . . _ _ . . . . . . . . _ . _ _ _ . . . . _ _ _ . . . _Y ~$ _ _ _ _ . . . _ . . . .. . . _ . _ . . . . _ _ . . . . . .. _ _ . . . . . . . _ _ . _ _ . . _ . . _ . _ . . . . . . . . . . _ . _ _ _ . _ . . _ . . _ . .We.lIJQcat~d in.a.d.ef¡ne.p.pool. . . . . . . . _ _ _ . . . _ _ . . . . . . . . _ _ _ _ _ . . . . . . . Yes _ _ . _ . . . Cohlille.River.AJp.in.e. . . . . . . _ . _ . . _ . . . . . . . _ . .. . . _ . .. . . . . . . . . . _ . _ . . . . _ . . . _ . _We.ll JQcated proper _distance. from drilling unilb.ound.a(y. . _ . . . . . . . . . . . _ . _ _ _ _ _ . . _ Yes. . . _ . _ _ Gov.em~d by COrtsef\lati.oo Order No. .443 . . . . . . . . . . . . . . . _ . _ . . . . . _ _ _ . . . . . . . . _ . . 6 _We.ll JQcat~d pr.oper _distance. from othe.r wells. . _ . _ _ . . . . . . . _ . . . . . . . _ .. . . . . . . . Yes . . . . . _ . . . . . . . . _ . . . . . . _ . . . . . . . _ . . _ . . . . .. . . _ . . . . _ . . . . . . . . . . _ . _ _ . . _ . 7 .S.ufficiel1t .acreage.ayailable in. d.rilJiog unjt. _ _ . _ . . _ _ . . . . . . . . . . _ _ . _ _ . . . . Y~$ _ . _ . . . . _ . . _ . _ . . . _ _ . _ . . . . _ . . . . _ . . _ . . _ . . . _ . _ . . .. . _ _ . . . . . .. . . _ . _ . . . . . . . _ _ . . . 8 Jf.deviated. js. weJlbQre platinc.lu.ded . _ _ . . . . . . _ . . . _ . . . . . . _ . . . . . . . . . . . Y.e$ . . . . . _ _ _ _ _ _ . . . _ . _ . . .. . _ . . _ _ _ _ . _ _ . . _ . . . . . . . . . . .. . . .. _ _ _ . . .. . . _ . _ _ _ . .. . . . . _ . . . . . . . 9 .Operator only affected party.. . . . . . . . . _ . . . . . . _ . _ . . . . . . . _ _ . _ _ . . . . . . . . . Y~$ _ _ _ . _ . .. .. . .. _ . _ . . . . . . _ . . . . . . .. _ . . . . . . .. . . . . . . _ _ . . . . _ . _ . . . .. . . _ . . . . _ . . . . _ . . _ _ . . . _ 10 _Operator bas_appropriate_ bond in Jorce. . _ _ _ _ _ _ . . . . . _ _ _ . . . . . . _ . . . _ . . . . . . . Yes. . . _ _ _ _ . . . . . _ _ _ _ . _ . _ _ _ . . . _ _ _ . _ . . . . _ . . . . . . _ _ _ . . . _ . _ _ . . . . . . _ . . _ _ . _ . . _ _ .. . _ _ . . _ 11 P~(mit cao be issu.ed wjtbQut co.nserva.tion order. . _ . _ . _ . . . . . . _ _ _ _ _ _ _ . . . . . . _ . Yes. _ . _ _ . . . . . _ . . . _ _ . . . . . . . . . . _ _ . _ . .. . _ .. . _ _ _ _ _ _ _ _ _ . _ _ _ _ . . _ . . . . _ . . . _ . _ _ . _ _ _ . . . . _ . 12 P~r:mit cao be issu.ed wjtbQut adrnioi$tr.ative.approvaJ . _ . . . . . _ . _ . _ _ _ _ . _ . . . . . . . . Y~$ . . . . . . _ _ . . . . . . . . .. . . . . . .. . . . . . . . _ . _ . . . _ . _ . . . _ . .. _ . _ _ . . . . .. .. . . . . . _ _ . _ . . . _ . . . . . . _ 13 Can permit be approved before 15-day wait Yes 14 .We.IIJQcaled within area an.d.strata .aut\"loriled by.lojectioo Ord~( # (pullOt/: in_cOO1m.eots). (For. Yes. _ _ . . .. _ Area InjectjoRQrde.r No.. 1.8A_ . . . . . . . _ . _ _ _ . _ _ _ _ _ . .. _ _ _ _ _ . _ _ .. _ _ . . . _ . _ . _ _ . _ _ . . . . . . . 15 AJlw~lJs.wit.hi.n.1l4_roile.are.a.of(eyi~,~tjd~otified(For:~ervjG.e.welJonM_ _ _. _ _' _..... _. .Y~$_ _ _ _" .Non_e.w.itbi[1_1J.4.mil~. _...... _ _. _ _ _ _ _. _.... _ _.. _ _ _ _.. _ _.. _ _ _.. _ _. _ _.. _ _ _... _. 16 Pre.-produced i[1j~çtor~ 'puratiQn.of pre-produGtiPIJ tes~ than. 3 months. (For_ser:.vi.ce well QnJy) _ _ .NA . . _ . .. . . . . _ . . . . . . _ . _ . _ . . . . . . _ . . _ _ _ . _ . . _ . . _ . . . . _ _ . . _ . _ . . . . . _ . . . . .. . _ . . . _ . . . . . . 17 ACMP. ~inding _of Con.si$teOGY. h.as bee.n .i~sued_ for. tbis proiect. . . . . . . . _ . _ _ . _ _ . . . . . _NA . .. _ . . _ . Exi~tif1g project _ . _ . . . . . _ . . . . _ _ _ _ . . . . . . . . . . . . . . _ _ _ _ _ . . . . . . . _ _ _ .. _ _ _ . _ _ _ _ . . . . 1 2 3 \: ( 18 _C.oodu.ctor $tr.ing.prQvid~d _ _ . . . . . . . . . _ _ _ _ _ . _ . . . . . . . . . . . _ . _ _ . . _ .. . . . . Y~$ _ . _ _ .. _ _ . . _ . . . _ _ _ _ . . . . . . . . . . . . . _ . . _ _ . _ _ _ _ . . . _ . _ _ _ . _ . _ _ . . . . . . . . _ . _ _ _ . _ . . . 19 _S.urfac~.casing.pJQtects. aILk.nown. USDWs _ _ _ . _ _ . . . . . . . . . . . _ _ . . _ _ .. . . . _ . . . Yes. . _ _ . _ . .. . . . . . . _ _ _ . _ . _ . . _ . _ . _ _ _ _ _ _ . . _ . _ _ . . _ _ . . . . _ _ _ . . _ . . _ _ _ _ . _ _ . _ _ _ _ _ . . _ .. . _ . 20 _CMTv.otad~qu.ate.toçirc.utate.o.n.cOl1d.uctor_&$uJf.C$g _ . _ _ . . _ .. _ _ . _ _ . . _ .. _ _ . _ . .. . .Y~s. .. _ _ . . . . _ . . . . . _ _ _ . . _ _ . . . . . . . . _ _ _ . _ _ . _ _ . . . . . . . . _ _ _ _. . _ . . . . _ _ . _ . . . . . _. . . . . . _ _ 21 _CMT v_ot ad~qu.ate.to tie-inJQng _string to.surf ~g_ . _ . _ . . . . . . . . . . . _ .. _ _ . . _ . . . .. . No_ _ . . _ . _ _ fu.ture AD JeQ.ue~t.. _ . _ _ _ _ . . . . _ _ _ _ _ _ . _ . _ _ . . _ . . _ _ _ _ . . . _ . . _ . _ _ . . _ . _ _ . _ . . _ . .. 22 .CMTwill GoYer_ail !<oown.pro_dUGtiye bQri~on.s. . _ . . . _ , . . _ . . . . . . . . .. . _ . . _ . _ _ .. . .No_ _ . . . . . . Ope.n.h.ol~.injecto!._ _ . . . . ,. _ . _ . . . _ _ _ . . . _ . . . . . . .. _ . ., _ . _ _. '., _ _ _ . _ . _ _ _ _ _ . . _ .. . . _ 23 _C.asiog de.signs adequate. f.or. C..T, B.&.p-erroafr.ost . . . . . . . . _ . . . . . . . _ _ . . . . . . . . Y~$ . . _ . _ _ . . . _ . . , . _ _ _ . _ _ . _ . . . . . , . . _ _ _ _ . . _ . . . _ . . _ . . . _ _ _ . . . . _ . . . . . . _ . _ . _ _ . . . . . . . . 24 Adequate.tan.kage_o! re.serye pit . . . . _ . _ _ . . . _ . _ . . _ . . . _ . _ _ _ _ . _ _ _ . . . . . . . Y~$ _ _ _ _ _ _ . OOYOO :19. _ _ _ _ . . _ _ _ . . . _ . . _ _ _ _ _ . _ _ . . . . _ . . . _ . . . . . _ _ _ . . . _ . _ . . _ . _ . . . _ _ . . . . . . 25 Jf.a.re-d(ill~ bas.a. 1.0:-403 fQ! abandOl1rne_nt be~1J ç¡pp.rov~d _ _ . . . .. . . _ . _ _ _ _ . . . . . . _ . _NA . . . _ . _ _ . . . . . . . _ _ _ . _ . . _ . . . _ " . . _ _ _ _ . _ _ _ _ . . _ . . . . . . _ _ . . . . . _ . . . _ . _ . _ . _ _ _ _ _ _ _ . _ . . 26 Adequate.wellbore. ~eparç¡tio_n.propo~ed _ _ _ _ _ _ . _ _ _ . . _ _ _ . . . _ _ _ _ _ _ _ _ _ . . . . _ _ .Y~$ . _ _ _ _ . _ . . _ _ _ _ _ _ _ . _ _ _ _ _ . _ . _ _ _ . _ . . _ _ _ . _ _ _ _ . _ _ . . _ _ _ . _ _ _ _ . _ . . . _ _ _ _ _ _ _ _ _ _ . _ . . . _ _ 27 Jf.djv~r:ter .reqj.lir~d. dQeß jt .m.e~t r~guJatiOl')s_ _ . _ . _ . . . . . _ . _ . . . _ _ _ _ _ _ . . _ _ . . _ . _NA. _ _ _ _ _ . . WfiiYer.approved~ _ . _ _ . . _ . . . _ _ _ _ _ _ . . _ _ _ _ . . _ . . _ _ . . . _ _ _ . . _ _ _ _ . _ _ . _ _ . ., _ _ _ . . . . . 28 _D.riUioQ fJu.id.pJogram schematic.& eq.uipJistadequate. _ . _ _ _ . . . _ _ _ _ _ _ _ . . . . . . . _ . .Y~$ _ _ _ _ _ _ . Max MW.9.8. ppg~ . _ . _ . . _ . . _ . _ _ _ _ . _ _ _ _ _ . . _ _ _ . . _ . _ . . _ _ . . . . . _ . . . . _ _ _ . _ . . . . . _ _ 29 .BOPEs,.d_o _they .m.e~t reguJatiolJ . . . . . . . _ . _ _ _ . _ _ _ . . . _ . . . _ _ _ _ _ _ _ . . _ . _ . . Y~$ . . . _ _ _ . . _ . . . _ . _ _ _ . _ _ . . . . . . . _ . _ _ _ _ _ . . _ _ . . . _ . . . _ . _ _ . . . _ . . . . _ . . . _ . . _ _ _ _ . . . _ . _ . 30 _BOPE.pre.ss ratiog approp(iate;.testto.(pLlt p$ig i.n.c9rrll~nel')t$). . _ . . _ . _ _ _ _ _ _ . . . . . . . Y~$. _ . _ _ _ . T~stto_50QO_p-sLMS~ 25.98 P$i.. . . _ _ _ _ _ _ _ _ _ . . _ _ _ . . . _ . _ . _ _ . .. _ _ _ . . . . _ _ . . _ . ., _ . . . . . _ 31 .C.hoke.roanjfold cQmpJie~ w/API. R~-53. (May 84). _ _ . _ . . _ . . . _ . . . _ . . _ _ _ . . . . . . . Yes. . . _ _ . . . _ . . . . . _ _ _ . _ _ . _ . . . . . . . _ _ _ _ . _ . _ _ _ . . _ . . . . _ _ _ . _ . _ . _ . . . . . . . . _ _ _ . _ . . _ . . . . 32 _WQrk will OGC.U( withoytoperç¡tio.n _shutdown. _ . _ _ _ . _ . . _ . . . . . _ _ _ _ _ . _ . . _ _ . . . . Y~s . _ . _ _ . . . _ . . . _ _ _ _ _ . . . . . _ . . . . . . _ _ _ . _ . _ _ _ . . _ . _ . . . _ _ _ _ . _ _ . _ . . _ . . . _ . . _ _ . _ _ . . . . . . 33 J~ pres.ence_ Qf H2$ gas. p-rQb_aÞI~ _ _ . . . . . _ _ _ _ _ . _ _ _ . . . . _ . _ _ _ . . _ _ _ . . _ . _ . . No _ . _ . . . . . . _ _ . _ _ . . . _ . _ . _ . . .. _ _ _ . . . _ _ _ . _ . . . . . . . . . . . _ _ _ _ _ _ . . _ . _ _ _ _ . _ . _ _ . . _ . . . . . _ . 34 MecbanicatcPlJd.ition o{ we.lIs wi.thin AOß. yerifiect (f9r.s_ervic~ w~1J QnJy) _ . . . _ _ _ . . . . . . . Yes _ . . . . . . No well$ wjtlJiO AOR_ _ . . _ . . _ . . . _ _ _ . _ . . _ . . . . . . . ,. . . _ _ _ . _ . . _ _ _ . . . _ _ _ _ _ . . . . . . _ _ . 35 .P~(mit ca[1 be issu.ed w!o. hydr:ogen. s_ulfide meas.u(es. _ . . _ . . _ _ . _ _ _ _ . . . . . _ . . _ . ,. Y~$ _ _ _ . . . . . . . _ _ _ _ . . . . _ _ _ _ . . . . . . . _ _ . _ . _ _ _ . . . . . . . . _ _ . _ _ _ _ _ _ . . . . . . , . . . . _ . _ _ _ . _ . . . 36 _D_ata_PJes~lJteqon.p-ote.ntialoveJpre$.sur~_zone~.. ,.". _ _...... _ _ _ _ _' _....... Yes. _' _., .Non.e.expe.cted._Res_ervoirprßss.ure.e.xpe.cte.d.is.8.7ppg.EMW;.wilJbe.qriJled.with.9,0.-.9,3.ppg.rnud... _'..,.' 37 _S~i.smic.a.nalys.is. Qf ßhallow gas_zoo~s. . . . _ _ . . . . , _ . _ _ . . . . _ _ _ _ _ _ . . . . . . . . . NA . _ _ _ . . _ _ . . _ _ . . _ _ _ . . . _ _ . . . . . _ . . . _ _ . _ . . _ _ _ . . . . . . . . _ .. . _ . _ _ . . _ . _ . . . .. _ _ . _ . . . . . . . 38 _S~Çlbed .C9l1djtioo survey .(if Off-~ho(e) . . . . _ _ . . . . . . _ _ . . _ . . _ _ _ _ _ _ . _ . _ . _ . . _ NA. . _ _ _ . . _ . . . . . . _ _ _ _ _ . . _ _ . . . . . . . _ _ . . . _ . _ . . _ . _ _ . . _ . _ . _ _ _ _ _ . _ _ . _ . .. _ . . _ _ . _ . _ . . . . . 39 _ CQntact narnelp.hQneJQr_we~kly progress.rep-orts [exploratpry _only]. , . _ _ . _ . _ . . _ _ . . " . NA. . . ., _ _ _ . . _ . . _ . . _ _ _ _ . . . . . . . _ . _ . _ _ . _ . _ _ _ . _ . _ . . _ . . _ . . _ _ . _ . . _ . . _ . . . . . _ _ . . . _ . . . . . { Date: oJ! 2..7 þ:s Engineering Commissioner: ~~ Public Commissioner Date Date ~ ~ ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to Sinlplify fìnding infomlation, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. J! Sperry-Sun Dr: )ng Services LIS Scan Utility ') 803~ II<G' Â 1~7 $Revision: 3 $ LisLib $Revision: 4 $ Tue Oct 14 13:56:06 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/14 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 CD2-55 501032046300 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 14-0CT-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: RUN 1 MW0002546011 R. KRELL G. WHITLOCK MWD RUN 2 MW0002546011 M. HANIK D. MICKEY MWD RUN 3 MW0002546011 R. KRELL D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 11N 4 E 2113 1497 ~\l i:: () MSL 0) O 1"\ -r /) -":? :~" ¡ L-; c·D C; ~~) 52.40 15.90 ......)~~ .,' ,J" (:.f'f¡Js~on # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.500 6.125 CASING SIZE (IN) 16.000 9.625 7.000 DRILLERS DEPTH (FT) 114.0 2796.0 12210.0 # ~~'ùrY\~ ,,¡J ,'" REMARKS: ) ) 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS 0.L..1ERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 2 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE. 5. THE WELL WAS SUSPENDED DUE TO A POOR CEMENT JOB FOR THE 7" CASING. AFTER THE CASING WAS PERFED AND RECEMENTED BY COIL AND PRIOR TO MWD RUN 3, A CLEAN-OUT RUN WAS MADE, DURING WHICH THE INTERVAL 12220'MD - 12240'MD WAS DRILLED WITHOUT MWD. 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 7. MWD RUNS 1 - 3 REPRESENT WELL CD2-55 WITH API#: 50-103-20463-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15238IMD/7344'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS $ File Header Service name............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/10/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY 1 and clipped curves; all bit runs merged. .5000 .' PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ START 1 2776.0 2790.5 2790.5 2790.5 2790.5 2790.5 2810.5 ~H STOP DEPTH 15183.0 15190.0 15190.0 15190.0 15190.0 15190.0 15238.0 ') # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: BIT RUN NO 2 3 MERGE TOP 2776.0 12220.0 MERGE BASE 12220.0 15238.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing................... ..60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order 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 2776 15238 9007 24925 2776 15238 ROP MWD FT/H 0.11 548.77 153.645 24816 2810.5 15238 GR MWD API 32.27 418.89 99.1124 24815 2776 15183 RPX MWD OHMM 0.07 1586.26 7.14923 24800 2790.5 15190 RPS MWD OHMM 0.06 2000 7.4589 24800 2790.5 15190 RPM MWD OHMM 0.06 2000 7.90378 24800 2790.5 15190 RPD MWD OHMM 0.02 2000 10.8456 24800 2790.5 15190 FET MWD HOUR 0.19 1626.78 6.64384 24800 2790.5 15190 First Reading For Entire File......... .2776 Last Reading For Entire File.......... .15238 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... "\ version Number.........., \.0 Date of Generation...... .Oij10/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/10/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPS RPM ROP $ 2 ) header data for each bit run in separate files. 2 .5000 START DEPTH 2776.0 2790.5 2790.5 2790.5 2790.5 2790.5 2810.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 12185.5 12177.5 12177.5 12177.5 12177.5 12177.5 12220.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): 21-JUL-03 Insite 66.37 Memory 12220.0 2810.0 12220.0 38.2 87.4 TOOL NUMBER 124725 163840 8.500 2796.0 LSND 10.00 38.0 9.0 400 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: 6.6 ) 1.500 85.0 .830 159.8 1.600 85.0 2.200 85.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O Name Service Order 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 2776 12220 7498 18889 2776 12220 ROP MWD020 FT/H 0.45 548.77 172.899 18820 2810.5 12220 GR MWD020 API 37.91 418.89 113.176 18820 2776 12185.5 RPX MWD020 OHMM 0.07 1586.26 5.86654 18775 2790.5 12177.5 RPS MWD020 OHMM 0.06 2000 6.05228 18775 2790.5 12177.5 RPM MWD020 OHMM 0.06 1586.55 6.207 18775 2790.5 12177.5 RPD MWD020 OHMM 0.02 2000 6.91014 18775 2790.5 12177.5 FET MWD020 HOUR 0.19 164.49 0.791826 18775 2790.5 12177.5 First Reading For Entire File......... .2776 Last Reading For Entire File.......... .12220 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/14 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 ") Physical EOF File Header Service name............ .STSLIB.003 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/14 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 3 ') header data for each bit run in separate files. 3 .5000 START DEPTH 12178.0 12178.0 12178.0 12178.0 12178.0 12186.0 12240.5 STOP DEPTH 15190.0 15190.0 15190.0 15190.0 15190.0 15183.0 15238.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: #' TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERIS 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: # 29-SEP-03 Insite 66.37 Memory 15238.0 12220.0 15238.0 85.4 93.1 TOOL NUMBER 129046 159439 6.125 12210.0 Flo Pro 8.80 44.0 9.0 16000 4.6 .260 .120 .230 .380 72.0 163.4 72.0 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): ) ') # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth 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 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 12178 15238 13708 6121 12178 15238 ROP MWD030 FT/H 0.11 525.01 93.2124 5996 12240.5 15238 GR MWD030 API 32.27 101.55 54.9622 5995 12186 15183 RPX MWD030 OHMM 0.24 1504.79 11.1463 6025 12178 15190 RPS MWD030 OHMM 0.26 1505.7 11.8422 6025 12178 15190 RPM MWD030 OHMM 0.6 2000 13.1913 6025 12178 15190 RPD MWD030 OHMM 5.53 2000 23.1091 6025 12178 15190 FET MWD030 HOUR 0.44 1626.78 24.8798 6025 12178 15190 First Reading For Entire File......... .12178 Last Reading For Entire File.......... .15238 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name.. . . . . . . . . . . .LISTPE Date. . .. . . .. . . . . . . . . . . . . .03/10/14 Origin. . . . . . . . . . . . . . . . . . . STS ~" .~ " Tape Name.. .......... .... }NOWN ) Continuation Number..... .01 Next Tape Name.. ........ .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/14 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