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206-118
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:WNS Wells Integrity Eng Subject:10-426 form for CD4-pad SI non-witnessed MIT-IA 6-17-25 Date:Wednesday, June 18, 2025 8:25:00 AM Attachments:image001.png MIT CRU CD4 PAD SI TESTS 06-17-25.xlsx Morning, Please see the attached 10-426 form from the CD4-pad SI non-witnessed MIT-IA that was performed on 6-17-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com &ROYLOOH5LYHU8QLW&' 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2061180 Type Inj N Tubing 1900 2265 2305 2310 Type Test P Packer TVD 7130 BBL Pump 3.2 IA 510 3300 3235 3230 Interval V Test psi 3000 BBL Return 3.2 OA 1 5 5 5 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2071010 Type Inj N Tubing 320 3280 3235 3225 Type Test P Packer TVD 7161 BBL Pump 7.2 IA 325 3300 3245 3240 Interval V Test psi 3000 BBL Return 7.2 OA 1 3 3 3 Result P 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 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 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 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 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 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 TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD4 PAD Non-witnessed Van Camp 06/17/25 Notes:MITIA to maximum anticipated injection pressure per AIO 18C.003 AMENDED Notes: Notes: Notes: CD4-17 CD4-322 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA to maximum anticipated injection pressure per AIO 18C.005. LTSI: Tubing has open pocket, CMIT T x IA to 3000 psi to prove integrity. Notes: Notes: Form 10-426 (Revised 01/2017)2025-0617_MIT_CRU_CD4-17 9 9 9 9 9 99 999 9 9 9 -5HJJ CD4-17 MITIA AIO 18C.003 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 CD4-17 50103205340000 2061180 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD4-17 COLVILLE RIV UNIT CD4-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 CD4-17 50-103-20534-00-00 206-118-0 W SPT 7130 2061180 3000 1871 1871 1869 1871 24 61 61 59 REQVAR P Adam Earl 6/18/2023 MIT IA tested as per AIO 18C.003 amended from 1.2x max Inj. 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 CD4-17 Inspection Date: Tubing OA Packer Depth 680 3330 3280 3270IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230620133701 BBL Pumped:3.3 BBL Returned:3.3 Thursday, July 27, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg ` P.I. Supervisor�(�,'e, Fell j('ZzZ� FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD4 -17 COLVILLE RIV UNIT C134-17 Src: Inspector Reviewed B�y: � P.I. Supry �-'�I`-- Comm Well Name COLVILLE RIV UNIT CD4 -17 API Well Number 50-103-20534-00-00 Permit Number: 206-118-0 Insp Num: mitLOL210611142104 Rel Insp Num: Inspector Name: Lou Laubenstein Inspection Date: 6/11/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - - - Well CD4 -17 'iT a In� � 7130 Tubin 2225 - 2230 I TVD T 0 Tubing zzzs zzzs PTD 2061180 --}-- 3300 '� SPT'!Test sl 3000 IA 1370 yp Test I T--- 3260 3255 - BBL Pumped: --- - z.a 'BBL Returned: 2.4 OA as ns _ - — — los 96 — [ntery -e REQVAR !p/F P Notes: MIT -IA to Maximum Anticipated Injection pressure per A1018C.003 Thursday, June 17, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor ""y� �(�� FROM: Adam Earl Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 2, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD4 -17 COLVILLE RIV UNIT CD4 -17 See: Inspector Reviewed By: P.I. Sup" J (L NON -CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD4 -17 API Well Number 50-103-20534-00-00 Inspector Name: Adam Earl Permit Number: 206-118-0 Inspection Date: 6/19/2019 , IUSp NUm: mitAGE190623115342 Rel Insp Num: Packer Depth Well ci � 1 . iTyp�TVD 7130 } PTD zo6nso Type TessttI Ty SPT Test psi i 2900 BBL Pumped: 3.5 BBL Returned 34 Interval I REQVAR P/F I P Notes: MITIA tested as per AIO I8C.003 to MAID Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 189- 1897 1897 '� 1897 � IA 180 9300 3260 3240 OA 12 31 - 17, 24 Tuesday, July 2, 2019 Page I of 1 • w MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r� DATE: Thursday,February 08,2018 P.I.Supervisor (f SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD4-17 FROM: Brian Bixby COLVILLE RIV UNIT CD4-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry j'`— NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD4-17 API Well Number 50-103-20534-00-00 Inspector Name: Brian Bixby Permit Number: 206-118-0 Inspection Date: 2/3/2018 Insp Num: mitBDB180207113741 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min � CD4-17 Type Inj W '!.TVD 7130 g' 2275 2275 - 2275 2275- --. Testpsi 3000 Tubing r 300 3300 3260 Well , � t BBL Pumped: Type, BB SPTIL Returned: {, 3.4 OA 66 345 . 247 I 32 203 PTD 2061180 l T-- j Interval REQVAR P/F j P , Notes: AIO-18C.003 Test pressure was 3000psi as per AlO to test to maximum anticipated injection pressure. SCANNED �t Thursday,February 08,2018 Page 1 of 1 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, November 27, 2017 8:12 AM To: 'NSK Well Integrity Supv CPF3 and WNS' Cc: Senden, R.Tyler Subject: RE: CRU CD4-17 (PTD 206-118) Request for 30-day monitor on Water Injection Rachel, Approved for restart and 30 day water injection for monitoring and diagnostics. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK Well Integrity Supv CPF3 and WNS [mailto:n2549@conocophillips.com] Sent: Friday, November 24,2017 6:54 PM To:Wallace, Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:CRU CD4-17 (PTD 206-118) Request for 30-day monitor on Water Injection Chris, CRU CD4-17(PTD 206-118) is an injector with Administrative Approval to inject water-only due to TxIA communication that appears during gas injection. On June 21,2015,a shallow surface casing leak was discovered and reported. The well has been shut-in since that time. Diagnostics suggest the leak is"42" below the OA valve. The well recently passed a shut-in MITIA to 3300 psi that was performed on June 9, 2017 and witnessed by inspector Bob Noble during the UIC MIT pad-test for CD4(previously submitted 10-426 attached). CPAI would like to bring the well on water injection for a 30-day monitor period to confirm the present condition of the well and gather the data necessary to submit a request to amend the current Administrative Approval. The amendment request would be to allow continued water-only injection with a known surface casing leak to atmosphere, in addition to the previously identified TxIA communication when on gas injection. At this time,CPAI believes the tubing, packer, and intermediate casing in this well have the integrity necessary for water injection. Do we have permission to restart water iniection and proceed with a 30-day monitor? Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. SCANNED Office:907-659-7126 Cell:907-943-0450 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 19,2017 TO: Jim Regg �'tfy 2. / P.I.Supervisor f ` SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-17 FROM: Bob Noble COLVILLE RIV UNIT CD4-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD4-17 API Well Number 50-103-20534-00-00 Inspector Name: Bob Noble Permit Number: 206-118-0 Inspection Date: 6/9/2017 Insp Num: mitRCN170611170159 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-17 ' Type Inj N TVD 7130 - Tubing 1475 1940 1940- 1940 PTD 2061180 J Type Test SPT Test psi 3000 - IA 130 3300 - 3260 - 3250 - BBL Pumped: 3.7 ' BBL Returned: 3.7 ` OA 0 6 3 2 Interval REQVAR P/F P ✓ Notes: MITIA per AIO 18C.003 to max anticapted injection pressure of 3000 psi ✓ • SCORED AUG, 2 22017 Monday,June 19,2017 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, June 21, 2015 8:04 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Alpine WAG injector CD4-17 (PTD #206-118) Report of OA x Atmosphere communication Attachments: image001.png; CD4-17 90 day TIO trend 6-21-15.JPG; CD4-17 wellbore schematic.pdf Chris, Alpine water injector CD4-17 (PTD 206-118) was discovered to have OA x Atmosphere communication today. The well has been shut in and freeze protected. CPAI intends to perform diagnostics to locate the leak point and determine potential repair options. Upon conclusion of the diagnostics a follow up email with the plan forward along with any required paperwork will be provided. Attached are a wellbore schematic and 90 day TIO. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor SCANNED JUL 0 2 2015 ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager (907) 659-7000 pgr. 123 .WELLS TEAM ConocoPhillips Horn: NSK Problem Well Supv Sent: Fr. ay, June 05, 2015 5:54 AM To: 'Wallace, Chri _CDOA)'; Regg, James B (DOA); aogcc.inspectors@alaska.gov; phoebe.brooks@alaska.gov Cc: Senden, R. Tyler Subject: RE: Alpine WAG injector 7 (PTD #206-118)Water injection monitor period update 1 June 15 Chris, Attached is the MIT form for the MIT-IA performed on 5/6/15. Please know if you need anything else. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor �. ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 1 W > j aaa ' Ha N i_ 11.1 W0 Q D fn c, r- O CO CO'- -C COS a u_ t• O p y O kfi O O W Lli M O O co CC rn LSD r— i a v o a, Z _y W E N '— N O u-, 6,.., N O CD G N N C N In LC) X17 LC! O▪ O O O YJ LV N N N p 7 L7-, ,1?, C.?, CD �� N- N- N- N- awl -C -t r W�++ 0000 0000 0 O 0 ABap "- 'J O [O O O O O (p V .r-..',t O U, f.,.:, Al_ ) Y! a) 1 ) ) - C C U C asI 7 0 + o u, N cy V io ; C C 7 O WI a) 0 Z c Q U, u, u, a— 6 6 • 1 O N 6 en 0) N ! i : t V N Ni M CD CL a r aS 03 III IA U, P I @ = to 0 0 0 0 0 0 0 0 0 aim # 4- U; O U, O U, O U, O Ui t Y, o v r, r, n, Nu .- Odle viaw A@Z lad ` WNS INJ CD4-17 ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Aa Btm(ftKB) tmr' h.Ihp, 501032053400 ALPINE INJ 94.27 15,044.03 17,975.0 -.- Comment H2S(ppm) Date Annotation End Date KB-Ord(R) 'Rig Release Date CD4-17,6/9/20159:53:05 AM SSSV:WRDP Last WO: 37.17 10/4/2006 Ventral schematic(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ADD WAIVER NOTE hipshkf 6/9/2015 II CasingStnngs Going Description '013(in) ID(In) Top(ROMB)'Set Depth KB) 'Set Depth(TVD)...'Wt/Len(I...Grade Top Thread CONDUCTOR 36" 16 15250 34.0 114.0 114.0 65.00 H-40 HANGER,31 7ir Insulated Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I SURFACE 95/8 8.835 33.8 3,009.3 2,386.8 40.00 L-80 Casing Description GD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'WtlLen(1...'Grade -Top Thread 1 18F INTERMEDIATE 7 6276 33.5 13,334.2 7,490.6 26.00 L-80 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) -Set Depth(TVD)...'Wt/Len(I...Grade 'Top Thread • OPEN HOLE 6 1/8 13,334.0 17,975.0 Tubing Strings 110- /{ Tubing Description String Ma...ID(in) Top(FMB) Set Depth(tt..J (IMO Depth(TVD)(...Wt(IMGrade Top Connection Tubing-Water INJ 4 1/2 3.958 31.7 11,825.61 7,163.4 12.60 L-80 _ Completion Details Nominal ID ' ' °'A Top(ftKB) Top(TVD)(FMB),Top Incl(') Item Des Corn (in) 31.7 31. 0.00 HANGER FMCO TUBING HANGER 3.958 CONDUCTOR 38'Insulated; 2,261.9 1,981.5 55.49 NIPPLE CAMCO'DB'NIPPLE 3.812 34.0-114.0 11,753.0 7,130,2 61.93 PACKER BAKER PREMIER PACKER 3.875 11,813.3 7,157.9 63.32 NIPPLE HES'XN'NIPPLE 3.725 11,824.3 7,162.8 63.58 WLEG WIRELINE ENTRY GUIDE 3.875 NIPPLE;2.251.0 /-t Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) VALVE;2.262.0 - Top(TVD) Top Incl Top(ftKB) (ftKB) (') Com Run Date , ID(in) 2,262.0 1,981.6' 55.49 VALVE 3.81"A-1 INJECTION VALVE(S/N:HRS-44) 9/2/2012 1.250 Mandrel Inserts St ati I on Top(TVD) Valve Latch Port Size TRO Run l To (ftKB) Make Model OD(in) Sero Type Type (in) (pet) Run Date Com 1 9,119.2 5,713.7 CAMCO CBG-2 'GAS LIFT DMY BK-5 0.000 0.0 11/16/2007 2 11,646.7 7,078.5 CAMCO "KBG-2 1 GAS LIFT DMY BEK-2 0.000 0.0 11/16/2007 SURFACE;33.85,000.3 Notes:General&Safety End Date Annotation 10/3/2006 NOTE:TREE:FMC 4-1/16"/5,000 psi-TREE CAP CONNECTION T'OTIS 12/6/2009 NOTE:View Schematic w/Alaska Schematic9.0 6/9/2015 NOTE:WAIVERED WELL T x IA COMMUNICATION.WATER INJECTION ONLY. GAS LIFT;9,110.2r--i ____ __— GAS LIFT,116467I" __ PACKER:11,753.0psi NIPPLE,11,813.3id WLEG;11,824.3 INTERMEDIATE;33.5-13,334.2 OPEN HOLE;13.334.0-17,075.0 cit-i7 Regg, James B (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday,June 05, 2015 5:54 AM To: Wallace, Chris D (DOA); Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Senden, R.Tyler Subject: RE: Alpine WAG injector CD4-17 (PTD#206-118)Water injection monitor period update 1 June 15 Attachments: MIT CRU CD4-17 Diagnostic MIT-IA 5-6-15.xls Chris, Attached is the MIT form for the MIT-IA performed on 5/6/15. Please let us know if you need anything else. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. SCANNED JU201 Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 &EL.LS TEAM conectiphinips From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Thursday, June 04, 2015 9:40 AM To: NSK Problem Well Supv Cc: Senden, R. Tyler Subject: [EXTERNAL]RE: Alpine WAG injector CD4-17 (PTD #206-118)Water injection monitor period update 1 June 15 Dusty, We are progressing the AA application. Please provide the MITIA of 05/06/2015 re - enced in the AA in the appropriate MIT form 10-426 to the distribution list on the form so that I may use it for the . niversary date. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`"Avenue / Anchorage,AK 99501 (907)793-1250(phone) / (907)276-7542 (fax) chris.wallace@alaska.gov /+ CONFIDENTIALITY NOTICE:This e-rrklil message, including any attachments, contains information from the Alaska Oil and Gas Conservati Commission (AOGCC), State of Alaska and is for the sole use of the intended 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to- pm.regq@alaska.gov AOGCC Inspectors@alaska goy phoebe.brooks(rDalaska qov chns.wallace(dialaska qov OPERATOR: ConocoPhillips Alaska,Inc. ' Eg 6/5,i 5 FIELD/UNIT/PAD: Alpine/CRU/CD4 Pad DATE: 05/06/15 OPERATOR REP: Hollandsworth AOGCC REP: N/A Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min. Well CD4-17 - Type In) W ' TVD _ ' 7,130' Tubing 1,813 1,814_ 1,815 1,815 Interval 0 P T.D. 2061180 - Type test P - Test psi ' 1782.5 Casing 1,107 '3,000 - 2,984 ' 2,982 P/F P - Notes: Diagnostic MIT-IA OA 30 30 30 30 Well. Type In/ TVD Tubing Interval P T D Type test Test psi Casing_ P/F Notes: OA Well Type lnj TVD Tubing Interval I P T D. Type test Test psi Casing P/F Notes: OA Well Type In) ND Tubing Interval P T D i Type test Test psi -Casing P/F Notes: OA Well Type Int. ND Tubing Interval P T D Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes 1 D=Drilling Waste M=Annulus Monitonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT CRU CD4-17 Diagnostic MIT-IA 5-6-15 xis Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, June 01, 2015 4:07 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Alpine WAG injector CD4-17 (PTD #206-118)Water injection monitor period update 1 June 15 Attachments: image001.png; CD4-17 90 Day TIO plot 6-1-15.JPG; CD4-17.pdf Chris- Alpine injector CD4-17 (PTD#206-118) is nearing the end of the AOGCC approved 30 day water injection monitor period. The well passed the initial diagnostic testing of an MIT-IA, IA DDT and T& IC pack off tests. During the monitor period the tubing and inner annulus did not show signs of communication therefore demonstrating TxIA integrity while on water injection. It is CPAI's intention to apply for administrative approval for water injection only due to TxIA communication while injecting gas. The well will be left on water injection while the AA is in process and will be added to the monthly report. Please let us know if you have any questions or disagree with the plan. Attached are a 90 day TIO plot, well bore schematic and a copy of the AA justification packet for reference. Dusty Freeborn I Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907)943-0450 .111,WELLS TEAM ConocoPhillips SCONE° JUN 0 9 2015 From: NSK Problem Well Supv Sent: Sunday, May 03, 2015 9:55 AM To: Wallace, Chris D (a0A) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Alpine WAG injector CD - PTD #206-118) Report of IA pressurization Chris, Alpine WAG injector CD4-17 (PTD#206-118) currently on miscible injection is exhibiting signs of IA pressurization. CPAI plans to WAG the well to water as soon as reasonably possible or shut in the well until resources become available to do so. The well will be placed on a 30 day monitor period, while on water injection. DHD will perform initial diagnostics to include an MIT-IA, IA draw down test, and pack off tests. At the conclusion of the diagnostics and monitor period the proper notifications and paperwork will be submitted to the AOGCC for continuedction or corrective action. A 90 day TIO and wellbore schematic are attached. Please let us know if you have any questions or disagree with this plan. Regards, 1 W _U > - anaa i- CC CC CC www a U - Ur- o In 6d �t L v: s O W MCe M CO O O a r a o N 2 N w N W N O (O 2 Lo O M O. N N 11 kr) kr, w O O O 2 N N N cc lri ri r- r- -J r- J "t f "f U., 0 0 0 !JAB a U U U U U U U - W .71 4111 1 C v, O u, V ❑ z u O Y c R O1 ti `f9 M) c r O et N N 0 en e- CD _ U a _— a M CO u, I l ( i l NO O U U U O U U W U O O O U U u O O u O U7 U. U U UI i Odle Wall !Sd C N ❑ w Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, May 03, 2015 9:55 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: Alpine WAG injector CD4-17 (PTD#206-118) Report of IA pressurization Attachments: image001.png; CD4-17.jpg; CD4-17 90 day TIO 5-3-15.JPG Chris, Alpine WAG injector CD4-17 (PTD#206-118) currently on miscible injection is exhibiting signs of IA pressurization. CPAI plans to WAG the well to water as soon as reasonably possible or shut in the well until resources become available to do so. The well will be placed on a 30 day monitor period,while on water injection. DHD will perform initial diagnostics to include an MIT-IA, IA draw down test, and pack off tests. At the conclusion of the diagnostics and monitor period the proper notifications and paperwork will be submitted to the AOGCC for continued injection or corrective action. A 90 day TIO and wellbore schematic are attached. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne/Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. E� �+ 201 Desk Phone(907) 659-7126 Pager(907) 659-7000 pgr. 123 Ar:ELLS cELTEAM 1 mimik o c o o Jap o Ti �� �, i� o 0 0 0 o u, cls CO r-- cs,�' I I I I I I I I I JCO W' U, maU \\ ,_ may. 0 \C—\\..\sol 1 L.1 C CO ▪11,1 3 CO C r' u1 CO iti▪, 03 03 0 .0 7 E E o V I` ifi 1113 4 114 .1 ...N.,. ) Li', T. jkV in LL N kr' w- ,e— . e-- d N O CI Os N in V i G =p, 7 j 2 H m 1 I U U E a 1 I I I I a ar -, ti' C. mss sw 0 0 0 0 0 0 0 0 0 0 R3 D6VOC Z c QD o 0 0 0 0 0 0 0 o r+' + ' U... o u) o u) o u) o u) Odle 10iOW t N •t ti r, r) N N f r- 5. CACIIil Isd WNS CD4-17 ConocoPhillips a Well Attributes Max Angle&MD TD • Alaska.In. Wellbore API/l1WI Field Name Well Status Incl(") MD OMB) Act Btm(RKB) GorgcaPralllpa 501032053400 ALPINE INJ 94.27 15,044.03 17,975.0 Comment 025(ppm) 'Oct.' Annotation End Date KB-Grd(ft) Rig Release Date "• SSSV:WRDP Last WO: 37.17 10/4/2006 _ Wall Confg-CD4-17,9/15/2012 1n.n831 AM '...... Sdromatic-Actual Annotation Depth(MB) End Dab Annotation Last Mod...End Date Last Tag: Rev Reason:SET INJ VALVE ninam 9/15/2012 Casino Strin o s Casing Description Siring 0... String ID...Top(WB) Set Depth It..Set Depth(TVD)...String Wt..String...String Top Thrd CONDUCTOR 36" 16 15.250 34.0 114.0 114.0 65.00 H-40 Insulated ■ Cain Description 0... String ID...To 1K8 Nibe Depth 0...Set Depth(ND)... String Wt..',String...String Top Thrd CasingString 9 PI 1 P B SURFACE 9 5/8 8.835 33.8 3,009.3 2.386.8 40.00 L-80 HANGER.32 r Caning Description String 0... String ID._TOP IftKB) iMt Depth 1/...Set Depth(TVD)... Siting VOL..'String...String Top Thrd INTERMEDIATE 7 6.276 33.5 13,334.2 7,486.9 26.0.0 L-80 Casing Description String 0... Shing ID_.Top(ftKB) Depth( String 9...' g P SMnStan To Thrd ',OPEN HOLE 6 1/8 13,334.0 17,975.0 Set Depth(/...Sat NDI... Wt.. Tubing Strings Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND) String Wt..:String... String Top Thrd Tubing-Water INJ 41/2 3.958 31.7 11,825.6 7,163.3 12.60 L-80 Completion Details Top Depth (TVD) Top Ind Top(MB) (KS) I') Rem Description Comment ID(in) 31.7 31.7 0.00 HANGER FMCO TUBING HANGER 3.958 _hi 41111.111111.11.Ma 2,261.9 1,981.5 55.49.NIPPLE 'CAMCO'013*NIPPLE 3.812. CONDUCTOR • 11,753.0 7,130.2 61.90 PACKER BAKER PREMIER PACKER 3.875 38'Insulated. .—_: 34-114 11,813.3 7,157.6 63.32 NIPPLE HES'XN'NIPPLE l 3.725 11,824.3 7,162.7 63.58WLEG WIRELINE ENTRY GUIDE 3.875 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) NIPPLE,2,282 Top Depth VALVE.2.282 (TVD) Top Ind . lI Top(RKB) ( B) (•) Description Comment Run Dab ID(10) 2.262 1,981.6 55.491l VALVE 3.81"A-1 INJECTION VALVE(S/N:HRS-44) 9/2/2012 1.250t�i Notes:General&Safe _ End Date Annotation 10/3/2006 NOTE:TREE:FMC 4-1/16"/5,000 psi-TREE CAP CONNECTION 7"OTIS 12/6/2009 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE Al L 34-3,009 t--i tic;.,.P I GAS LIFT. 9.119 l I i GAS LIFT. 11,847 I I: PACKER. 11,E53 R. I NIPPLE.11.813 L 1 Mandrel Details MEG.11.824 Tap Dept Top I Port (ND) Incl OD Valve Latch Size TRO Run SM Top(MB) (RKB) (") Melte Model lin) Serie Type Type lin) (psi) Run Dab Cont.. 1 9,119.2 5,714.2 57.52 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 11/16/2007 2 11,646.7 7,078.5 60.07 CAMCO.KBG-2 1 GAS LIFT DMY BEK-2 0.000 0.011/16/2007 i i, . [ NTERMEDIATE, 33-13.334 OPEN HOLE, 13,334-17,975 • TD,17,975 • • Image Project Well History File Cover Page XHV7_E 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 tar are viewable by direct inspection of the file. ~~ ~ - ~ ~ ~ Well History File Identifier Organizing (done> Two-sided III IINIIIIIII IIIII ^ Rescan Needed III II~IIIIIII III~II RE AN DIGI L DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ~Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Date: ^ Other:: lsl BY: aria ~~ Date: ~ ~ ~~ ~ ~ ~ /s/ Scanning Preparation ~ x 30 = BY: Maria Date: Production Scanning + ~~~ =TOTAL PAGES__~~ (Count does not include cover sheet) i n /s/ Y r Stage 7 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: I j'~ D V /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I (I II I I II ae=~,,,~.o iiiiuiiiimmii BY: Maria Date: /s/ Comments about this file: o~,,~.~~e~,~ iiiiumimuuu f P 10/6/2005 Well History File Cover Page.doc Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, January 12, 2012 9:29 AM To: 'Nelson, Tim J' Cc: ALP DS Lead and Simops Coord; Neville, David J; ALP Ops Maint Supt; Pysz, Nick P Subject: RE: CD4 -17 (PTD 206 -118) Tim, Please file a 10-404 outlining the steps you have taken to back -flow the well (CD4 -17) and converting it to production. Our records indicate it has been on a water injection cycle for some time... You will have to do your best to allocate production between the two twinned wells over the flowback period. If the backflow continues for more than a couple of weeks please update me. Hopefully this will help the drilling folks out. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) NNED l= E_F3 1 5 LUIZ 444 -3433 (cell) From: Nelson, Tim 3 [mailto: Timothy .J.Nelson @conocophillips.com] Sent: Thursday, January 12, 2012 9:08 AM To: Schwartz, Guy L (DOA) Cc: ALP DS Lead and Simops Coord; Neville, David J; ALP Ops Maint Supt; Pysz, Nick P Subject: CD4 -17 Guy, This is to let you know that CD4 -17 injection well, at Alpine, was converted to production early this morning about 02:30. This was accomplished using hardline and a choke skid routing the fluids to an adjacent producer, CD4 -16. The operation is manned 24 hours a day. The conversion was driven by a kick taken on Doyon 19 drilling well CD4 -27. It is expected that well will be on production Tess than 2 weeks. If you need any further information please call. Thanks Tim J. Nelson Subsurface Development Staff Production Engineer WNS- Alpine St Phone: 907 - 265 -6859 S Fax: 907 - 265 -6715 1� Email: timothy .j.nelson@conocophillips.com 1/12/2012 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 05, 2011 TO: Jim Regg Z P.I. Supervisor y ' 1 )4 ' I! SUBJECT: Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA INC CD4 -17 FROM: Matt Herrera COLVILLE RIV UNIT CD4 -17 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 3 NON- CONFIDENTIAL Comm Well Name: COLVILLE RIV UNIT CD4 -17 API Well Number: 50- 103 - 20534 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFH110701082956 Permit Number: 206 -118 -0 Inspection Date: 6/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4-17 Type Inj. W ' TVD 7130 ' IA 400 1840 ' 1806 1802 P.T.D 2061180 " T ype Test i SPT Tes ps I 1 782 - OA 7 10 725 725 725 Interval 4YRTST P/F P - Tubing 2278 2277 2275 2273 Notes: IA tested to 1800psi 1.8 BBL's Tuesday, July 05, 2011 Page 1 of 1 • ,. _ ~ ~ ~,F ~ _.~ ~~^ Ak„ ~~~ ~;_ :~ '~'~ .. ~~ ~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc r~ ~ MEMORANDUM T~~ Jim Regg P.I.Supervisor~P~,q ~'~pl~~ Z~ FROM: Bob Noble Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 29, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-17 COLVILLE RIV LJNIT CD4-17 Srr. Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: COLVILLE RN LTNIT CD4-17 Insp Num: mitRCN090729085340 Rel Insp Num: API Well Number: 50-103-20534-00-00 permit Number: 206-118-0 / Inspector Name: Bob Nobie Inspection Date: ~/23/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ CD4-17 Type Inj. W 'r~ 7130 TA ]060 3030 ~ 2988 2984 p.T.D 2061180 TypeTest SPT Test psi 3030 QA 357 409 408 407 Interval 4YRTST p~` r / Tubing 2190 2190 2191 2192 Notes: ~~i /~ ~-~°S~- /~ rz°4~; v~ ( 2~ Z p 5'~ ~ ! '~ie ;"y' , f~rfn .. ., ~ ~, k - .a~ . ._ .. w Wednesday, July 29, 2009 Page 1 of I r • • ~,: ConocoPhillips ~as~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 ~~~. Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~'~t$~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 18~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sinc Perry iucin ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Well Name PTD # Initial top of .cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18/2009 CD4-306 207-094 SF NA 5" NA 1.70 3/18/2009 CD4-07 207-118 SF NA 6" NA 0.42 3/18/2009 CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 CD4-210 206-077 SF NA 7" NA 1.27 3/18/2009 ~ CD4-211 ' 206-153 9" NA 9" NA 3.82 3/18/2009 CD4-214` 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 ~ 206-157 5" NA 5" NA 2.55 3/18/2009 CD4-16 206-131 SF NA 5" NA 2.55 3/18/2009 4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321 206-142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18/2009 ~-P N e / DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061180 Well Name/No. COLVILLE RIV UNIT CD4-17 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20534-00-00 MD 17975 TVD 7491 Completion Date 10/4/2006 Completion Status 1-OIL Current Status WAGIN UI~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neutron (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tvoe Med/Frmt Number Name Scale Media Nn Start Stnn C:H Raraivart ('nmmnnte ED C Lis 14218~uction/Resistivity 2959 17975 Open 11/9/2006 GR, NPHI, RHOB, FCNT, ', ~ DRHO, NCNT, ROP w/Graphics 'i ED D Asc D~i ectional Survey 0 17975 Open 11/9/2006 ED C Lis 15009"Induction/Resistivity 2959 17975 Open 4/17/2007 LIS Veri, GR, NPHI, RHOB, FET, FCNT, DRHO, NCNT, ROP w/Graphics Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y /~1 Chips Received? ~A1~ Analysis Received? Comments: Compliance Reviewed By: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~N Formation Tops ' %/ N Date: ~ ~~CEIVEC7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~AY 2 ~ ~(~[~~ REPORT OF SUNDRY WELL OPERATION"~~aa ®d & Ges t^.nnc r,,.-.._ 1.Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~itl~l'8t~@ ~-~„ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ -~~- Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ ~u• 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhillipS Alaska, InC. Development ^ Exploratory ^ 206-118 ' 3. Address: Stratigraphic ^ Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20534-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 56' CD4-17 ` 8. Property Designation: 10. Field/Pool(s): ADL 380075 and 380077 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 17975' - feet true vertical 7491' ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2953' 9-5/8" 3009' PRODUCTION 13278' 7" 13334' OPEN HOLE 4641' 6 1/8" 17975' Perforation depth: Measured depth: Open Hoie true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 11825' MD. Packers &SSSV (type & measured depth) Baker Premier Packer Packer= 11753 SSSV= Camco'DB' Nipple SSSV= 2262' 12. Stimulation or cement squeeze summary: _ ~ ~ ~~~~ ~ ~ 7Q~~ Intervals treated (measured) ~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data GD7~IIUefIG~~°~ ~ ~~~~' ~~~ Oil-Bbl Zc~ Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 324 2257 2011 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _ 16. Well Status after proposed work: Oil^ Gas^ WAGQ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-289 Contact Jack Walker Printed Name Jack Wal er Title Production Engineer k r'v`. Signature /~ L%~:~ ~~ ~ ~'° ~ Phone 265-6268 Date `~~~-A rr ~~ - rreoareo oy reanne r+aas coo-a4rv v . ~y~~~~~iAL 5.~.~a Form 10-404 Revised 04/2004 ~511~ Submit Origi' n nl 'Oli ~t I MEMORANDUM Toy Jim Regg P.I. Supervisor ~~~ ~ ~ ~~~~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 22, 2008 SUBJECT: Mechanical Integrity Tests COtiOCOPHILLIPS ALASKA iNC CD4-17 COLVILLE RIV iJIvIT CD4-(7 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv--~-~ Comm Well Name: COLVILLE RN UNIT CD4-17 API Well Number: 50-103-20534-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG080406I55936 Permit Number: 206-t 18-0 - Inspection Date: 4/5!2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 NTin. 45 Min. 60 Min. Well ~ cDa f7 TypeInj. ~' ' TVD i i ------~ nso ~ IA Is6s ~ Is6s ~ fa6s I iloo I foes doss _ P T ~ 2061180 !T eTCSt SPT ', TBSt S1 ~ 1860 ~ OA j 515 ~ 515 ~ 490 490 515 ! 485 rvITAL P ~ Interval P/F Tubin zl9o ~ zl9o ~ g~ _ zi9o ~ z~9o 2I9o zl9o Notes' Initial witnessed test. IA pressured up when I arrived, observed pretest conditions for thirty mi nutes with no change. Bled IA to 1100 psi and observed for additional thirty minutes with no change (after stabilization). Good test which was repeated today at my request. ~ Tuesday, April 22, 2008 Page 1 of 1 ConocoPhillips CRU Initial MIT Regg, James B (DOA) Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] f~ J Sent: Saturday, March 29, 2008 2:45 PM \~~~' ~ ~ ~ y D ~ To: Fleckenstein, Robert J (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips CRU Initial MIT's Attachments: MIT CRU CD3-114 03-26-08.x1s; MIT CRU CD4-17 03-26-08.x1s «MIT CRU CD3-114 03-26-08.x1s» «MIT CRU CD4-17 03-26-08.x1s» Attached for your records are the initial waived State witnessed MITIA's for the CRU CD3-114 and CD4-17 wells. Please contact me at your convenience if you have questions or comments. Martin Walters ConocoPhillips Alaska, Inc. Problem Wells Supervisor Office 907-659-7224 Cell 907-943-1720 Pager 907-659-7000 #909 4/1 /2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. ~~~ ~' I t' ~~ FIELD /UNIT /PAD: Alpine /CRU /CD4-17 DATE: 03/26/08 OPERATOR REP: Mike Graves AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. Well CD4-17 Type Inj. W TVD 7,130' Tubing 1844 1843 1842 1841 Interval I P.T.D. 2061180 Type test P Test psi 1783 Casing 1317 2484 2469 2462 P/F P Notes: Initial state witnessed MITIA OA 374 481 470 465 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9!1/05 2008-0326 MIT CRU CD4-17.xfs ~ ~ L~ U SARAH PAL/N, GOVERNOR CO~c~ttR~j~*O ~ ~ I ~ 333 W. 7th AVENUE, SUITE 100 -7L ~tsii l.~~jj•••~~~itt~~'1ii1i---777 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Schneider Production Engineer Conoco Phillips Alaska Inc PO Box 100360 Anchorage, Alaska 99510 Re: Colville River Field, Alpine Oil Pool, CD4-17 Sundry Number: 307-289 Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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. DATED this ~ day of December, 2007 Encl. Sincerely, ,.. ~~~ G~,~o -off ~ 1~EGEIVEC~ STATE OF ALASKA ~~P ~ ~ 2QO7 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVka oil & Gas Cons. Cafrlmissiofl 20 AAG 25.280 Alvn~nrn.,.. 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ e p~~ Change approved program^ ~ Pull Tubing ^ Perforate New Pool ^ yy Re-enter Suspended Well ^ 7~'~~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: k, 7~, ~ ConocoPhillips Alaska, InC. Development Q ~ Exploratory ^ 206-118 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20534-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q CD4-17 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380075 and 380077 RKB 56' Colville River Field /Alpine Oil Pool ' 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17975' 7491' Casing Length Size MD TVD Burst Collapse GONDUCTOR 114' 16" 114' SURFACE 2953' 9-5/8" 3009' PRODUCTION 13278' 7" 13334' OPEN HOLE 4641' 6 1/8" 17975' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Open Hole 4-1/2" L-80 11825' Packers and SSSV Type: Packers and SSSV MD (ft} Baker Premier Packer Packer= 11753 l ~ ~~~~ ~ ~ SSSV= Camco'DB' Nipple SSSV= 2262' ~ ~ llr~ '~~ ~C~~cC`t.-CRI~c 13. Attachments: Description Summary of Proposal ^ ^ 14. Well Class after proposed work: ~ 0 ~' << Detailed Operations Program BOP Sketch ^ Exploratory ^ Service Development q• 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider Printed Name Tlm SC ne' er Title: Production Engineer Signature Phone 265-6859 Date % ~ -O ~, Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Q Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: APPROVED BY ~~ ~y r ~" ~ Approved by: OM ISSIONER THE COMMISSION Date: ` Form 10-403 Revised 06/2006 ~ ~~u~,,~` ~ ~ ~~ 9~j'o~Su~~~~~ I,N./, ~ 2-~CHANICAL .INTEGRITY R :FORT . c~O ~o ~- ~~~ ~~ - °UD u=-=~ _ ~ ~r.~'~'l~ Cc. OPER ~ FIELD ~.~:i-~~-= ~ \~~ti+-°~ ..~G rE~I~S_.. 1~Oti-~ Cv i;r.LL NUMBER C.~ ~-~~ LL DA T ~ TD . ~''L~y'1S~ 2~.. ~~~L~ TVD ; ?ETD _ .---` ?~D '?'VD Cas ink : ~. Shoe : «~~ MD ~~~ ~ T~TD ; LV : .~ ?,~ "'"' .-s~-~ =w.,er . - Shoe : '~ T~TD ; .Cr . ?•~ ~'';D '- =u~i~~: ,`) Packer 1~'1~~>''~ TTil; Set et i ~Ss~--Co ole Size ~~ and `' Perfs O fc ii to 1~0~ _ .. _ '`.%'r'.~?~IC~~, iNT£GR?TY - PART #I ~.nnulus ?ress Test: _? CoQe:~ts 15 nin ~ 0 min. ,~ '~' CHP N 1 C~.l, INTEGRITY -PART # Z ~ ~`~S \rccc 1 ---9t ~ ~ c1 hb ~~ t SS's ~~ \ -°'r ~ ~-~ bb ~ 5 Cement Voltziues:. A~t_ Llner ~~ Csg DV ~ Cwt Jol to cover hers ~-3~~0'`~ S ~'1. ~~~~ Sy~~CZE~` `_r rc _ eoretycal TCC ~- 3~~8 ~5 ~' ~S~yVt . Cement Bond Log (Yes or Nod ~LS In AOGCC File~LS CBL Evaluation, zone above perfs R~yJ t'~,sp~~~. sows c~~.~- ~~~ ~~~~ p i~ ` 'moo ~c~~~~ --` Production I.og: Tyne Evaluation ~ - CONCLJS ~OtdS : ?arm :1: - . ?art r 2 : ~"l~ i ~ ~ ~~ `~ ~~.`~ t~~ ~~~c~\v ~ F ~ ~~C Summary by Month: Individual Well Production Well Name: COLVILLE RIV UNIT CD4-17 API: 50-103-20534-00-00 Permit to Drill: 2061180 Operator: CONOCOPHILLIPS ALASKA INC Field/Pool COLVILLE RIVER, ALPINE OIL Sales Cd: 12 Acct Grp: 4 Final Status: 1-OIL Current Status: WAGIN 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Days 8 28 12 pal 0 0 0 Wtr 6,356 36,690 15,114 Gas 2,877 7,102 2,815 2007 Totals: Oil 0 Water 58,160 Gas 12,794 Cum Oil 0 Cum Wtr 58,160 Cum Gas 12,794 ~~~ ~i +~~`O ~ ~1~~~ "l~c~ ~-~ ~~ ~-\ ~~ly ' ~ ~ ~ $~ ~ ~,~c~ r ~ r ~ ~ - `~ ~ ~ ~ n ASS ~ --~ ~~~ --~ a4~~ ~ ~~~ ~~ ~'`~~~ ~ ~ i~ ~ ~~- ~ ~~. -~c~S~ ~ ~~~~ c~~. ~; ~ `cam Wednesday, September 05, 2007 l ~( Page 1 Summary by Month: Individual Well Injection /Disposal Well Name: COLVILLE RIV iJNIT CD4-17 API: 50-103-20534-00-00 Permit to Drill: 2061180 Operator: CONOCOPHILLIPS ALASKA INC Field/Pool: COLVILLE RNER, ALPINE OIL Sales Cd: 12 Acct Grp: 4 Final Status: 1-OIL Current Status: WAGIN 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Shut-In Shut-In Shut-In Shut-In Days 0 0 0 0 Wtr 0 0 0 0 Gas 0 0 0 0 2007 Totals: Water 0 Gas 0 Cum Wtr 0 Cum Gas 0 • Wednesday, September O5, 2007 Page 1 Page 1 of 2 Maunder, Thomas E (DOA) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Friday, September 21, 2007 9:50 AM To: Maunder, Thomas E (DOA) Subject: RE: CD4-17 Cement bond log Tom, I just talked with Rob. He also brought up the 11800-11900 area. It looks like that is the KUR C sand. Hopefully we will get to talk to Rob later. I can conference you in with him or you can give him a call. Which ever is easier for you. Liz From: Maunder, Thomas E (DOA} [maitto:tom.maunder@alaska.gov] Sent: Thursday, September 20, 2007 10:50 AM To: Galiunas, Elizabeth C; Haas, 3eanne L Cc: Schneider, Tim S. Subject: ltE: CD4-17 Cement bond tog Thanks Liz. 1 will be out of the office for a bit, but will get together with Rob hopefully later today. Tom From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophitlips.rom] Sent: Thursday, September 20, 2007 10:45 AM To: Maunder, Thomas E (DOA); Haas, 3eanne L Cc: Schneider, Tim S. Subject: RE: CD4-17 Cement bond tog Tom, I just -eft you a message. Rob Kaylish can give you a better explanation than I can of the log. The geologist confirms that at 12490' is the Alpine Top. the LCU is at 11900'. I attached the rest of the tops for you to look at if you like. let me know if you have more questions. Regards, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 From: Maunder, '~he~[mailto:to Sent; Thursday, September AM To: Galiunas, Elizabeth C; Haa anise L Cc: Schneider, Tim S. Subject: RE: Cement bond tog 12/20/2007 Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, September 20, 2007 9:22 AM To: 'Galiunas, Elizabeth C ; Haas, Jeanne L Cc: Schneider, Tim S. Subject: RE: CD4-17 Cement bond tog Liz, Thanks for the log. I am not as familiar with this log as others and may need some help with interpreting. The reports that Jeanne sent indicate that it was not possible to move the pipe while circulating or cementing. It appears that the actual pumping operations went well and no lost returns are noted. I have a couple of questions 1. Looking at the log presentation, is the "redish strip" down the log indicative of a channel? 2. What zone occurs at about 11900? Based on the change in the VDL, I'd say this could be the Nanuq- Kuparuk. 3. Is the top of the Alpine about 12500? Thanks in advance, Tom Maunder, PE AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Tuesday, September 18, 2007 4:51 PM To: Maunder, Thomas E (DOA); Haas, ]eanne L Subject: CD4-17 Cement bond log Tom, this is a well we used the BAT Sonic tool one. Jeanne, I will print one off for our well file. Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-2b5-6247 Cell: (907)-441-4871 9/20/2007 Page 1 of 1 Maunder, Thomas E (DOA) From: Haas, Jeanne L [Jeanne.L.Haas@conocophillips.com] Sent: Wednesday, September 19, 2007 11:05 AM To: Maunder, Thomas E (DOA) Cc: Galiunas, Elisabeth C; Schneider, Tim S. Subject: RE: CD4-17 7" casing details Attachments: 20070919093906_001.PDF; 20070919092753 001.PDF; 20070919092747_001.PDF; 20070919092744_001.PDF Tom, Attached is a two page Cement Detail report and Daily Drilling Report for CD4-17. Jeanne From: Maunder, Thomas E (DOA) {mailto:tom.maunder@alaska.gov] Sent: Wednesday, September 19, 2007 9:49 AM To: Haas, Jeanne L Cc: Schneider, Tim S.; Galiunas, Elizabeth C Subject: RE: CD4-17 7" casing details Thanks Jeanne. I guess I wasn't clear in my request. What I'd like is the cementing details rather than the casing details. Sorry for any confusion. Tom Maunder, PE AOGCC From: Haas, Jeanne L [mailto:Jeanne.L.Haas@mnocophillips.com] Sent: Wednesday, September 19, 2007 9:17 AM To: Maunder, Thomas E (DOA) Cc: Schneider, Tim S.; Galiunas, Elizabeth C Subject: CD4-17 7" casing details 9/19/2007 ~ ~ F ~ Cement Detail Report CD4-17 ~ Producf3on Casing Ct+lrlt~nt Prknary.bb .tom catagogr - Date ~ Date En Date DrNfing Support -Capital Web Intervention 10142390 1017/L006 10Ri2006 Additives ype tratiwr Conc label Y1,..• i . l Description Objective Top (ifKB) (ftKB) ~ Ra4rm? t Rtne (... Top Plug? P~,rg? Production Casing Primary 5,575.0 6,663.0 No Yes No t! ) (bb{fmin) Q (~9) ~ P (~) ~ Reeip9 stroke (~ Rotated? Pipe RPM (~ 7 a 7 450.0 2,z1o.o No IVo pth tagged (ttiC6) Tag Metlrod DePih Plug DrMed tAR o comment Pumped through stage collar ~ 6663' Cernent•F.ltlydS & Additives".. _ _ Fluid... _:..:_.,~.... z:::. _ :.1.'" _ h ~ Florid Type Flukl Desdtption op (ttKB) Est Bhn ) Amowd (sacks) dame Pumped CV4N100 90.0 Yield Mbr ti1D Free (X) Dens6y P V (cp) 9 '} 8.30 Additives Type orx ,...:-_ ~. purd .:~ -... __ ..._:. ...- _:.. + Fkpd Type Desaipiion EstinrMed Top ~IC ) Eat Bbn (~ Amount (sacks) Vokune Pumped {tdd) Mud Push 21.0 (i tl~ Ratio (gailsa... roe YYater ) Density l Plastic op - 10.50 t Additives Ctration Urtti -. • ....x ,... -... .. .. . ~..~, .. . . . ~ . .. F[ Type Fluk! D~eription Esd Top ) Btrs ) (sactw) Vottane Pumped (bbt) Tail Cement 5,575.0 8,663.0 196 G 40.0 Ykdd (gaifsa._ Free Weser ('K) Duty q-) TlNdoeefkrg (fma) _ 1.11 5.10 15.80 Additives Ad~ive Gorrc tJnti label ~: y Y - Fkid Type Fk~id Descripdton Top (ttiC6) Estt36n (}!KB) Amount (sacks) lass Volume P water 20.0 F~ WrI ) 1 ~ 8.30 Additives .... .- •. ..,. .. _ _ ._ .- .: -:. .r~ ~_:. ..~.:5x :•:. ... w.., ". _ ......- .:..y:. r 1' ::. }: d Top Estl~n {iBB) (sacks) ohmre Purt~sd (Wrl} mud ~r,p - (cp) 10.00 Addittves lhdt I~Si i .. Report Printed: 10/12!2006 I I E f. f i ~ , Daily Drilling Report CD477 Report Date: 9/24120 Report umber Daps From (days) Start ) ~ Etd {ftIC6j pgPtl! i 14 93.00 13,345.0 13,345.0 0.00 CD417 FiMd Type Target ) 9112!2006 DOYON 19 ALPINE 0~ 17,041.0 E f Total AFE Amount Average ROP tt~l 10142389 6,215,564.00 Larzt (ietdC~ng (~ NextCastngSatOepth ) intsmsetliSte,13,334.2itKB ~ uW P~ i$ 9 eP~ Ctanmu Cost Laying doom 5° D.F. 460,177.18 3.424,704.84 r orec~t [lady Cum M Coat LD D.P. - MU r out easy. - PU 4° D.P, 8,014.18 377,208.64 Last?AIN rY Run and cemerrt 7" csg - General Remarks 34 f H!W ~ 2 nglh Courd 50.0 Don Mtdcey Rig Supervaor Dare Surrey Rg Srlttervfsor . 9'.. :: r - n - - - '~ ~ .~ n 1. ,y . tiY$ ..;~R796d _l'iOOB 'x. ,~T `;.`R!~°%? iYilB F _ f ~ s aTiW 4xRC -. \• ~ ••"' . { _ ..... . . ., : , / . : ... .. ... .r.-.. ..a _ : r .:.:. ~ -... -:h :.:- 00:00 00:30 0.50 iMRMt CASING P . _ ` . Z,773.0 3,196.0 } un 7" 28~ L-80 BTCM casir-g from 2774' to 3196' (75 jts iotai 00:30 01:00 0.50 1 tNG IRC P S,t98.0 3,196.0 Circ casing voitane - 5 bpm /350 psi 01:00 05:00 4.00 I 1 CA 1 RNCS P 3,196.0 7,450.0 Run 26~ L-80 BTCM casing from 3195 to 7050' ~ jts total) :00 06:00 1.00 I 1 C P 7,050.0 7,050.0 Stage pumps up 2 bent J 400 ao 5 - BiJ - F 520 psi 06:00 10: 4.75 I CASING RN 7,050.0 10,899.0 un 7" -80 B'TCi4A casing 7050 to 1 ,899' (255 JLs • total ) 10:45 12:30 I 1 NG CI 10,899.0 10,899.0 Stage purr>(us uP 2.5 bpm J 650 psi bo 5 bpm - U - F P 700 psi - PUW 280k SDW 160K 2:30 18:00 3.50 1 ING RNCS P 10, .0 13,334.0 Run 7° 28~ L-~ BTCM 9 from 10,899' to 13,297' (311 jts total) - PUW 385K 50W 170K - MU FMC fluted hanger and LJ -Land hanger in wellhead wRtt Shoe ~ 13,334', FC ~ 13,245' and insert baffle ~ 13,201' 16:00 18:30 0.50 tV'fRf+Ai C~kAEiVI' PULD P 13,334.0 13,344.0 Lay down !~ up root - clown top dove -rig rlp camera #tead 18:30 19:00 2.50 ( 1 CfltC P 13,344.0 t3, .0 S~ pun~ls up to 8 6prr - ctrc c~nddion 780 psi -780 bNs pumped - Ftekl PJSM wf t7owefl and tx+ear 19: 21:30 2.50 !WT'RM1 CEMENT P 3,344.0 13,344.0 7" csg as :Pumped 5 bbls CW100 - sated to 4400 psi - ptar~ted 45 bbd of CW400 4.0 bpm ~ 500 psi- M6a3d & pumped 40.t~ts MtrdPush ~ 10.5 ppg - 4.9 BPM i~ 575 Psi -Mined and pumped 129 bbd of lead slurry LBSCRETE ~ 11.0 ppg ~ 5.5 bpm / 815 -389 psi - A~taed 8~ 5. g ~ 8 ) 1 ~ ~ t ~ ~ 5.11 13PM >~ 340 Psi Dropped top piug bbLg Dovwefl - sw~Ched to ~ pumps & displaced orr~t w/ 10.0 ppg mud ~ 7 BPwA for 415 bbis /580 -840 psi- 6 bpm for 62 bbls / 790 -940 psi and 4 tlpm / 750 -770 psi ~ 12 btlis pumped - 509 bbis told di~lacerrtent -Bumped plug w/ 1200 psl -Check floats OK -CIP ~ 2130 rus.- Fufl returns throughout - No pipe moment 21:30 22.•30 1.00 1 Cl 3, .0 6,665.0 reasons up on ca~ng -Stage shifted open wf 3600 psi - C'acand wnd mud 5 bpm f 330 psi -prepare for sewnd stage c:errlent opts Latest B(?P Test Dffia r=:_. - .... ._ ~_. Paps 112 Report Prfrrted: 10/1212006 a t ~ ~ Daily Drilling Report - -~ CD417 ~ . Report Date: 9@4/2006 ti. ~...: ;. . ~,,.,~;•'- zfi 'rinse: ~.~_ -~::,r =; ~,: ~ ° ,_, ~ :,u::: - _s.: "31 ip~ "~~....~, T e - P `' P N ' ~ ~ t ~ ' , i ~~'' n ? • an ._ 9~se ~ Ctlde ' -T_ T~bi Cndeti: )- >. ~5 ,~ y ~- 3 ..~. `~ ~ 22.-30 23:30 1. iNTFtM1 CF7JIEPiT l)ISP P 6,655.0 6,665.0 Second Sfage ownent opts as fotiows: Pumped 10 bbls GV1l1~ - 3.5 bprn ~ 202 psi-Muted $ pump~l 2D bbis MudPush ~ 10.5 ppg - 4.8 BPM ~ 275 psi -Mixed $ ptunped 4U 4 bbis tati starry (Glass G wladddiv~) -15.8 ppg ~ 5.1 t3PM ~ 290 - 100 psi - t}roped tcpkslos>n9 Ph+S w120 bbls weber ty Dannrek - switd~ed to ~ pumps $ displaced cmt as 10.0 ppg mud ~ 7 BPM for 225 [GIs /215 -570 psi -then 4 bpm / 420 -450 psi last 10 ~ pumped - 255 bbis total d~plar~ment -Bumped p~ wd 2690 psi (2240 psi over final displacemerrt pn3ss.heid 5 mfiutes) - CiP ~ 2330 hrs: Full returns throughout - No pipe movement -annulus static 23:30 00:00 0.50 1 C ENT RURD P 6,665.0 6.665.0 blow dovm lines - t2D t~rr~nt head Mud.t~ .. ~ •: redc•i>~a: :\'e -, 4 ~- • v ..\. :S:'^`.:Yg~ ~%[`!: '- - I ..g.. .,. .::S -~ ..~,....c ~t i:e~ . ...... 2y_3?;+. ::: - ....... .... .. ....~ ,.+. ._... ~ ' ' [ :.~'F°..%tt:Srt:`k :'Y yj~,, i' 00 ? - - - - ~ - ~ ~r'iC1f.. . : . ,+. ,P.V,QBIC' .~.:> 4+A`!C' ~~..{ tom"! "~'J.:. .' .: ~T (~)` ._ s ~ .t~ - • ~ _ ~'~):-Y^. i SND 13,345.0 10.00 45 1 .0 21.OD0 9.000 11.0 12.000 Z0.0 7.2 9.i t ,tom i ...._ . :_i.,~, ~..=:..-r ", .. v .._ ...~.;.,:;A ~-ti >:` , -~r ~. " Water Based Mud 5~.0 CD1-19 0 CD4-17 r~~'e .: ~'.s..e~' .: ,' 110/~5/{M W.r a> 4 :.:L::.w^ i Z• ~-.; j~~":". ~S1.3E' .mJ. i:...t. _L _'Y~ 4~ .: si : "ks.., r ' CD4-17 501032053400 :~... ~_ ~ ..... .:.t .' .. ~. :~ COND1 ~ 37.0 i 14.0 St~2FAC 121/4 114.0 3,020.0 9112!2006 9/'1412006 IIYi'RM1 83/4 3,0.0 13,34,5.0 9/17!2006 9/22/2006 FRODi 61/8 13,345.0 19,975.0 9!21/2006 10!'1/2006 ..y _ r-!Mlr1t.; :s-z' ia -.~ -.ry ;ice '- .r~:~ > ~ ...,.., .,-. .u„~ti~" _ r.<-.' •i~:t _ ~, ~- - - _ Production Cass Cement - Started 8/24tZ006 Try Ceraeirt i using CD4-17 Intermediate,13,334.2RtCB ~ Q 1 -.. F ~j {psi) 1 Production Casing Cement 9,450.0 13,334.0 4 7~.0 _ ...__,F. ,~.,_,. ..- _ ... ~ _ erx ~ . CW-100 50.0 8.30 Mud Push 40.D 10.50 Lead Garners! LiteCreta 218 130.0 11.00 3.35 9,450.0 12,600.0 Tati Cement G 158 34.0 15.80 1.16 12,BOO.D 13,334.0 W 20.0 8.30 Mud 489.0 1D.00 ~9 ToP ~ BWto1rt ~1 t~ t~ P 2 Produr~ori Casing 5,575A 6,663.D 4 450.0 _ : - • ._. - r.e. lama ^-°•" .,` aP ). _ CVW100 10.0 8.30 Mud Push 21.0 10.50 Tati Cement G 196 40.D 15.80 1.17 5,575.0 6,863.0 water 20.0 8.30 mud 235.8 1D.00 Page 2l2 Report Print; 10/12/2006 • • Cement Detail Report CD417 Piroductfon Casing C~rterit DRlWI~ ORIGINAL .Iob chary DRN.UtVG ~ RFE 10142369 Start 9/112006 ~ i 9!'122006 Date 10/412006 .. .... . .t... ~. i , t'ludut~lon Caste Cement C18 S~ ~ 9124200619:00 CJ ~p~~~ GW l ~i 9124/200823:38 CD4-i7 Comment . ..~ ... .. . - °'-3ei ~L 3''..' r i7 @; 7F. I:.a ~.-i° i..i:i~:. k..,.-. `..?'....":..'.: .....•, ..Sa" «..cJ. -.t Yu _ _ _ .Y.. - Production Casing pr&nary 9,450A Cement Q (starq ) Q tom) Q t~ (~~) P ( (!~ 7 4 7 769.0 13,334.0 Yes 0.0 P ~) ipsA Recip? Stroke 1,x00.0 No Y~ No (~ No ag 1letirod Dried Out To ) Comment Vi9~tR~i Fluids ~B Additives'=-`'Tia,',, ~ n+? Y y.; . - . -, - ri- y ~ry ~~y . w. .. ._. z :. . ~ .a a.. ..... t:...:'t~. .f. , r., ... t.~a..:. . ~~ Type CW 100 wed rop ) Est eba hate) Amornrt mks) c vow Purred •`~-0 Yield HZO Ratio (galfsa._ Free Yl ) ~~•Y 8.30 ~~~ ~s~~y t~ - Tkne hns} 7 (ps Additives >~ ~ } ~ ~ ~ S~ ..aa ~,a i~USti Fkdd tipamr Ta- ~) atin ) tsars) class Purt~ed l~ 40.0 ne 10.50 cp T~{Urs- 7 ~ Additives Adr6tive type Certlon tkrA label - ... a.: 'z :: -' - - Fluid:. : ~s ~ , _ - - - FlrrTd lead cement Top ) 9,450.0 Est Sbn 1a,soa.o Amaart ) z16 Class L~eCrete N 130.0 YfNd 3.35 fgeNsa.- 11.20 11.00 Pia~(c Vtarxrsby (op) ~S ) Additives Addaive type Concenbatrmt Cone ~ry~tl~'~ x a r... •. .: .t...e ..r. .~ .'. •..tv ,S. riYlY' - .> }. .~•. t' W . 'Y .: ~iv.: .. '. 'v: ~ kluid Type Tai Cement 1.18 Field Ratio 5.09 ESfHnabed Top (itllB 12,600.0 ree Est 61m (RKB) 13,334.0 15.80 Amamt ) 156 toP! C G Tine i vohene Pumped 34.0 'I tpsn Additives Type thrtr 1 . ,,,, ,..A "'. _ _ ... __ 8 ' • Type water Fluid Esarrrebed Top ha03) Bbn Amount (seeks) Ctass okrme Pumped t~i zo.a air t9~-- ~~ 6.30 tq~i AdcBtives Type Carxsntratimr aid. ~ii'.v' r L ~~. _ -~t .3 z ~'~_ _ . o-`_`~: 7 i ~ .ukl Type Alkxi Fluid Top ~) Est Hbn has$) Amount (sacks) Ck~ Pumped 489.0 Yield Radio 10.00 cp} ties) 4 Report Priri~d: lonzrmo6 • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, September 18, 2007 4:16 PM To: 'Schneider, Tim S.' Cc: 'Allsup-Drake, Sharon K'; Davies, Stephen F (DOA); 'Haas, Jeanne L ;Roby, .David S (.DOA) Subject: RE: CD4-17 (206-118) Tim, We have received the sundry application. I need to request some additional information. 1. Would you please supply the 7" casing cementing report? 2. Was a bond log run? I did not find anything in the operations summary indicating a bond log was run. If a bond log was run would you please supply a copy? Electron is fine. Thanks in advance. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Thursday, September 06, 2007 9:02 AM To: Schneider, Tim S. Cc: Allsup-Drake, Sharon K; Davies, Stephen F (DOA); Haas, Jeanne L; Roby, David S (DOA) Subject: RE: CD4-17 (206-118) Tim, You don't need any authorization to use the well to monitor pressures. You can do that with the classification as a development well (1-oii) or a service well (WAG). Due to the interference information, it sounds like there are no plans to produce or inject into the well in the near future, correct? It is CPAI's option as to the how to classify and operate or not operate the well. Key item is if you wish to classify the well as an injector, then a 403 is needed. Call or message with any questions. Tom Maunder, PE AOGCC From: Schneider, Tim S. [mailto:Tim.S.Schneider@conomphillips.com] Sent: Thursday, September 06, 2007 8:51 AM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K; Davies, Stephen F (DOA); Haas, Jeanne L Subject: RE: CD4-17 (206-118) Tom, Your records are correct and we have not submitted a 403 to convert CD4-17 to an injector. Thank you for your kind reminder. I'm preparing a letter of request to leave the well SI based on the interference testing which indicates direct communication with the CD2-56 well to the North of CD4-17. The request will be to convert the well to a MWAG injector; Status: SI. We currently have the CD2-56 and CD2-54 injectors shut-in (Both northern in-line injectors to CD4-17) for reservoir pressure management for the drilling of CD4-07 (To spud possibly Sunday, Sep. 9th). We have not injected any water into the CD4-17 well. We'd like to monitor the surface pressure on CD4-17 until we complete drilling CD4-07 (recently permitted Alpine "A" well just West of GD4-56} to help us monitor the regional pressure's until we drill CD4-07; if permissible. Once the CD4-07 is TD'd, we'll run a plug into CD4-07. I'll include this request in the letter. Would the State be agreeable to this plan of action? 9/18/2007 . Page 2 of 2 thanks again Tom for the reminder. Regards, Tim S. Schneider Subsurface Development Staff Production Engineer WNS-Alpine Q Phone: 907-265-6859 '~ Fax: 907-2656472 P~ Mobile: 907-632-8136 O Email: timsschned_erC~cono_cophillipscom From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, September 05, 2007 11:19 AM To: Schneider, Tim S. Cc: Allsup-Drake, Sharon K; Stephen F Davies Subject: CD4-17 (206-118) Tim, I was just looking at this file and noted that I did not find a 403 to convert this well to .injector (service-WAG). The weft was permitted as an injector (8/11/06), but since it would be pre-produced was completed as a producer (development-1-oil) with an effective date of 10/4/06. You obtained a sundry to conduct some production testing without a SSSV (306-359) on November 20, 2006 and according to the production record produced for a total of 48 days from about January 24 -March 12, 2007. You submitted infiormation regarding the testing attached to a 404 dated 4/4/07. On the 404, you have "before status" checked as development and after status as development-WAG. A 404 is the correct form to use when reporting a conversion, however as 1 indicated i don't find a sundry requesting the change. There is an email in the file dated October 11 where the proper forms needed are noted. Would you check your files to see if I've missed something? I believe a 403 to convert the well is needed. I also note that it appears that there has not been any injection into the well at least through July 2007. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 9/18/2007 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, September 05, 2007 11:19 AM To: 'Tim Schneider (tim.s.schneider(ci3conocophi0ips.com)' Cc: 'Allsup-Drake, Sharon K ; 'Stephen F Davies' Subject: CD4-17 (206-118) Contacts: Tim Schneider Tim, I was just looking at this file and noted that 1 did not find a 403 to convert this well to injector (service WAG). The well was permitted as an injector {8/11/fl6), but since it would be pre-produced was completed as a producer {development-1-oiq with an effective date of 10/4/06. You ob#ained a sundry to conduct some production testing without a SSSV (306-359) on November 20, 2006 and according #o the production record produced for a total of 48 days from about January 24 -March 12, 2007. You submitted information regarding the testing attached to a 404 dated 4/4107. On the 404, you have °before status checked as development and after status as development-WAG. A 404 is the correct form to use when rel~rting a conversion, however as I indicated I don't find a sundry requesting the change. There is an email in the file dated October 11 where the proper forms needed are noted. Would you check your files to see if 1've missed something? I believe a 403 to convert the well is needed. I also note that it appears that there has not been any injection into the well at least through July 2007. Thanks in advance. Call or message with any ques#ions. Tom Maunder, PE AOGCC 9/5/2007 i • WELL LOG TRANSMITTAL To: State of Alaska April 17, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-17, AK-MW-461234 CD4-17: LIS & Digital Log Images: 50-103-20534-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIl~TG THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~tSaOg STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations Q Stimulate ^ Other ^ f / Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ ~~v Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ f ~ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ij ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 206-118 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20534-00 ' 7. KB Elevation (ft}: 9. Well Name and Number: RKB 56' CD4-17 ` 8. Property Designation: 10. Field/Pool(s): ADL 380077, 380075 Colville River Field /Alpine Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 17975' ~ feet true vertical 7491' ' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2953' 9-5/8" 3009' PRODUCTION 13278' 7" 13334' OPEN HOLE 4641' 6-1/8" 17975' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-112" , L-80, 11825' MD. Packers &SSSV (type & measured depth) Baker Premier Packer set at 11753' SSSV= NIP SSSV= 2262' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbf Casin Pressure Tubin Pressure Prior to well operation na na na na na Subsequent to operation 578 1583 na 220 14. Attachments 15. Well Class after work: ~ ~ Copies of Logs and Surveys run X Exploratory ^ Development Service Q'S Daily Report of Well Operations _ 16. Well Status after work: Oil^ Gas^ WAGQ ~ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: contact Tim Schneider Printed Name Tim Schneider Signature ~"'-~~~~/~ Title Phone Production Engineer 265-6859 Date ~~~1G' ~ ~ Pre ared b Jeanne t. Haas 263-4470 Form 10-404 Revised 04/2006 ~ ~. ~~~ ~ 0 2DQ7 ~~o~ ~~ Submit Origi ~Iy/ ~°Y<f'N~ D~ e an ate Hours Oil Gas Water Li uid Choke GOR TGOR GlR WC WHP WHT GL Rate CD4-17 A 03/12/2007 6.0 0 578 1583 1583 l00! 365 999 999 100.00 220 75 10041 CD4-17 A 02/20/2007 26.1 0 412 2107 2107 100 196 441 441 100.00 220 75 517 CD4-17 A 02/19/2007 12.0 0 395 2401 2401 100 164 399 399 100.00 220 75 564 _ CD4-17 _ A 02/18/2007 12.0 0 659j 0 1122 100 587 649 649 _ _ 0.0 220 75 69 • • Alpine Well Pressure Survey Data Well CD4-17 CD4-17 10/12/06 4,385 Unit CRU Reservoir Alpine Gauges In 10/12/06 9:00 Gauges Out 1/14/07 22:00 SI Elapsed Days 94.5 2269 hrs Service Co. Panex Test Type Interference Testing Gauge Type & ID Panex Upper GAU-1038 Calibrated Gauge Type 8~ ID Panex Lower GAU-1039 Calibrated Wireline RKB Depth Depth 0 11813 • Pressure Reading Temp Reading SS Upper Lower Upper Lower Depth 3,582 3,585 157 157 56 4,453 4,406 161 150 7,102 7" Shoe 13,334 7,435 Estimated Pressure at the casing shoe Estimated Pressure at Datum 7,000 WHSIP I nitia I 1900 Final 1900 IA Initial 0 Final 0 OA Initial 0 Final 0 Gradient Fluid Temp Grad psi/ft p~q deg/ft 0.4400 8.5 4,576 11.84 4,385 12.05 Pressure 3,500 3,700 3,900 4,100 4,300 4,500 0 1,000 - ~ - -- + UPeer 2,000 ~ ^ Lower 3,000 • Datum 0 4,000 5,000 - 6,000 - 7,000 -- ----- 8,000 • Well ~ CD4-17 CD4-17 C_D4-17 _ CD_4-17 Sample Time ___ ; 1/27/2007 2/7!2007 ! 7 /2007 2 1 2/23/2007 Well Test Watercut % 100 . 100 _ _ _ _ 100 __ 100 omments The well watercut is 100% and the sample is from the wellhead. Sample appears to be SW but there are some differences, manganese, (phosphorous, silicon, zinc (see winter STP SW composition). ! iAppearance: Clear aqueous sample. There was clear hydrocarbon layer visible on surface of this sample... possibly diesel, not crude oil Descriptor Wellhead Production fluid- unknown water test sep Temperature Degrees F 85 _ ~ Pressure PSIG 220 _____ SPGR @60 Degrees F i 1.0263, 1.0257 1.0258 ' 1.0258 pH ! _ 7.18 ~ _ 8.03 7.9 9 7.9 Conductivity micro-mhos/cm 366001 36100 ____ . Not Available __ Ortho-Phosphate ppm _ _ ; Bicarbonate mg/I 421 903' _ __ _ 0 879 Carbonate mg/I 0 0 1052 _ 0 Magnesium mg/I 941 817 1052 ] _ _ 976 Aluminum mg/I 0.2 < 0.1 <0.1 I <0.1 Strontium mg/I 8.9 8.4 _ ~ 12 _ 11 Sulfate mg/I __2250 _ 2070 ____ _ 1989 __ 1900 Boron mg/I 4.4 4 6 6 Butyrate mg/I _ __ Chromium mg/I ___ ~ < 0.2 < 0.2 <0.2 _ _ <0.2 Lithium mg/L ____' 1 ; 1 , 0.8, _ 0.8 Manganese mg/I 0.13 0.182! ________ 0.256! 0.093 __ Phosphorus mgll 0.6 0.2 _ ~ 0.6 ____ 0.6 Propionate mg/I _ _ ___ ____ Silicon mg/I _ _ 14 ____ 10 _ ___ _ __ 17 _ 19 Sodium mg/I 9191 8423 ~ _ ______ 11090 __ 10160 Acetate mg/I Barium mg/I < 1 < 1 _ <1 _ <1 _ Calcium mg/I 393 361 496; 467 Chloride mg/I 17950 17850 17135] _ 16600 Formate mg/I j ~ _ _ Iron mg/I < 0.5 1' 1.3 0.2 Potassium mgll 114: 436 690 706 .Sulfide mg/I Not Analyz Not Analyzed Not Available Zinc m /I !! <0.1 < 0.1 0.2 <0.1 Re: CD4-17 Water sampling results questions ~ ~ Subject: Re: CD4-17 Water sampling results questions From: Dave Roby <dave_roby@admin.state.ak.us> Date: Tue, 13 Feb ?007 11:07:09 -0900 ~--Q (~ --- ~ ~ ~' 'To: "Schneider, I~im S." ~=.L.im.S.Scht~eia~;r@,conocopi~illiPs.com-= CC: Thomas Maunder <lom^uzundcr~~l~admin.state.aku~=~, Stephen F Davies ~~=stcvc da~~ics~'~i;admin.stalc.akus== Tim, Thanks for the thorough answers and quick response. This resolves all the questions I had. Dave Schneider, Tim S. wrote: Dave, Presently, only STP water is injected at the CD2 pad. All produced water is commingled with STP water and injected in the CD1 wells. The Sulfate content ranges from 26 to 4000 mg/1 depending on the time of year the STP water sample is taken. The Summer STP water is lower in sulfates (fresher water) than the winter sample (-2000 - 4000). Looking at our produced water from CD1 & CD2, the sulfates are in the 400-800 mg/1 range. Log analysis indicated the drilled OH interval to be wet. Differentiating between below a water-oil contact vs. being swept could not be determined from the resistivity data. The toe of the well indicates a fault may exist. As for running a spinner or any other production logging tools, we've had a poor history of success running production logs of any kind in the Alpine OH horizontal wells. Coiled Tubing can't reach due to friction in the open hole and "tractor" technology just hasn't proven itself in the open hole environment; yet. ', Based on the pressure interference testing, I believe the pressure ', response between CD2-56 and CD4-17 is hours. We ran gauges in CD2-60 during the interference testing and they confirm good communication between CD2-55 and CD2-60, but no direct ', communication between CD2-60 and CD4-17. The communication is parallel to the maximum principle stress, but not in the minimum principle stress ', based on the pressure interference testing. Hope my answer's help clarify some of your questions. We hope to see some oil as we continue to produce CD4-17. we're currently performing some gaslift work on the CD4-17 well to increase the drawdown at CD4-17 to hopefully create a "sink" for the surrounding fluid to provide some indications of oil saturation in the area. Where the water has gone beyond the CD4-17 well is something our GG&RE folks are reviewing. Tim S. Schneider Subsurface Development Staff Production Engineer WNS- Alpine * Phone: 907-265-6859 * Fax: 907-2656472 U Mobile: 907-632-8136 1 of 2 2/14/2007 8:51 AM Re: CD4-17 Water sampling results questions • * Email: tim.s,schneiderzc•~nocophiliips.ccm -----Original Message----- From: Dave Roby [mailto:dave robyadmin.state.ak.us] Sent: Tuesday, February 13, 2007 9:20 AM To: Schneider, Tim S. Cc: Thomas Maunder; Stephen F Davies Subject: CD4-17 Water sampling results questions Tim, I have a few questions about the results in PowerPoint file that you sent to Tom Maunder earlier. 1) The chart on the CD4-17 water analysis shows that the sulfates are about 10 to 20 ~ less than the typical STP analysis and is showing a declining trend (if you can believe a trend from just two data points). ', According to AIO18B a mixture of STP water and produced water is injected into the Alpine Oil Pool. Do you know how the composition of this blended injection water compares to the STP water? 2) Did the logs for this well give any indication that the reservoir had been swept? ', 3) If the logs did not indicate the reservoir had been swept did they show any faulting and/or have you done any spinner surveys (or similar) to see if the water is coming from a single high perm zone or a fault? 4) It is hard to tell from the graph, but it looks like the pressure response in CD4-17 to changes in injection at CD2-56 is virtually instantaneous. Is the response truly instantaneous, or is there a small lag and if there is a lag is it consistent with what you would expect given the distance between the two wells? 5) I notice from our records that the CD2-60 well has been shut in since June. Are surface pressures recorded for this well on a regular basis and if so did they show any interference with CD2-55, CD2-56, or CD4-17? Thanks in advance. 2 of 2 2/14/2007 8:51 AM CD4-17 Results to Date • Opened well to flowback equipment on January 24, 2007. ~ -Flowed back 3168 bbls of water before putting production to the Alpine facility. - Wellhead Watercut samples still indicate 100% water (2-12-07) -Water analysis matches STP water chemistry • (Injection water) CD4-17 Results to Date • Well test: - 890 bw d 431 MCFPD 250 si WHP. ~ p p • Cum production: 17,800 BW, 7.2 MMCF • Gaslifting will begin later this week to increase production rate. • CD4-17 Produced Water Sampling Analysis mgn 2500 2000 1500 1000 soa CD4-77 0 . rti 2 0 i_ 2 ~ 2 2 ~ 2 2 ~ 0 0 o a o 0 0 0 -+-Bicarbonate Carbonate -~--Magnesium - Aluminum -,~- Strontium .. ,,. Sulfate --+:~-- @oron -~~~ Butyrate Chromium Lithium Manganese -~--- Phosphorus --~---Propionate ~--° Silicon --- Sodium -M--Acetate ~~-°~~-- @arium -+--Calcium - Chloride Formate -+-Iron -s-Potassium -~k- Sulfide -yam Zinc -~-Watercut % -,k-Event • • CD4-17 Interference Testing • Interference Testing ,~ indicates communication ~~ with C D2-56 • BHP = 4496 psi at 7101' SSTVD - 4433 psi at -7000' SSTVD Datum. (0.63 psi/ft) ~~ ~ ~m .~ . ~~ { E '" a ,~ ~ r~ ~ ~. A ~ ~- ~ ~ t~~ [~~ °-=v - ~L~d-1 T ~~~ ~.~ ~1 ~ ~ . ~' Q ~ ~ C'~ ~~ ~~:~. :f ~~e ~~ • • CD4-17 Interference Testing Analysis CD4-17 Interference Testing CD2,56 end CD2-55 injection i~f~sets soon t,,~ _ __ ~ __ _.._ asoo ti 'S '`~*eY #750 i ~~` ~ ~ j X050 ~ ~ ~ `E;.. '~ ~ ~ (' ~iiYi~~'~,~. ~ } ' 4 ~ i ' - i ~500 _~ '~ ~ .500 s P i.:i `~' i ~ 2`950 X3250 _ I a ~ ~ F _ - _ ~ ~, ~ ~ ~~ '-•~ i yl µ} ~ ' 2aao aooo '~,r' ~~ z ~ '',~~ Na CD4-17 response ~~ to CD2-5~~ t-- ry . ~ _ ~ ~p (. t$50 3730 I ~-i.~.' r.a.~ ~ \ CD4-17 response ~'~, ~~~ ~"y~..~ - ~ to CD2-56 ' ` 7 goo X500 tOr``12~OG 0:00 10~2~.~00 0:00 1t:~9~00 0:00 '1'1:2300 0:00 t2?'8G 0:00 12`.'2'1 00 0:00 tt~~"07 0:00 '1r1~ 07 0:00 E1.11iseil Trite {Days) -=- Pre~ure I,sin --- CD2-5ti Inj. Rate -+~ ~.:D255 Inj. R.tte • • Re: [Fwd: CD4-17 Water sampling-Results to Date] • Subject: Re: [Fwd: CD4-17 Water sampling-Results to Date] From: Stephen Davies <steve_davies a)admin.state.ak.us> Date: Tue, 13 Feb 2007 09:28:2.1 -0900 To: Thomas ~-launder 'tc~n1 maun~lcr(~i'_a~~min.stat<;.ak.us~=- CC: Da~~c Rohy ~~~dave roh~~~rradmir~.statc.akus==~ Well, looking back at a 2002-vintage generalized structure map, there is a prominent southeast-trending fault in the area.... Either it or a similarly trending small fault are the likely culprits. Thomas Maunder wrote: Guys, Here is some information from CPAI regarding interferance testing between CD4-17 and two CD2 wells. They feel they have proven interferance between CD4-17 and CD2-56. I don't think this is surprising given that they oppose each other toe-to-toe. I believe they felt that the area penetrated by CD4-17 appeared to be swept. It looks like their water analysis confirms this. Big question is what is allowing the water to flow southeast when there aren't offtake points in that direction. Feel free to ask Tim questions. I will forward anything else on that I receive. Tom -------- Original Message -------- Subject: CD4-17 Water sampling-Results to Date Date: Mon, 12 Feb 2007 15:43:09 -0900 From: Schneider, Tim S. <Tim.S.Schneidere~conocophiLiz~s.com> To: Tom Maunder <;tom maunderc~~admin.stat~c:.ak.us> Tom, I've attached a short PowerPoint presentation on the CD4-17 and where we're at to date. Let me know if you have any questions. Thanks «CD4-17 production data.ppt » Tim S. Schneider Subsurface Development Staff Production Engineer WNS- Alpine ( Phone: 907-265-6859** ( Fax: 907-2656472** U Mobile: 907-632-8136 + Email: tim.s.schr~eiderG%conoco hilli~,s.com 1 of 1 2/14/2007 8:55 AM CD4-17 Water sampling-Results to Date Subject: CD4-17 Water sampling-Results to Date From: "Schneider, Tim S." <Tim.S.Schneider~conocophillips.com> Date: Mon, 12 Feb 2007 15:43:09 -0900 'Tv: Tom '~~faunder <-tom il~aundcr~~r~.~idnlin.siat~.ak.us> Tom, I've attached a short PowerPoint presentation on the CD4-17 and where we're at to date. Let me know if you have any questions. Thanks «CD4-17 production data.ppt» Tim S. Schneider Subsurface Development Staff Production Engineer WNS-Alpine ~ Phone: 907-265-6859 ~ Fax: 907-2656472 ~ Mobile: 907-632-8136 Email: tim.s.schneider@canocophillips.com Content-Description: CD4-17 production data.ppt CD4-17 production data.ppt' Content-Type: application/vnd.ms-powerpoint Content-Encoding: base64 1 of 1 2/14/2007 8:55 AM • FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 995D1-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska PO Box 100360 Anchorage, AK 99507 Re: Colville River Field, Alpine Oil Pool, CD4-17 Sundry Number: 306-373 Dear Mr. Alvord: Your Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well is denied. While the construction of CD4-17 was determined satisfactory, an uncemented wellbore section lies within about 180' of the surface casing shoe of CD4- 17. If communication were to develop between the wellbores, this uncemented section could allow waste to move to shallower depths. 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 DATED this~ay of November, 2006 Encl. ~-~i5~ Note to File • CD4-17 (206-118...306-373) Colville River Unit (CD4 Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends denial of ConocoPhillips' request. While review of the submitted information indicated that CD4-17 was satisfactorily constructed and that disposal would likely occur at EMWs less than the initial surface shoe leakoff, exploration well Nanuq 3 (201-026) is only 186' distant. Nanuq 3's surface casing shoe is at about 1780' tvd in contrast to the nominal 2380' tvd depth of the other wells from CD-4. Several hundred feet of shallower production hole annulus is not cemented and if communication were established between the wellbores waste could move to shallower depths. There are documented cases where communication between wellbores has occurred with distances of about 300'. Based on examination of the submitted information, I recommend ConocoPhillips' request for the subject well be denied. ~~oa~,~.~9~ Tom Maunder, PE Sr. Petroleum Engineer November 22, 2006 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\061122--CD4-17.doc r~ LJ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE {907) 279-1433 FAX (907) 276-7542 Tim Schneider Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD4-17 Sundry Number: 306-359 Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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. ~~ ~\ DATED this2i~day of November, 2006 Encl. ~~~ < <~ ConocoPhillips November 6, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for CD4-17 Dear Commissioner: Tim Schneider Staff Production Engineer Alpine Engineering P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1768 ~~~~ V ~~ ~~v Q ~~ 2oos Alaska Oil ~ JG~~ Goys. Crrlis~ion f eR~li~~zvo ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Alpine well CD4-17. The PTD proposed this well as an injector. The log data indicates the well to be wet along the producing interval. We are planning to pre- produce this injector to determine if the area was swept from the northern injector, or if there is an oil water contact in the Alpine reservoir. The production test duration is expected to be approximately 60 days. Due to the longer flow time requirements, we are requesting approval to flow the well without a SSSV. The SSV immediately downstream of the wellhead will be in service. If you have any questions regarding this matter, please contact me at 265-6859. Sincerely, ~ /; T. S. Schneider Staff Production Engineer CPAI Alpine Engineering TSS/skad • ~ ~, __ STATE OF ALASKA l~ ~!I'~~ ~ ~' ~(~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL~~~~~a Ali ~ f ;~.k ref°~- L~~txifni~ait~n 20 AAC 25.280 ~;;"~~;'~`;~~~'~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change. approved program ^/ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4: Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 206-118 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20534-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO ^~ CD4-17 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380077, 380075 RKB 37' GL Colville River Field /Alpine Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD~ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): /'! 7~ ,0` 7~9/~ 1795 ~ 7~I1 ~ Casing t .?•~ Length Size. d'~ MD TVD Burst Collapse CONDUCTOR 114' 16" 114 SURFACE 3009' 9-5/8" .2972' ___<__- _PRODUCTIt;iIV- _ 13334' _ 7" 13297.. _ _ ._ ~ _ _ Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Open Hole from 13334' - 17975' 4.5" L-80 11826' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier Packer Packer @ 11753' 4 1!2" Camco DB Nipple SSSV @ 2262' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: ~~ Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development [~ ~//'7 Service [~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: November 30, 2006 Oil^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best. of my knowledge. Contact: Tim Schneider @ 265-6859 Printed Name Tim Schneider Title: Production Engineer Signature ~' ~ ~ Phone 265-6859 Date /~ ~ rU~o . Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representat ive may witness ~ ?3Jr " ~~ ~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clea ~i e ^ Other: SSA} N.vS~b~~~cs~~ Qt`,o~°~o pt ~ ~«~. ~ w~.~~; ~ e~,<~e,;~h ~~ ~r ~O~c e3,~ ~~~.-~~c_~o~ _ Subsequent Form Required: ~ W ~^ ~ _ ~ ~ ~~ e~,~SJ,~, ~~~ V S ~ G.~G.~~S V S ~, APPROVED BY /-L ~ Approved by: COMMISSIONER THE COMMISSION ~' Q ` Date: !J/ Form 10-403 Revised 06/200$/ \~/ / u mit in Duplicate 4 CD~17 Wellbore Scl~matic 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812" ID) at 2262' MD 9-5/8" 40 ppf L-80 BTC Surface Casing @ 3009' M D cemented to surface Packer Fluid mix: 9.2 ppa KCI Brine With 1600' TVD diesel ca 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM #1 (3.938" DRIFT ID) w/dummy Camco KBG-2 GLM #2 (3.938" DRIFT ID) w/dummy Tubing suspended with diesel Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#!ft, IBT-Mod Tubing Camco-DB nipple = ~- 2262' 1985' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG2-GLM (3.938" ID) 9119" 5765' 4'/", 12.6#/ft, IBT-Mod Tubing (2) Camco KBG2-GLM #2 (3.938" ID) 11647' 7078' Baker Premier Packer 11753' 7130' 4-1/2", 12.6#/FT, IBT-Mod Tubing (1) HES "XN" (3.725" ID)-64.2° inc 11813' 7156' 4-1/2" 12.6#/ft, IBT-Mod 10" pup joint WEG 11825' 7162' Baker Premier Packer at 11753' MD, 7130' TVD Well TD at 17975' MD 7490' TVD Top Alpine A at 13510' MD / 7205' TVD ~~~~``~~~'~ << 7" 26 ppf L-80 BTC Mod Production Casing @ 13334' MD /7490' TVD • • Net pay map Section showing CD4-17's approximate location in the Alpine "A" Sand CD DS-06C ~ ::; \ ~ ~ ~ , ~i-~r~ `~ RE: CD4-17 Alpine well: Action Plan proposal: API: 103-20534-00 • Subject: RE: CD4-17 AlpineweIl: Action Plan proposal: API: 103-20534-00 From: "Schneider, Tim S." <Tim.S.Schneider@eonocopl7illips.com> Date: Wed, 11 Oct 2006 13:12:55 -0800 "Co: l'homas ~~i~uuuler ~~-tom mauruicr(~%admin.state.ak.us> Tom, Yes, the "no SSSV request" is because the well would require asub-surface controlled safety valve, such as a K-valve to be in compliance with the pool rules (443A.8.b) while we produce it, but once we convert to injection, we'll use an A-1 injection valve for flowback control. We don't anticipate flowing this well until the first week of December, contingent on the production heater being put in service. The anticipated pad start up without lift gas is slated fior mid November. We'll get starEed on submitting the proper paperwork. thanks Tim S. Schneider Subsurfnce Development Stnff Production Engineer WNS-Alpine ~ Phone: 907-265-6859 Fnx: 907-2656472 ~ Mobile: 907-632-8136 Email: tim.s.schneiderC~conocophillips.com From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, October 11, 2006 12:45 PM To: Schneider, Tim S. Subject: Re: CD4-17 Alpine well: Action Plan proposal: API: 103-20534-00 Tim, That should do it. Is the request for no SSSV due to equipping the well for the injection valve? That approval will need to be in place prior to initiating any production. I expect from our conversation that action production will begin until late November after the pad starts up, is that so? Tom Maunder, PE AOGCC Schneider, Tim S. wrote, On 10/1 1/2006 1 1:25 AM: Tom, The CD4-17 logs indicate the Alpine section is wet throughout the logged interval. PTD: 206-118 Top Alpine A: 13,518' MD 7448 TVDSS TD 17,975' MD 7431 TVDSS H=18' Sw= 45-60% based on porosity assumptions put into log model. 1 of 2 11/20/2006 12:10 PM RE: CD4-17 Alpine well: Action Plan proposal: API ~~~ . ~~2-~'~ ~~. ~~ _. . ,FL Y 1 Ct~ 56 C~~ ', ~'~, M Gad ~ ~ ~ t '~ ~`~ .. ~ ~. .. 103-20534-00 • ti We believe that the area could have been swept from the northern injector CD2-56. We believe enough uncertainty exists surrounding these findings that we propose the following: • Flow the well for ~60 days to determine if oil is present in the vicinity of CD4-17. • Produce the well without a SSSV via gaslift. Hardline will be run from the SSV to the lateral production line. From our conversation Tom, the following permits are required to execute this work: • 10-407 service type will be "Producer" • Sundry request to produce without SSSV for 60 days • 10-404 post report • 10-403 Convert to injector (If test indicates commercial potential) Please let me know if this action plan is acceptable and if I've noted the correct permitting documents to stay in compliance. Thanks Tim S. Schneider Subsurface Development Staff Production Engineer WNS- Alpine m Phone: 907-265-6859 m Fax: 907-2656472 ~ Mobile: 907-632-8136 Email: tim.s.schneider@conocophillips.com 2 of 2 11/20/2006 12:10 PM s ~~~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION / 20 AAC 25.080 ~_v 1. Operator 3. Permit to Drill Name: Number: 206- 18 ConocoPhillips Alaska 4. API Number: 5 03-20534-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-17 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic descripti a) All wells within one-quarter mile: a) Interval exposed to pen annulus: N anuk 3, CD4-318, CD4-210, CD 4-321, CD4-214 Torok and S abee formation, shale, siltstone and sandstone //~~ ~ ` ~ P'1~~ C~-MQn~Z 1~ ~ECb\`J~ ~ ~ Y"~' ` Waste rec in b r.`~~5 } ) g zone: F b) water wells within one mile: Sand layer below the C30 marker in the Seabee formation None c) C finement: Th chrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1780' MD / 1600' D None 11. Previous volume disposed in annulus and date: s ated s ensity: 13. Maximum anticipated pressure at shoe: None siti ran o diesel to 12#/g 2247 psi 14. Estimated volume to be disposed with this request: . Flui to be d spo d: 35,000 bbls. pes of s e may a tilling mud, drilling cuttings, reserve pit fluids, cement- taminated r diesel formation fluids associated with the ng m completion fluids 16. Estimated start date: , act of drilli , , , well drill rig wash fluids, domestic waste water, any added water 31-Oct-06 ~ \ ede t 't a umping of drilling mud or drilling cuttings, new product cleanup ~ uids su h a e 'sate, and mud and brine pit rinse from mixing operations and ~ ~ an other fluids associated with drillin a well. 17. Attachments: Well Schematic (Include D and TVD) Q Cement d Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementi Data ~ Other ~ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the re going is true and correct to the best of my knowledge. / Signature: _(.~. Title: ~ (1 '~_t~~~~/ Printed Phone Name: Chip Alvord Number: 265-6120 Date: f ~ ~ tS (o G Commission Use Only Conditions of approval: LOT review and approval: ~~ - -" ~~ Subsequent form required: Approval number. APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403RD Rev. 6/2004 G {-{ I I -, ~ E1~T8U~TIONS ON° E~~~" '~~ i" 't '~" ~~~b /~~/,~~bmit in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 15, 2006 ~ ~ COnOCOPhillips Alaska Oil and Gas Conservation Commission 333 West 7t1i Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of DrillinE Waste on well CD4-17 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-17 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD4-17 approximately November 3~ 2006 or whenever a permit is available. Please fmd attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD4 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within % mile radius at AOGCC: CD4-321, CD4-214 12. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (16.2 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.1 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FTT/LOT. If you have any questions or require further information, please contact Vern Johnson at 265-6081; Chip Alvord can also be reached by calling 265-6120. Sin y, (~~~5 ~6 Vern Johnson Drilling Engineer cc: CD4-17 Well File Chip Alvord ATO-1700 Anadarko Sharon Allsup-Drake ATO-1530 Annulus Disposal Transmittal Form -Well CD4-17 AOGCC Reeulations, 20 AAC 25.080 (bl 1 Desi ation of the well or wells to receive drillin wastes: CD4-17 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = +/-1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste maybe drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD 1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2247 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4-211, CD4-16, CD4-215, ,CD4-207, CD4-205, will be enerated. CD4-213 CD4-212 CD4-203 CD4-204 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why coin Hance would be im rodent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. • Well CD4-17 Date 10/ 10/2006 Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi ~<;; ~Vi --. ~ -: U< N a 2,387 TVD Version L0 - )an'OS Pburst85% - PHydrostatic +PApplied - PFormation 4,888 = ( 2,387 * 0.052 * MWm~ ) + 1500 - ( 0.4337 * 2,387 ) MWmax = 35.6 PPg Surface Casin>? Strin Size 9.625 in ~ ~ Weight 40 ppf d a Grade L 80 eo ~ ~ rburstl0o% 5,750 Pst o P ° 4,888 psi .y burst85 /o U Depth of Shoe 2,387 ft F[T/LOT @ Shoe 18.1 ppg or 2,247 psi FIT/LOT for Annulus 16.2 ppg 0 c Max Surf. Pressure 1,500 psi 0 t; TOC Est. @ 5,575' MD 3,833' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% - PHydrostatic +PApplied - PGasGradient - PHeader 4,599 =( 3,833 * 0.052 *MWmax )+ 1,500 - ( 0.0700 * 3,833) - 1,000 MWmax = 21.9 PPg a.5 "Tubing 2nd Casing String Size 7 in 7,491 TVD Weight 26 ppf Grade L 80 rcoltapse100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 3,833 $ Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,387 * .052 * 18.1 ) Pmax allowable - 2,247 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". • ~OCl4CU~"1~~! 5 Casing Detail 9 5/8" Surface Casing Well: CD4-17 Date: 9/13/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.84 FMC Gen V Hanger 2.20 36.84 Jts 3 to 76 74 Jts 9-5/8" 40# L-80 BTC Csg 2890.95 39.04 Halliburton Float Collar 1.12 2929.99 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 75.97 2931.11 Ray Oil Tools "Silver Bullet" Float Shoe 2.25 3007.08 3009.33 TD 12 1/4" Surface Hole 3019.33 12 1/4" hole 3020' MD - 2392' TVD 9 5/8" csg shoe 3009.33' MD - 2387' TVD TOTAL BOWSPRING CENTRALIZERS - 43 1 per jt on Jt #1 - #12 (stop ring on Jt #1 8~ 3 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64, 66, 68,70,72,74 86 joints in the pipe shed. 76 jts to run -Last 10 jts out Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torque ~ 8600 ft/Ibs Remarks: Up Wt - 195 k DnWt-127k Block Wt - 75k Supervisor. D. Mickey ~ ~ ConocoPhillips CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4-17 RIG: Doyon 19 CASING DESCRIPTION: 9 5/8", 40# L-80 BTC DATE: 09/13/06 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 37.22 26 36.55 51 38.25 76 38.20 101 126 151 176 2 38.75 27 42.94 52` 42.18 77 37-98 102 127 152 177 3 39.34 28 38.73 53 40.13 78 89-'44 103 128 153 178 4 38.90 29 40.86 54 35.93 79 ~8 104 129 154 179 5 37.03 30 38.01 55 38.13 80 89:58 105 130 155 180 6 39.47 31 36.39 56 39.63 81 39~ 106 131 156 181 7 36.46 32 41.33 57 38.69 82 36:44 107 132 157 182 8 37.18 33 36.67 58 43.04 83 463 108 133 158 183 9 37.15 34 40.59 59 42.09 84 48-28 109 134 159 184 10 41.96 35 37.61 60 36.94 85 89:65 110 135 160 185 11 36.72 36 35.88 61 39.67 86 38-5 111 136 161 186 12 41.15 37 36.98 62 38.61 87 112 137 162 187 13 40.29 38 40.17 63 38.27 88 113 138 163 188 14 39.18 39 38.05 64 37.93 89 114 139 164 189 15 40.19 40 38.59 65 40.11 90 115 140 165 190 16 36.22 41 40.31 66 38.41 91 116 141 166 191 17 42.01 42 36.83 67 38.10 92 117 142 167 192 18 37.04 43 39.67 68 38.11 93 118 143 168 193 19 37.25 44 40.19 69 38.08 94 119 144 169 194 20 39.63 45 37.59 70 42.90 95 120 145 170 195 21 43.57 46 39.04 71 40.16 96 121 146 171 196 22 43.77 47 39.25 72 38.56 97 122 147 172 197 23 42.69 48 36.96 73 37.84 98 123 148 173 198 24 39.51 49 40.11 74 36.85 99 124 149 174 199 25 39.67 50 37.39 75 41.07 100 125 150 175 200 Tot 982.35 Tot 966.69 Tot 979.68 Tot 430.79 Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 3359.51 DIRECTIONS: TOTAL JOINTS THIS PAGE = 86 FLOAT SHOE 2.25 FLOAT COLLAR 1.12 HANGER RKB 36.37 ~' Cement Detail Report CD4-17 Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10142389 9/11/2006 9/12/2006 10/4/2006 'Cement Details _ _ _ Description Cementing Start Date Cementing End Date 1Nellbore Name Surface Casing Cement 9/15/2006 10:00 9/15/2006 12:00 CD4-17 Comment - - - -- Cement Stages -_ _------_ __ Sta a#1 Description Objective Top (ftKB) Bottom (ftKB) Full Return. Cmnt Rtrn (... Top Plug. etm Plug. Surface Casing Cement 37.0 3,009.0 Yes 108.0 Yes Yes O (start) (bbl/min) O (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 5 8 600.0 1,100.0 Yes 15.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment ,Cement Fluids & Additives ~--- - Fluid ---- _ _ _ Fluid Type Fluid Description Estimated Top (ftKB) 'Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Water Biozan water w/ nut 35.0 plug Yield (ft'Isack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud push MudPush XL 52.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid __ _ _ _ _ _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) lead ASL 37.0 2,509.0 400 G 316.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (°~) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.70 10.70 Additives Additive Type Concentration Conc Unit label --- -- - - Fluid Fluid Type Fluid Descrip8on Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbq Tail G 2,509.0 3,009.0 230 G 48.6 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (°k) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.10 15.80 Additives Additive Type Concentration Conc Unit label Fluid _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Water 20.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label - - Fluid - Fluid Type Fluid Description Estimatetl Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Mud 202.4 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 9.80 Page 1/3 Report Printed: 10/12/2006 Daily Drilling Report CD4-17 ,. Report Date: 9/15/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 5 4.00 3,020.0 3,020.0 0.00 CD4-17 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 9/12/2006 DOYON 19 ALPINE Development 17,041.0 AFE / RFE I Maint.# Total AFE Amount Average ROP (ft/hr) 10142389 6,215,564.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Surface, 3,009.3ftK6 Ops and Depth ~ Morning Report Daily Cost Total Cummulative Cost LD 4" DP 335,852.07 1,178,203.83 24hr Forecast Daily Mud Cost Cummulative Mud Cost PU DP - MU BHA -Drill 8 3/4" hole 4,603.07 59,444.83 Last 24hr Summary Finish running & cmt csg - NU & test BOPE General Remarks Weather Head Count 44/37 wG NE@12 mph 47.0 -- --- 3~.penns,.,r_ __. Title _. _~ - ___~ Don Mickey __ Rig Supervisor Time Log _ Start Fn^ Time ~epfh Start Dep4 Ena Tlr~a Tree Our(hrs) Phase Op Code OpSub-Cope P-N-T TrblCode {ftKB) (ftke'~ Co-.m.„~p~ranon 00:00 01:00 1.00 SURFAC CASING RURD P 0.0 0.0 RU to run 9 5/8"' csg 01:00 01:15 0.25 SURFAC CASING SFTY P 0.0 0.0 Held pre-job safety meeting 01:15 04:15 3.00 SURFAC CASING RNCS P 0.0 1,759.0 Ran 9 5/8" 40# L-80 MBTC casing as follows: FS (Ray Oil Tools Silver bullet) 2 jts.- FC (Halliburton Super Seal) 2jts. (first 4 connections made up w/ BakerLoc -fill pipe 8 checked floats) 41 jts. to 1759' - 45 jts. total 04:15 05:15 1.00 SURFAC CASING CIRC P 1,759.0 1,759.0 Break circulation -stage pumps up to 3.5 bbls/min. @ 400 psi Circulate btms up - PU wt 137 SO wt. 123 05:15 07:15 2.00 SURFAC CASING RNCS P 1,759.0 3,009.0 Continue running 9 5/8" 40# L-80 MBTC casing - 31 jts (76 jts total) f/ 1759' to 2970' - PU landing jt w/ FMC fluted mandral hanger & land csg on landing ring w/ shoe @ 3009.33' & float collar @ 2929.99' 07:15 07:45 0.50 SURFAC CASING RURD P 3,009.0 3,009.0 RD csg equipment - RU cmt head & lines 07:45 09:45 2.00 SURFAC CEMENT CIRC P 3,009.0 3,009.0 Break circulation & stage pump up to 6 bbls/min -Circulate hole clean & condition mud for cement job 09:45 10:00 0.25 SURFAC CEMENT SFTY P 3,009.0 3,009.0 Held pre job safety & operation meeting with crew 10:00 12:00 2.00 SURFAC CEMENT DISP P 3,009.0 3,009.0 Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pumps -Line up Dowell & pump 5 bbls water -Test lines to 2900 psi -Drop btm plug -Mix & pump 52.29 bbls MudPush @ 10.5 ppg @ 5 bbl/min @ 200 psi - Mix & pump Lead slurry (ASL) @ 10.7 ppg @ 7.5 bbls/min @ 200 psi -Observed nut plug marker @ shakers w/ 300 bbls lead slurry pumped -pumped down surge can - 316 bbls lead slurry pumped -Switched to tail slurry (G w/ 1 % -S002, .20% D046, .30% D065) Mixed & pumped 48.6 bbls @ 15.8 ppg @ 5.4 bbls/min @ 200 psi -dropped top plug & chased w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 9.8 ppg mud @ 7 bbls/min for 180 bbls (400 to 700 psi) slowed pump to 3.5 bbls/min for last 22 bbls of displacement (500 to 600 psi) 202.4 bbls total displacment -Bumped plug w/ 1100 psi - Checked floats OK - CIP @ 1200 hrs. -Full circulation throughout job w/ 108 bbls 10.7 ppg cmt to surface 12:00 13:00 1.00 SURFAC CEMENT OTHR P 3,009.0 3,009.0 RU & pressure test 9 5/8" csg to 2500 psi for 30 mins. 13:00 14:30 1.50 SURFAC CEMENT PULD P 3,009.0 3,009.0 Flush surface riser - RD cmt equipment - LD landing jt. 14:30 15:30 1.00 SURFAC DRILL PULD P 3,009.0 ND surface riser 15:30 16:30 1.00 SURFAC DRILL OTHR P Install FMC wellhead & test seals to 1000 psi 16:30 18:00 1.50 SURFAC WELCTL NUND P NU BOPE Latest BOP Test Data Oate ':o~nrcr•~~,t Page 1/2 Report Printed: 10/12/2006 Daily Drilling Report CD4-17 Report Date: 9/15/2006 Loq 5,-,rt Ica ~ Tlme -_ _. _ - L~ 1. ,. ti~ ail ~, U~'Pth Errd ', l-r-~~- 7u~~r put !l~~s~. 'I Phase Op Code U: ~t (.roe P-N-T 7 i i~,~~ oe ith6~ ' !nKB) ~onr..~/Ooeratioc --- ----- 18:00 - 22:30 4.50 SURFAC WELCTL BOPS P - Test BOPE - Hydril to 250 & 3500 psi -Test pipe rams -choke manifold valves -choke & kill line valves -floor safety & dart valves - TD IBOP's -blind rams to 250 & 5000 psi -performed accumulator closure test - RD testing equipment 22:30 23:00 0.50 SURFAC DRILL OTHR P Install wear bushing -blow down choke & kill lines 23:00 00:00 1.00 SURFAC DRILL PULD P PU drilling bails & DP elevators -Change out 1 bad jt of 5" DP in derrick Mud Check Data -_ -_ _- i - - ~ YP Ca ? TYPe Pepth (frK8} Dens{Ib/u ^'~i V ~~ct1 '~ I ~~ ~Ir ~;.;~1 IIbf110C~P ' -- - Ge 1:~;~~--' ;1~2~»1 ~ Gel {30m) H I HP Filt Unn~ T~n~o i _ :)sir. !lu(1~OFPi ~t ~JGF~. (Ibf/100ft~) M6T (Iblb o'1 EmLl3Dmin) p}{ 'f ~ ~ %i ° Spud Mud 3,022.0 9.~~0 11 0 13.000' 5.000 5.000 30.0 5 0~ ~+.SI S 000, - 'Infection Fluid _ I wd jai ~ -- -_ -- ~i. r Laa; .. ~I~ De~'i dliorl Note Cementing Fluids 508.0 CD4-208 Ctm. contam mud Diesel 5.0 CD4-208 inject. test Water 135.0 CD4-208 annular flush Water Based Mud 2127.0 CD4-208 f/ CD4-17 __ _ Wellbores - Wellbore Name Wellbore API/UWI 1 CD4- 17 501032053400 ----- Section. - -~_ (c,~ ~-. ~ Top {fl COND1 36 RL'; Act Bfm (ftK8) '. Start Date End Datc 37.0 114.0 SURFAC 12 1/4 114.0 3,020.0 9/12/2006 9/14/2006 INTRMI 8 3/4 3,020.0 13,345.0 9/17/2006 9/22/2006 PROD1 6 1/8 13,345.0 19,975.0 9/22/2006 10/1/2006 Cement _ _- Surface Casin Cement -Started 9/15/2006 Type Wellbore String Cement Evaluation Results casing CD4-17 Surface, 3,009.3ftKB Stg No. Description Top (ftK6) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 37.0 3,009.0 5 600.0 Fluid Class Amount (sacks) V (bbl) DensiEy {iblgal) Yield (ft'/sac6,y ~ Est Top (ftY.Fi1 Cu Gtn-. r~B; Water 35.0 8.30 Mud push 52.0 10.50 lead G 400 316.0 10.70 4.45 37.0 2,509.0 Tail G 230 48.6 15.80 1.16 2,509.0 3,009.0 Water 20.0 8.30 Mud 202.4 9.80 Page 2/2 Report Printed: 10/12/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-17 Rig: Doyon 19 Date: 9/16/2006 Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: D. Mickey Pump used: #2 Mud Pump ~ Strokes ~ 0.1000 Bbls/strk • 8.OO Strk/min ~ T f T t: o h l T t LOT Frr ~ P i I d d ll ~ ype o es pen o e es / ump ng own ~ ri pipe. Casin g Test Pressure In te rit Test Hole Size: ' $-3/4" ~ Casin Shoe Depth Hole De th Pum pin Shu t-in Pumpin Shut-i n RKB-CHF: 36.8 Ft 3009.0 Ft-MD _ 2387.0 Ft-TVD 3040.0 Ft-MD 2403.0 Ft-TVD Strks psi Min si Strks psi Min psi Casing Size and Description: 9-5/s" 4o#/Ft L-so t3TC ~ 0 0 2500 0 0 0.00 1040 Casin Test Pressure Int e rit Test 2 40 1 2500 1 20 0.25 1030 Mud Weight: 9.8 ppg Mud Weight: 9.6 ppg 4 160 2 2500 2 40 0.50 1020 Mud 10 min Gel: 21.0 Lb/100 Ft2 Mud 10 min Gel: 23.0 Lb/100 Ft2 6 380 3 2500 3 60 1.00 990 Test Pressure: 2500.0 psi Rotating Weight: ####### Lbs 8 600 4 2500 4 100 1.50 95 Rotating Weight: 130.0 Lbs Blocks/Top Drive Weight: 74000.0 Lbs 10 780 5 2500 5 170 2.00 9 Blocks/Top Drive Weight 74.0 Lbs Desired PIT EMW: 18.0 ppg 12 960 6 2500 6 260 2.50 9~ _ Estimates for Test: 2.1 bbls Estimates for Test: 1043 psi 0.8 bb_Is 14 1120 7 2500 7 350 3.00 920 ~ 16 1300 8 2500 8 450 3.50 910 EMW =Leak-off Pressure + Mud Weight = 1060 _ _ PIT 15 Second 18 1480 9 2500 9 540 4.00 905 0.052 x TVD + 9 6 0.052 x 2387 Shut-in Pressure, psi 20 1660 10 2500 10 640 4.50 900 EMW at 3009 Ft-MD (2387 Ft-ND) = 18.1 ppg 1030 22 1860 15 2500 11 690 5.00 900 aooo Lost 0 psi during test, held 100% 24 2080 20 2500 12 770 5.50 895 of test pressure. 26 2280 25 2500 13 830 6.00 890 - - 28 2500 30 2500 14 ~, 880 6.50 885 2soo 15 ' 930 7.00 880 _ - _ ___ ___ - 16 990 7.50 880 17 1030 8.00 880 2000 w 18 1060 8.50 875 a ~ 9.00 875 ~ lsoo 9.50 870 w -- 10.00 87 - a 1000 . __ r .b ~ 500 - 0 1 2 3 0 5 10 15 20 25 30 Volume Volume Volume Vol Barrels Shut-In time, Minutes CASING TEST f LEAK-OFF TEST O PIT Point PUm ed Bled Back PUm ed Bled s s s ~: Tested 9 5/8" csg after bumping plug on cmt. Job Summary • • ConocaP'hfl~ iii Casing Detail 7" Casing Well: CD4-17 Date: 9/23/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.59 FMC Gent/ Hanger 2.40 34.59 Jts 157 to 311 155 Jts 7" 26# L-80 BTCM Csg 6626.87 36.99 Weatherford/Gemoco Stage Collar 2.31 6663.86 Jts 3 to 156 154 Jts 7" 26# L-80 BTCM Csg 6578.51 6666.17 Halliburton Float Collar .92 13244.68 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.62 13245.60 Ray Oil Tools "Silver Bullet "Float Shoe 2.10 13332.22 13334.32 7" Shoe @ 13334.32 8 3!4" hole @ 13345.00 *Baffle for Shut -Off plug @ 13,201' (top of FC jt) 8-3/4" Hole TD @ 13,345' MD 17491' TVD 7" Shoe @ 13,334.32' MD / 7490.5' TVD Total Centralizers: 65 Straight blade centralizer one per jt on jts # 1-15 Straight blade centralizer one per jt on jts. 155,156,157,158 Straight blade cent. one per jt. on joint #'s 220,221,222 Straight blade cent.one on every other. jt.# 224 to 308 320 joints in shed - 311 total jts. to run Last 9 jts. Out *Circ @ jts 75, 165, 13i 255 Use Run & Seal i e do e Average make up torque 8000 ft/Ibs Remarks: Up Wt - 385 k Dn Wt - 160 k Block Wt - 75k Supervisor: D. Mickey ~t?I'10C©~~"11 ~ ~ [ ~ p CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4-17 RIG: Doyon 19 TUBING DESCRIPTION: 7", 26# L-80 BTCM DATE: 09123/06 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 43.59 26 43.12 51 41.87 76 43.43 101 43.37 126 43.32 151 41.60 176 43.39 2 43.03 27 41.56 52 43.19 77 44.12 102 43.18 127 40.73 152 43.32 177 42.30 3 43.39 28 43.56 53 43.52 78 43.45 103 43.28 128. 43.11 153 43.96 178 43.59 4 40.66 29 42.76 54 42.88 79 43.46 104 42.81 129 43.57 154 42.46 179 41.25 5 41.99 30 43.58 55 41.41 80 43.44 105 42.18 130 42.68 155 43.45 180 42.35 6 41.72 31 43.51 56 42.39 81 43.34 106 43.32 131 43.49 156 42.21 181 41.97 7 43.66 32 43.34 57 41.76 82 43.59 107 43.38 132 42.17 157 43.35 182 41.98 8 42.40 33 43.41 58 43.37 83 43.20 108 41.22 133 43.45 158 42.59 183 43.23 9 43.50 34 41.71 59 43.38 84 41.94 109 43.35 134 41.89 159 43.28 184 43.58 10 42.66 35 40.93 60 42.80 85 41.24 110 42.30 135 43.48 160 41.90 185 42.14 11 43.10 36 42.18 61 42.18 86 42.65 111 44.20 136 43.53 161 38.06 186 42.83 12 41.32 37 40.43 62 41.92 87 42.16 112 43.02 137 42.61 162 42.18 187 42.14 13 43.50 38 43.30 63 42.31 88 42.58. 113 43.50 138 43.36 163 42.40 188 43.50 14 41.77 39 42.12 64 42.57 89 41.18 114 43.91 139 43.59 164 43.21 189 42.92 15 43.48 40 41.09 65 41.53 90 42.50 115 41.27 140 43.38 165 43.39 190 43.35 16 43.06 41 43.37 66 36.62 91 41.91 116 41.26 141 43.23 166 43.25 191 42.65 17 41.23 42 42.60 67 43.20 92 42.28 117 42.25 142 40.80 167 43.37 192 42.18 18 43.45 43 43.50 68 43.57 93 42.13 118 43.59 143 43.50 168 43.38 193 43.16 19 41.80 44 43.49 69 43.58 94 43.58 119 42.46 144 43.35 169 42.72 194 43.27 20 43.37 45 43.58 70 43.48 95 43.34 120 43.22 145 42.00 170 43.39 195 42.08 21 43.72 46 43.03 71 42.49 96 42.21 121 41.36 146 43.48 171 42.36 196 43.59 22 43.49 47 40.87 72 43.44 97 43.37 122 43.59 147 43.49 172 43.50 197 43.12 23 43.46 48 42.77 73 41.01 98 43.35 123 43.35 148 43.17 173 43.37 198 42.15 24 42.00 49 42.43 74 41.62 99 43.46 124 43.18 149 43.23 174 43.07 199 43.60 25 43.32 50 42.72 75 43.46 100 43.38 125 40.98 150 43.52 175 43.01 200 41.75 Tot 1068.67 Tot 1064.96 Tot 1059.55 Tot 1071.29 Tot 1069.53 Tot 1074.13 Tot 1068.78 Tot 1068.07 TOTAL LENGTH THIS PAGE = 8544.98 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 FLOAT SHOE 2.1 FLOAT COLLAR 0.92 HANGER 2.4 RKB 34.59 ---,. Cement Detail Report CD4-17 ...«,- Production Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10142389 9/11/2006 9/12/2006 10/4/2006 ,Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 9/24/2006 19:00 9/24/2006 23:30 CD4-17 Comment - - _ - Ceme~tStages - - - __ -_ -- Stage # 1 Description Objective Top (ftK6) Bottom (ftK6) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Production Casing primary 9,450.0 13,334.0 Yes 0.0 Yes No Cement O (start) (bbl/min) O (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 769.0 1,200.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment -- - - - --- Fluid Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW-100 50.0 Yield (ft /sack] Mix H2O Ratio (gal/sa... Free Water (%) Density (tb/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label . _ - Fluid _- - -- - _- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbq Mud Push 40.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label 'Fluid -- - - - Fluid Type Fluid Descnpfion Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 9,450.0 12,600.0 218 LiteCrete 130.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 3.35 11.20 11.00 Additives Additive Type Concentration Conc Unit label Fluid _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB} Amount (sacks) Class Volume Pumped (bbl) Tail Cement 12,600.0 13,334.0 158 G 34.0 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.09 15.80 Additives Additive Type Concentration Conc Unit label Fluid - - _ - - Fluid Type Fluid Descnption Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Giass Volume Pumped (bbq Water 20.0 Yield (fP/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label --- -- Fluid... Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbq Mud 489.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.00 Page 1/3 Report Printed: 10/12/2006 Cement Detail Report CD4-17 Production Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date Drilling Support -Capital Well Intervention 10142390 10/7/2006 10/7/2006 Additives Additive Type Concentration Conc Unit label - ~Cement Stages - - _ -- Stage # 2 - - ---- Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Production Casing primary 5,575.0 6,663.0 No Yes No O (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 450.0 2,210.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped through stage collar @ 6663' - _ - - - -_ Cement Fluids & Additives - --- -_- Fluid -- _ - --- - - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW-100 10.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label (Fluid -- - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 21.0 Yield (ft*/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid - ----- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 5,575.0 6,663.0 196 G 40.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label :Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amowit (sacks) Class Volume Pumped (bbl) water 20.0 Yield (ft°/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 8.30 Additives Additive Type Concentration Conc Unit label - - -- Fluid _ __ _ _ --- -_ _ _ - -- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) mud 235.0 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 10.00 Additives Additive Type Concentration Conc Unit label Page 2/3 Report Printed: 10/12/2006 • Daily Drilling Report CD4-17 . .., . Report Date: 9/24/2006 Report Number Days From Spud (days) Depth Start (ftK6) Depth End (ftKe) Depth Progress (ft) Wellbore 14 13.00 13,345.0 13,345.0 0.00 CD4-17 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftK6) 9/12/2006 DOYON 19 ALPINE Development 17,041.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10142389 6,215,564.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 13,334.2ftK6 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Laying down 5" D.P. 460,177.18 3,424,704.64 24hr Forecast Daily Mud Cost Cummulative Mud Cost LD D.P. - MU clean out assy. - PU 4" D. P. 6,014.18 377,208.64 Last 24hr Summary Run and cement 7" csg - General Remarks Weather Head Count 34/NW@2mph 50.0 Don Mickey Dave Burley Time Log Rig Supervisor Rig Supervisor title -- Sta~, ~ F^.o Tip°- _' ~=ice Cur(iusj Rase -- p Code pSub-Code Time F-N-T -- --blGuue _ r orr. S ,rt ~ D; f~.Frd i'' ~Itha;) tRkB; _. CommlOperation 00:00 00:30 0.50 INTRM1 CASING RNCS P 2,773.0 3,196.0 _ ___ Run 7" 26# L-80 BTCM casing from 2774' to 3196' (75 jts total 00:30 01:00 0.50 INTRM1 CASING CIRC P 3,196.0 3,196.0 Circ casing volume - 5 bpm / 350 psi 01:00 05:00 4.00 INTRM1 CASING RNCS P 3,196.0 7,050.0 Run 7" 26# L-80 BTCM casing from 3196' to 7050' (165 jts total) 05:00 06:00 1.00 INTRM1 CASING CIRC P 7,050.0 7,050.0 Stage pumps up from 2 bpm / 400 psi to 5 bpm -CBU -FCP 520 psi 06:00 10:45 4.75 INTRMI CASING RNCS P 7,050.0 10,899.0 Run 7" 26# L-80 BTCM casing from 7050' to 10,899' (255 jts total ) 10:45 12:30 1.75 INTRM1 CASING CIRC P 10,899.0 10,899.0 Stage pumps up from 2.5 bpm / 650 psi to 5 bpm -CBU -FCP 700 psi -PUW 280k SOW 160K 12:30 16:00 3.50 INTRMI CASING RNCS P 10,899.0 13,334.0 Run 7" 26# L-80 BTCM casing from 10,899' to 13,297' (311 jts total) -PUW 385K SOW 170K - MU FMC fluted hanger and LJ -Land hanger in wellhead with Shoe @ 13,334', FC @ 13,245' and insert baffle @ 13,201' 16:00 16:30 0.50 INTRMI CEMENT PULD P 13,334.0 13,344,0 Lay down fill up tool -blow down top drive -rig up cement head 16:30 19:00 2.50 INTRM1 CEMENT CIRC P 13,344.0 13,344.0 Stage pumps up to 6 bpm - circ and condition mud -FCP 780 psi - 780 blls pumped -Held PJSM w/ Dowell and crew 19:00 21:30 2.50 INTRMI CEMENT DISP P 13,344.0 13,344.0 Cemented 7" csg as follows: Pumped 5 bbls CW100 -Tested lines to 4400 psi -pumped 45 bbls of CW100 4.0 bpm @ 500 psi- Mixed & pumped 40 bbls MudPush @ 10.5 ppg - 4.9 BPM @ 575 psi -Mixed and pumped 129 bbls of lead slurry LiteCRETE @ 11.0 ppg @ 5.5 bpm / 615 - 389 psi -Mixed & pumped 34 bbls tail slurry (Class G w/additives) - 15,8 ppg @ 5.1 BPM @ 340 psi -Dropped top plug w/ 20 bbls water f/ Dowell -switched to rig pumps & displaced cmt w/ 10.0 ppg mud @ 7 BPM for 415 bbls / 580 - 840 psi- 6 bpm for 62 bbls / 790 - 940 psi and 4 bpm / 750 - 770 psi last 12 bbls pumped - 509 bbls total displacement -Bumped plug w/ 1200 psi -Check floats OK - CIP @ 2130 hrs.- Full returns throughout - No pipe movement 21:30 22:30 1.00 INTRMI CEMENT CIRC P 13,344.0 6,665.0 Pressure up on casing -Stage collar shifted open w/ 3600 psi - Circ and cond mud 5 bpm / 330 psi -prepare for second stage cement opts Latest BOP Test Data Date Comment Page 1/2 Report Printed: 10!12/2006 Daily Drilling Report CD4-17 Time Log __ Report Date: 9/24/2006 Tin~~_ _ _ Tun Gu, !nns I E^:z.=.~ i U~ ~ one J~ it i,o~i.. - -- ~ N T', 7 I (a~o~.-, tI P;Ci ~ i ~..r... ~.... (ftKB) C-~n r .~-~c-~ln ~;. 22:30 23:30 1.00 INTRMI CEMENT DISP P 6,665.0 6,665.0 Second Stage cement opts as follows: Pumped 10 bbls CW100 - 3.5 bpm @ 202 psi- Mixed & pumped 20 bbls MudPush @ 10.5 ppg - 4.8 BPM @ 275 psi -Mixed & pumped 40.4 bb{s tail slurry (Class G w/additives) - 15.8 ppg @ 5.1 BPM @ 290 - 100 psi -Dropped top/closing plug w/ 20 bbls water f/ Dowell - switched to rig pumps & displaced cmt w! 10.0 ppg mud @ 7 BPM for 225 bbls / 225 - 570 psi -then 4 bpm / 420 - 450 psi last 10 bbls pumped - 255 bbls total displacement -Bumped plug w/ 2690 psi (2240 psi over final displacement press held 5 minutes) - CIP @ 2330 hrs.- Full returns throughout - No pipe movement -annulus static 23:30 00:00 0.50 INTRM1 _-- _ -- CEMENT RURD P 6,665.0 6,665.0 blow down lines - RD cement head - - -_ _ - Mud Check Data __ _ _- -- __ VP Cali;rl,~_i ,10m) Gel (30m) HTHP Fllt ', n~vi_it, ~ n,>' Ir~~ :oc i Tgpe L'rptl,. ir'H F~ IJ~~m ~t n.a ~; 'Jis (s/qt) F'~r I: (cn ~La~~niPP ; C~~._.,_ n~rn OOft') {Ibfl100ft') MBT Qb/bbl) (mL130min) I nH 'F~ ~. .°'-i ~ LSND 13,3450 10.00 45 10.0 21.000 9.000 11.000 12.000 20.0 7.2 9.1 'In'ection Fluid - - - __ R~_.id _ _- s~~• e HomLeaSe(bbl) Destination tJ i= Water based Mud ---- l 560.0 CD1-19 f/CD4 17 Wellbores -- ---- - Wellbore Name - __ _ _ Wellbore API/UWI CD4-17 501032053400 __~.,cn ____ _ Scn i in? ~ Act Top (ftK6) Act 8tm (ftK6 ~ Start Date End Date COND1 36 37.0 114.0 SURFAC 12 1/4 114.0 3,020.0 9/12/2006 9/14/2006 INTRM1 8 3/4 3,020.0 13,345.0 9/17/2006 9/22/2006 PROD1 6 1/8 13,345.0 19,975.0 9/22/2006 10/1/2006 . _- - - Cement - -- _ _ _ _ _ _ _ -- Production Casin Cement -Started 9/24/2006 Type Wellbore String Cement Evaluation Results casing CD4-17 Intermediate, 13,334.2ftK6 Stg No. Description Top (ftK6) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) 1 Production Casing Cement 9,450.0 13,334.0 4 769.0 Piwd '~lar,s Amount jsa~.bs, / LD'~.; D~n~.ity (tblgal) Yield {fi'Isack) Est Top (fth6i Est Btm ~^hHi CW-100 50.0 8.30 Mud Push 40.0 10.50 Lead Cement LiteCrete 218 130.0 11.00 3.35 9,450.0 12,600.0 Tail Cement G 158 34.0 15.80 1.16 12,600.0 13,334.0 Water 20.0 8.30 Mud 489.0 10.00 Stg No. Description Top (ftK6) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) 2 Production Casing 5,575.0 6,663.0 4 450.0 Fluid Class Amount(sa~ ;= V(bbl) Density(iblgal) Yeld(fNlsachi '~ EsT~~, ^,KB1 Es?Btm ttK~,! CW-100 10.0 8.30 Mud Push 21.0 10.50 Tail Cement G 196 40.0 15.80 1.17 5,575.0 6,663.0 water 20.0 8.30 mud 235.0 10.00 Page 2/2 Report Printed: 10/12/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-17 Rig: Doyon 19 Date: 9/25/2006 Volume Input Pump Rate: Drilling Supervisor: D. Mickey Pump used: Cement Unit ~ P i d '' Barrels ~ Bbls/Strk' ~ 0.8 Bbl/min ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ ump ng own annulus. ~ Casin Test Pressure In te rit Test Hole Size: '~ 8-3/4" ~ Casin Shoe De th Hole Depth Pumpin Shut-in Pumpin Shut-in RKB-CHF: 34.6 Ft 3,009 Ft-MD 2,387 Ft-TVD 5,575 Ft-MD 3,833 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 0 0 635 Chan es for Annula r Ade u ac Test Pressure Int e rit Test 1 0.5 168 0.25 578 uter casing shoe test results in comments Mud Weight: 10.0 ppg 2 1 256 0.5 527 Description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 334 1 482 ize is that drilled below outer casing. 4 2 380 1.5 timated TOC for Hole Depth. 5 2.5 451 2 Enter inner casing OD at right Desired PIT EMW: 16.0 ppg 6 3 518 2.5 Estimates for Test: 745 psi 0.4 bbls 7 3.5 ,. 587 3 430 j ~ ,/ ~ 8 4 ~ 650 3.5 425 EMW =Leak-off Pressure + Mud Weight = 773 _ PIT 15 Second 9 4.5 , _. 711 4 422 + 1 0.052 x TVD 0.052 x 2387 9rw1 Shut-in Pressure, psi 10 5 ~ 773 4.5 420 EMW at 3009 Ft-MD (2387 Ft-TVD) = 16.2 '`~~~ 57s 15 5.5 805 5 417 looo 20 ~ 801 5.5 416 25 6.5 750 6 414 - -- 30 7 698 6.5 412 -___ _ 7.5 664 7 411 ~S 8 649 7.5 410 8 5 638 8 408 - . 9 635 8.5 407 ~ -- - I I - - - - 9 406 N soo -- --- - - 9.5 405 w ~ ~ 10 40 a ~ - - - 0 0 1 2 3 4 5 6 7 8 9 10 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes ~~CASING TEST -LEAK-OFF TEST O PIT Point Vol Pum ume ed Vol Bled ume Back Vo Pu lume m ed Vol Bled ume Back s s s s Comments: 9 5/8" shoe FIT = 18.1 ppg t~c~no~ 'h1[ips Atka CD4-17 w,nwttsur+~rc+rw C ~ y - al`/ n. f :•..;lw~Pt~ - sa v vc y t a,«.r anu~s's..wa... Pe,,., cP, CD4-210 (CD4-2101 1 0 0 0 :, 0 ., .~ -1 0 ~: CD4-17 II rn ~ Rig: CD4-321 CD4-319 (CD4-3191 \ CD4-208 (CD4-20 CD4-321 s16~ Quarter Mile (1320 feet) radius plot 7" -3 CD4-319 CD4-319 CD4-318 CD4-318 '~ ,, __ _ .. _ CD4-318 CD4-318A ~~ _-- _----- -5000 -4000 -3000 -2000 -{ CD4-209 (CD4-20S -1000 0 West(-)Bast(+) [1000ft/in] ~ Nanuq 5 (Nanuq 5) _ _ _~__ CD4-320 (CD4-3 1000 2000. 3000 4000 SURFACE CASING SHOE SEPARATION FROM CD417 CD4-17 x v Surface Casing Shoe ASP 4 Coordinates NAD 27: 376416.34 5957221.03 ells Nanuk 1 Nanuk 2 Nanu 3 Nanu 5 Details @ AOGCC*" n n Ann, Disp. Permit # ermit Date ource well Ann. Vol. tart Date nd Date i from Object well* 181 2147 Surface csg. Shoe X Coord. 376499.69 378326.61 Surface csg. Shoe Y Coord. 5957381.96 5956241.68 Surf L07 (ppg) 11.8 14.9 Surface casing TVD (ft) 1781 2393 Annular LOT (ppg) 5.1 omments Exploration P&A'd Exploration P&A'd Ex !oration Not for annular dis osal C02-319 305-373 12/9/2005 CD4-208, CD4-318, CD4-209, CD4-320 32000 12/14/2005 7/2/2006 1619 377174.72 5955790.42 18.4 2400 16.1 CD4-208 306-183 5/30/2006 CD4-318a, CD4-320, CD4-214, CD4-321 58495 7/3/2006 10/31/2006 1770 378134.16 5956792.74 16.3 2439 14.4 volume extension to 70000 bbl, ermit#306-266 CD4-318 306-181 5/26/2006 CD4-209, CD4-320 457 5/31/2006 7/2!2006 954 376138.41 5956308.25 18.2 2375 17.1 Unable to um - SD um in CD4-209 1523 377934.93 5957333.86 14.7 2377 17.5 Not for annular dis osal CD4-210 1160 377547.421 5956963.174 18.0 2386 17.3 CD4-320 1739 377914.23 5958105.03 17.1 2378 17.8 Not for annular dis osal CD4-17 0 376416.34 5957221.03 18.1 2387 16.2 CD4-321 679 375795.55 5956945.42 18.0 2385 16.3 CD4-214 676 377040.88 5956962.79 18.2 2365 17.6 Not for annular dis osal * Lateral distance in feet, between surface casing shoes, in the X-Y plane ** As of Nov. 14, 2006 Note that this sheet is not the definitive record for annular disposal volumes • ~ Subject: RE: CD4-17 AD Request From: "Johnson, Vern" <Vern.Johnson@conocophillips.com> Date: Wed, 22 Nov 2006 12:38:50 -0900 To: 'T~hQ~nas Maunder <to~n maunder@adniin.state.ak.us> .~ ~ ~ ~-. ~ ~~~ Tom, In addition to our discussion this morning, please see my answers below. 1. In general, the distance is from a 2-D calculation based on the global x/y locations of the surface casing shoes. This works well for the bulk of the wells because almost all the shoes are at very similar TvD. The equation is less applicable for Nanuq 3 due to the difference in TVD, so the X-Y location used for Nanuq 3 is the wellbore X-Y at 2400 ft TVD, this is ± 529' TVD below the shoe. 2. I searched for an annular LOT plot for Nanuq 3 but I was not able to find one. The well was drilled by the exploration group in 2001, and they may not have considered annular disposal as an option at that time. 3. Estimated TOC for the second stage on CD4-17 was ± 5575' MD / 3833' TVD. As discussed, we will arrange to have the annulus on CD4-210 tested again in the next several days. Let me know if you have any questions. Vern Johnson -----Original Message----- From: Thomas Maunder [~.ailto•-om ~~.a~~n~e~~~ad:~~n.state.a~' .~s] Sent: Tuesday, November 21, 2006 3:15 PM To: Johnson, Vern Subject: CD4-17 AD Request Vern, I am looking at the AD request for CD4-17 and have a couple of questions. According to the proximity plot, Nanuq 3 is fairly close to CD4-17. A distance of 181 feet is given in the spreadsheet page. 1. Is this the distance separating the wellbores at the surface shoe of Nanuq 3 or CD4-17? Would you please clarify the distance separating the wellbores at the respective surface casing shoes? 2. No pressure/EMW is given for the annular LOT on Nanuq 3. Is any such information available? 3. Do you have a TOC estimate for the 2nd stage job on the 7" casing? Thanks ir. advance for your reply. Call or message with any questions. Tom Maunder, PE AOGCC 1 of l 11/27/2006 10:30 AM ..~ »rr...,»...,..., ~ • Subject: Latest AD applications From: Thomas Maunder <tom maunder~;admin.state.ak.us> Date: Wed, 22 Nov 2006 12:09:16 -0900 To: Vern Jah3ison <Vern.3ahnson~conocophzlltps.com> CC: Chip Alvard<Chip.Alvord c~eonocophillips_com> ~~~^ ~`~ Vern, Thanks for the discussion this morning regarding the latest applications for AD at CD-4. As we discussed, it does not appear that the application for CD4-17 can be approved due to the uncemented section of the production casing annulus in Nanuq 3 tieing only about 180' away. On CD4-210 we discussed the comment regarding the delta between initial leakoff and pump in EMWs made in the letter submitted with the volume increase request for CD4-208. In order to provide further clarification, it may be appropriate to conduct a new pump in on CD4-210. Please look at the information you have for that well to make your determination regarding a new pump in. That decision is solely CPAI's Good luck. I am sure we will talk further. Tom Maunder, PE AOGCC 1 of 1 1 1/27/2006 10:30 AM ~~ ConocoPhillips November 3, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-17 (APD 206-118) Dear Commissioner: P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 ConocoPhillips Alaska, Inc. submits the Well Completion Report for the recent drilling operations on the Alpine well CD4-17. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~ ~ ~ ~~~ ~,- G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells G. C. Alvord Alpine Drilling Team Leader Drilling & Wells GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ V ~v~''~~ 4~ ~ 2COS WELL COMPLETION OR RECOMPLETION REPORT,,~~II~ 1a. Well Status: Oil ~ r Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: ~s1f,~OC3 ~ Development ^/ ExploYatory ff^--II Service ^ Stratigraphic TestLJ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: October 4, 2006 12. Permit to Drill Number: 206-118 / • 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: September 12, 2006 ~ 13. API Number. 50-103-20534-00 4a. Location of Well (Governmental Section): Surtace: 2962' FNL, 380' FEL, Sec. 24, T11N, R4E, UM 7. Date TD Reached: October 1, 2006 14. Well Name and Number: CD4-17 At Top Productive Horizon: 2227' FSL, 204' FWL, Sec. 26, T11 N, R4E, UM 8. KB Elevation (ft): 37' GL 15. Field/Pool(s): Colville River Field Total Depth: 4495' FNL, 1814' FEL, Sec. 15, T11 N, R4E, UM 9. Plug Back Depth (MD + TVD): 17975' MD / 7491' TVD Alpine Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 377864 y- 5957452 ~ Zone- 4 10. Total Depth (MD + TVD): ' 17975' MD / 7491' TVD 16. Property Designation: • ADL 380077, 380075 TPI: x- 367803 y- 5952251 Zone- 4 Total Depth: x- 365933 - 5961402 Zone- 4 11. Depth where SSSV set: DB profile @ 2262' MD 17. Land Use Permit: ALK 380077 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1700' MD 21. Logs Run: GR/Res/Dens/Neutron 22. CASING, LINERAND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" pre-installed 9.625" 40# L-80 37' 3009' - 37' 2387' 12.25" 400 sx AS Lite, 230 sx Class G 7" 26# L-80 37' 13334' , 37' 7491' 8.75" 218 sx LiteCRETE, 158 sx Class G 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 11826' 11753' 6.125" open hole completion from 13334'-17975' ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 26. PRODUCTION TEST Date First Production not available Method of Operation (Flowing, gas lift, etc.) / to be pre-produced at a later time w~ Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RA710 Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). i Submit core chips; if none, state "none". ~ L'~%''~ ~ -~ ~ ~s<v ~~~ ~y ~~yy . ,F NONE _~ ! . 50C Form 10-407 Revised 12/2003 CO TI l~ ¢N~~ ~ ~ ~i\ ~ ~ ~ /~• ~ G~p G zs. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD4-17 Top of Alpine 'A' 13510' 7205' N/A 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 C. Alv Title: Alpine Drilling Team Leader l~/.3~0 (, Signature ~ ~..-/~ Phone Z ~ ? ~ Date a .. ( ~ G 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. Prepared by Sharon Allsup-Drake 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 10-407 Revised 12/2003 Halliburton Company Survey Report I Company: ConocoPhillips Alaska Inc . .Date: 10/18/2006 7 ime: 14:49:13 Pace: Field: Colville River Unit Go-ordinate(NE) Reference: .Well: CD4-17, True North Site: Alpine CD4 Ve rtical {TVD) Re ference: CD4-17:-56.1 ~ Well: CD4-17 Section (VS) Refer ence: Well (O.OON,O.OOE,287.39Azi) Wellpath: CD4-17 Su rvey Calculation Method: Minimum Curvature Db: OracJe Field: Colville River Unit North Slope Alaska United States Map System:US State Pl ane Coordin ate System 1927 ~ Map Zone: Alaska, Zone 4 Geo Datum: NAD27 {Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: CD4-17 Slot Name: Alpine CD4 Well Position: +N/-S -79.49 ft Northing: 5957451.65 ft Latitude: 70 17 32.184 N ~ +E/-W -309.85 ft Easti ng : 377863.63 ft Longitude: 150 59 19.793 W Position Uncertainty: 0.00 ft Wellpath: CD4-17 Drilled From: Well Ref. Point 501032053400 Tie-on Depth: 36.60 ft Current Datum: CD4-17: Height 56.10 ft Above System Datum: Mean Sea Level Magnetic Data: 9/6/2006 Declination: 23.06 deg i Field Strength: 57547 nT Mag Dip Angle: 80.66 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.60 0.00 0.00 287.39 Survey Program for Definitive Wellpath Date: 9/14/2006 Validated: No V ersion: 13 Actual From To Survey Toolcode Tool Name ft ft 81.00 533.00 CD4-17 gyro (81.00-533.00) C B-GYRO-SS Camera based gyro single shot 569.20 17899.70 CD4-17 (569.20-17899.70) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey MD Incl Azim TV1) tiysTVl) v/S 1:~~V Maple MapE Tool ft deg deg ft ft ft ft ft ft __ 36.60 0.00 0.00 36.60 -19.50 0.00 0.00 5957451.65 377863.63 ~ TIE LINE 81.00 0.00 284.00 81.00 24.90 0.00 0.00 5957451.65 377863.63 CB-GYRO-SS / 166.00 0.25 267.00 166.00 109.90 -0.01 -0.19 5957451.64 377863.44 CB-GYRO-SS 259.00 0.50 263.00 . 259.00 202.90 -0.07 -0.79 5957451.59 377862.84 CB-GYRO-SS i 350.00 2.25 221.00 349.97 293.87 -1.47 -2.36 5957450.22 377861.25 CB-GYRO-SS 443.00 4.25 228.00 442.82 386.72 -5.15 -6.12 5957446.60 377857.43 CB-GYRO-SS 533.00 4.75 245.00 532.54 476.44 -8.96 -11.97 5957442.89 377851.52 CB-GYRO-SS 569.20 4.71 252.83 568.62 512.52 -10.03 -14.75 5957441.86 377848.72 MWD+IFR-AK-CAZ-SC 660.22 6.08 255.11 659.23 603.13 -12.37 -22.98 5957439.65 377840.45 MWD+IFR-AK-CAZ-SC 755.26 7.28 255.78 753.63 697.53 -15.14 -33.68 5957437.06 377829.71 MWD+IFR-AK-CAZ-SC 841.11 10.11 260.22 838.48 782.38 -17.76 -46.38 5957434.65 377816.97 .MWD+IFR-AK-CAZ-SC 935.50 16.37 263.56 930.32 874.22 -20.66 -67.79 5957432.09 377795.52 MWD+IFR-AK-CAZ-SC 1031.03 21.85 260.90 1020.55 964.45 -24.99 -98.74 5957428.27 377764.51 MWD+IFR-AK-CAZ-SC 1126.19 22.96 259.25 1108.53 1052.43 -31.25 -134.46 5957422.59 377728.69 MWD+IFR-AK-CAZ-SC 1221.68 26.53 263.49 1195.24 1139.14 -37.14 -173.96 5957417.34 377689.10 MWD+IFR-AK-CAZ-SC 1316.83 26.01 263.81 1280.57 1224.47 -41.80 -215.82 5957413.36 377647.18 MWD+IFR-AK-CAZ-SC 1412.15 28.85 262.84 1365.16 1309.06 -46.92 -259.42 5957408.95 377603.50 MWD+IFR-AK-CAZ-SC 1507.28 32.36 261.22 1447.03 1390.93 -53.67 -307.37 5957402.98 377555.45 MWD+IFR-AK-CAZ-SC 1602.28 36.02 259.61 1525.60 1469.50 -62.59 -359.99 5957394.92 377502.70 MWD+IFR-AK-CAZ-SC I 1697.57 39.63 258.69 1600.85 1544.75 -73.61 -417.37 5957384.83 377445.15 MWD+IFR-AK-CAZ-SC 1792.84 42.31 258.40 1672.78 1616.68 -86.02 -478.58 5957373.42 377383.75 MWD+IFR-AK-CAZ-SC 1887.55 43.80 259.45 1741.98 1685.88 -98.43 -542.04 5957362.05 377320.11 .MWD+IFR-AK-CAZ-SC 1982.63 46.71 259.70 1808.91 1752.81 -110.65 -608.44 5957350.91 377253.52 MWD+IFR-AK-CAZ-SC 2078.27 50.91 259.52 1871.88 1815.78 -123.63 -679.22 5957339.08 377182.55 MWD+IFR-AK-CAZ-SC 2170.57. 53.48 259.69 1928.45 1872.35 -136.78 -750.94 5957327.10 377110.63 MWD+IFR-AK-CAZ-SC 2268.92 55.64 259.37 1985.48 1929.38 -151.35 -829.73 5957313.82 377031.62 MWD+IFR-AK-CAZ-SC 2364.01 56.19 259.91 2038.77 1982.67 -165.51 -907.20 5957300.92 376953.93 MWD+IFR-AK-CAZ-SC i 2456.50 57.18 260.22 2089.57 2033.47 -178.84 -983.33 5957288.82 376877.60 MWD+IFR-AK-CAZ-SC 2554.30 57.84 260.23 2142.10 2086.00 -192.85 -1064.63 5957276.14 376796.10 MWD+IFR-AK-CAZ-SC Halliburton Company, Survey Report Company: ConocoPhillips Alaska Inc. Datc: 1 011 812 0 0 6 Timc: 14:49:13 Pair. 2 Field: Colville Rive r Unit Co-ordinatel~f:) Reference: V'Jefi: CD4-17, True North Site: Alpine CD4 Verti cal (TVD) Kefcrence: CDd-'E 7: 56.9 Weil: CD4-17 Section (VS) Reference: Well (O.OON,O. OOE,287,39Azij Weilpath: CD4-17 Survey C'alculati un ~{ethod: Minimum Curv ature 1)b: Oracle Sure e~~ ail) Intl Aiim llll ti~.TVD N!S E/W ivlapN MapE fool ft 'deg deg ft ft ft ft ft ft 2648. 03 57.45 259.65 2192.26 2136.16 -206 .68. -1142.59 5957263 .58 376717.93 MWD+IFR-AK-CAZ-SC 2743. 31 56.85 259.70 2243.95 2187.85 -221 .02 -1221.34 5957250 .52 376638.97 MWD+IFR-AK-CAZ-SC 2839. 87 57.30 260.84 2296.43 2240.33 -234 .72 -1301.22 5957238 .12 376558.88 MWD+IFR-AK-CAZ-SC 2935. 14 57.90 262.73 2347.48 2291.38 -246 .21 -1380.83 5957227 .93 376479.10 MWD+IFR-AK-CAZ-SC 2972. 50 58.19 262.63 2367.25 2311.15 -250 .24 -1412.27 5957224 .40 376447.60 MWD+IFR-AK-CAZ-SC 3008. 59 57.82 263.16 2386.38 2330.28 -254 .03 -1442.64 5957221 .11 376417.17 MWD+IFR-AK-CAZ-SC 3104. 48 57.10 264.21 2437.96 2381.86 -262 .93 -1522.98 5957213 .52 376336.70 MWD+IFR-AK-CAZ-SC 3200. 52 56.62 263.84 2490.46 2434.36 -271 .30 -1602.96 5957206 .45 376256.60 MWD+IFR-AK-CAZ-SC 3295. 32 56.99 263.34 2542.36 2486.26 -280 .15 -1681.80 5957198 .88 376177.64 MWD+IFR-AK-CAZ-SC 3390. 27 58.17 262.99 2593.27 2537.17 -289 .69 -1761.38 5957190 .63 376097.93 MWD+IFR-AK-CAZ-SC 3485. 35 57.43 261.86 2643.93 2587.83 -300 .30 -1841.13 5957181 .33 376018.02 MWD+IFR-AK-CAZ-SC 3579. 87 56.47 262.50 2695.48 2639.38 -311 .08 -1919.62 5957171 .83 375939.37 MWD+IFR-AK-CAZ-SC 3674. 86 55.38 262.05 2748.70 2692.60 -321 .65 -1997.58 5957162 .52 375861.25 MWD+IFR-AK-CAZ-SC 3769. 97 54.60 262.46 2803.27 2747.17 -332 .15 -2074.77 5957153 .28 375783.91 MWD+IFR-AK-CAZ-SC 3865. 49 54.36 261.45 2858.76 2802.66 -343 .03 -2151.75 5957143 .65 375706.77 MWD+IFR-AK-CAZ-SC 3960. 35 53.98 261.22 2914.29 2858.19 -354 .62 -2227.78 5957133 .30 375630.57 MWD+IFR-AK-CAZ-SC 4055. 81 54.83 260.03 2969.86 2913.76 -367 .26 -2304.36 5957121 .90 375553.80 MWD+IFR-AK-CAZ-SC 4150. 60 54.21 259.91 3024.87 2968.77 -380 .71 -2380.37 5957109 .70 375477.59 MWD+IFR-AK-CAZ-SC 4246. 15 53.51 259.11 3081.23 3025.13 -394 .75 -2456.24 5957096 .88 375401.50 MWD+IFR-AK-CAZ-SC 4341. 37 52.41 259.35 3138.58 3082.48 -408 .96 -2530.91 5957083 .90 375326.62 MWD+IFR-AK-CAZ-SC 4434. 53 51.06 258.48 3196.28 3140.18 -423 .02 -2602.69 5957071 .01 375254.63 MWD+IFR-AK-CAZ-SC 4529. 51 52.69 259.19 3254.91 3198.81 -437 .48 -2675.99 5957057 .74 375181.11 MWD+IFR-AK-CAZ-SC 4625. 12 51.38 260.05 3313.73 3257.63 -451 .06 -2750.13 5957045 .36 375106.76 MWD+IFR-AK-CAZ-SC ~ 4719. 94 51.80 260.97 3372.64 3316.54 -463 .31 -2823.41 5957034 .31 375033.30 MWD+IFR-AK-CAZ-SC 4815. 00 52.66 261.81 3430.86 3374.76 -474 .56 -2897.71 5957024 .27 374958.84 MWD+IFR-AK-CAZ-SC I . I 4910. 16 56.33 262.86 3486.12 3430.02 -484 .87 -2974.47 5957015 .21 374881.93 MWD+IFR-AK-CAZ-SC 5005. 10 57.60 263.15 3537.88 3481.78 -494 .56 -3053.46 5957006 .80 374802.79 MWD+IFR-AK-CAZ-SC 5100. 33 58.53 263.47 3588.25 3532.15 -503 .98 -3133.73 5956998 .69 374722.39 MWD+IFR-AK-CAZ-SC ~ 5195. 43 59.33 262.47 3637.33 3581.23 -513 .95 -3214.57 5956990 .04 374641.40 MWD+IFR-AK-CAZ-SC 5291. 46 59.06 261.53 3686.51 3630.41 -525 .43 -3296.25 5956979 .89 374559.55 MWD+IFR-AK-CAZ-SC 5386. 75 59.54 261.42 3735.16 3679.06 -537 .57 -3377.28 5956969 .06 374478.34 MWD+IFR-AK-CAZ-SC 5482. 04 58.72 261.80 3784.05 3727.95 -549 .51 -3458.19 5956958 .44 374397.25 MWD+IFR-AK-CAZ-SC 5577. 59 58.26 261.53 3833.99 3777.89 -561 .32 -3538.79 5956947 .94 374316.48 MWD+IFR-AK-CAZ-SC 5672. 58 58.19 261.99 3884.01 3827.91 -572 .89 -3618.71 5956937 .67 374236.39 MWD+IFR-AK-CAZ-SC 5768. 17 57.52 262.54 3934.87 3878.77 -583 .78 -3698.91 5956928 .08 374156.03 MWD+IFR-AK-CAZ-SC 5863. 43 57.33 262.69 3986.16 3930.06 -594 .10 -3778.52 5956919 .06 374076.27 MWD+IFR-AK-CAZ-SC 5958. 73 56.81 263.40 4037.97 3981.87 -603 .79 -3857.92 5956910 .66 373996.73 MWD+IFR-AK-CAZ-SC 6052: 87 56.49 263.70 4089.72 4033.62 -612 .62 -3936.06 5956903 .10 373918.47 MWD+IFR-AK-CAZ-SC 6148. 12 56.28 264.27 4142.45 4086.35 -620 .94 -4014.94 5956896 .07 373839.46 MWD+IFR-AK-CAZ-SC 6242. 92 57.07 263.99 4194.53 4138.43 -629 .04 -4093.74 5956889 .25 373760.55 MWD+IFR-AK-CAZ-SC I 6338. 26 58.52 264.10 4245.34 4189.24 -637 .41 -4173.97 5956882 .19 373680.20 .MWD+IFR-AK-CAZ-SC I 6432. 25 58.02 263.16 4294.78 4238.68 -646 .28 -4253.42 5956874 .61 373600.63 MWD+IFR-AK-CAZ-SC j 6527. 59 59.26 262.93 4344.39 4288.29 -656 .13 -4334.23 5956866 .07 373519.67 MWD+IFR-AK-CAZ-SC 6623. 07 60.79 261.78 4392.09 4335.99 -667 .14 -4416.20 5956856 .40 373437.54 MWD+IFR-AK-CAZ-SC 6718. 62 59.54 259.39 4439.63 4383.53 -680 .69 -4497.96 5956844 .18 373355.58 MWD+IFR-AK-CAZ-SC 6813. 93 59.69 258.27 4487.84 4431.74 -696 .62 -4578.62 5956829 .57 373274.68 MWD+IFR-AK-CAZ-SC I 6909. 44 59.77 257.97 4535.99 4479.89 -713 .60 -4659.34 5956813 .90 373193.70 MWD+IFR-AK-CAZ-SC 7004. 77 60.05 258.81 4583.78 4527.68 -730 .20 -4740.14 5956798 .62 373112.65 MWD+IFR-AK-CAZ-SC ! 7100. 00 59.85 259.44 4631.47 4575.37 -745 .75 -4821.08 5956784 .38 373031.47 MWD+IFR-AK-CAZ-SC 7193. 07 59.18 260.33 4678.69 4622.59 -759 .84 -4900.04 5956771 .58 372952.30 MWD+IFR-AK-CAZ-SC i 7290. 20 58.60 260.30 4728.87 4672.77 -773 .83 -4982.01 5956758 .93 372870.12 MWD+IFR-AK-CAZ-SC 7385. 17 58.10 259.91 4778.71 4722.61 -787 .72 -5061.66 5956746 .33 372790.26 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Compan}: Con0ooPhillips Alaska lnC. Field: Colville River Unit Site: Alpine CD4 Well: CD4-17 Wellpath: CD4-17 Date: 10/18/2D06 "Lime: 14:49 13 1'a~r. 3 Co-ordinatc(lY~;) Keference: Well: GD4-17, True North Vertical (TVD) Reference: CD4-17: 56.1 Section (~'S),Reference: Well (O.OON,O.OOE,287 39Azi) ~Snrvey CaJeulaHon Method: Minimum Curvature Db: Oracle tiur~ ey MD Incl lzim l ~ I) Sys "£VD M1';5 E/W Mapi~' MapE fool ft deg deg ft ft ft ft ft ft 7480.29 57.30 259. 63 4829. 53 4773.43 -802.00 -5140.78 5956733.34 .372710. 93 MWD+IFR-AK-CAZ-SC 7574.11 57.69 260. 04 4879. 95 4823.85 -815.96 -5218.66 5956720.65 372632. 84 MWD+IFR-AK-CAZ-SC 7668.63 58.10 259. 97 4930. 18 4874.08 -829.86 -5297.51 5956708.03 372553. 78 MWD+IFR-AK-CAZ-SC 7762.93 57.96 259. 55 4980. 11 4924.01 -844.08 -5376.23 5956695.10 372474. 84 MWD+IFR-AK-CAZ-SC 7857.72 57.44 260. 22 5030. 77 4974.67 -858.15 -5455.11 5956682.31 372395. 75 MWD+IFR-AK-CAZ-SC 7952.80 56.98 260. 37 5082. 26 5026.16 -871.62 -5533.89 5956670.12 372316. 77. MWD+IFR-AK-CAZ-SC 8047.58 56.36 260. 78 5134. 33 5078.23 -884.59 -5612.01 5956658.42 372238. 45 -MWD+IFR-AK-CA2-SC 8143.00 56.64 260. 96 5187. 00 5130.90 -897.22 -5690.58 5956647.07 372159. 70 MWD+IFR-AK-CAZ-SC 8238.52 57.75 261. 33 5238. 75 5182.65 -909.58 -5769.90 5956636.01 372080. 19 MWD+IFR-AK-CAZ-SC 8333.12 58.04 260. 85 5289. 03 5232.93 -921.99 -5849.07 5956624.88 372000. 84 MWD+IFR-AK-CAZ-SC 8428.03 58.02 261. 15 5339. 28 5283.18 -934.58 -5928.59 5956613.58 371921. 13 MWD+IFR-AK-CAZ-SC 8523.60 57.72 261. 07 5390. 11 5334.01 -947.09 -6008.55 5956602.38 371840. 98 MWD+IFR-AK-CAZ-SC 8618.53 57.28 260. 92 5441. 11 5385.01 -959.62 -6087.63 5956591.13 371761. 72 MWD+IFR-AK-CAZ-SC 8713.93 56.87 261. 79 5492. 97 5436.87 -971.66 -6166.80 5956580.38 371682. 37 MWD+IFR-AK-CAZ-SC 8809.34 57.02 261. 86 5545. 01 5488.91 -983.03 -6245.95 5956570.30 371603. 05 MWD+IFR-AK-CAZ-SC 8903.30 56.95 262. 33 5596. 21 5540.11 -993.87 -6323.99 5956560.74 371524. 85 MWD+IFR-AK-CAZ-SC 8999.84 57.17 262. 06 5648. 70 5592.60 -1004.87 -6404.26 5956551.04 371444. 42 MWD+IFR-AK-CAZ-SC 9095.32 56.87 262. 92 5700. 67 5644.57 -1015.34 -6483.67 5956541.86 371364. 86 MWD+IFR-AK-CAZ-SC 9190.66 57.24 262. 91 5752. 52 5696.42 -1025.21 -6563.06 5956533.29 371285. 32 MWD+IFR-AK-CAZ-SC ~ 9285.90 56.86 262. 43 5804. 33 5748.23 -1035.40 -6642.33 5956524.38 371205. 91 MWD+IFR-AK-CAZ-SC ~ 9381.24 57.25 261. 84 5856. 17 5800.07 -1046.35 -6721.58 5956514.72 371126. 49 MWD+IFR-AK-CAZ-SC 9476.76 57.16 262. 03 5907. 91 5851.81 -1057.62 -6801.09 5956504.75 371046. 82 MWD+IFR-AK-CAZ-SC 9571.90 56.88 262. 11 5959. 70 5903.60 -1068.63 -6880.13 5956495.03 370967. 62 MWD+IFR-AK-CAZ-SC 9667.45 56.35 261. 87 6012. 28 5956.18 -1079.74 -6959.14 5956485.20 370888. 45 MWD+IFR-AK-CAZ-SC 9762.62 56.27 262. 53 6065. 07 6008.97 -1090.49 -7037.59 5956475.72 370809. 84 MWD+IFR-AK-CAZ-SC 9857.79 56.79 262. 74 6117. 56 6061.46 -1100.67 -7116.32 5956466.83 370730. 96 MWD+IFR-AK-CAZ-SC 9952.77 56.82 262. 64 6169. 56 6113.46 -1110.78 -7195.16 5956458.00 370651. 97 MWD+IFR-AK-CAZ-SC 10047.94 57.08 262. 26 6221. 46 6165.36 -1121.26 -7274.24 5956448.81 370572. 74 MWD+IFR-AK-CAZ-SC 10142.77 57.75 261. 97 6272. 53 6216.43 -1132.22 -7353.38 5956439.13 370493. 43 MWD+IFR-AK-CAZ-SC 10238.07 58.10 262. 13 6323. 14 6267.04 -1143.39 -7433.36 5956429.26 370413. 29 MWD+IFR-AK-CAZ-SC 10333.17 57.81 261. 40 6373. 60 6317.50 -1154.94 -7513.14 5956419.02 370333. 35 MWD+IFR-AK-CAZ-SC ~ 10428.40 56.42 260. 98 6425. 30 6369.20 -1167.18 -7592.16 5956408.06 370254. 14 MWD+IFR-AK-CAZ-SC 10523.59 55.70 261. 18 6478. 45 6422.35 -1179.43 -7670.18 5956397.08 370175. 94 MWD+IFR-AK-CAZ-SC 10618.65 56.13 260. 98 6531. 72 6475.62 -1191.64 -7747.96 5956386.14 370097. 98 MWD+IFR-AK-CAZ-SC 10713.81 56.35 261. 78 6584. 60 6528.50 -1203.49 -7826.17 .5956375.56 370019. 59 MWD+IFR-AK-CAZ-SC 10808.73 56.42 262. 01 6637. 15 6581.05 -1214.64 -7904.43 5956365.69 369941 .17 MWD+IFR-AK-CAZ-SC 10904.56 57.21 262. 77 6689. 60 6633.50 -1225.26 -7983.93 5956356.36 369861 .52 MWD+IFR-AK-CAZ-SC 10999.60. 57.90 262. 43 6740. 59 6684.49 -1235.59 -8063.46 5956347.33 369781. 83 MWD+IFR-AK-CAZ-SC 11094.75 57.80 261. 16 6791. 23 6735.13 -1247.08 -8143.19 5956337.13 369701. 93 MWD+IFR-AK-CAZ-SC 11190.11 57.16 262. 21 6842. 49 6786.39 -1258.71 -8222.75 5956326.79 369622. 20 MWD+IFR-AK-CAZ-SC 11285.17 58.17 263. 99 6893. 34 6837.24 -1268.36 -8302.49 5956318.45 369542. 32 MWD+IFR-AK-CAZ-SC 11380.48 59.32 266. 35 6942. 79 6886.69 -1275.20 -8383.67 5956312.92 369461. 05 MWD+IFR-AK-CAZ-SC ~ 11475.33 59.12 269. 35 6991. 34 6935.24 -1278.26 -8465.08 5956311.18 369379. 60 MWD+IFR-AK-CAZ-SC 11570.50 59.32 272. 17 7040. 05 6983.95 -1277.18 -8546.83 5956313.60 369297 .89 MWD+IFR-AK-CAZ-SC 11665.71 60.26 274 .97 7087. 96 7031.86 -1272.05 -8628.93 5956320.06 369215 .89 MWD+IFR-AK-CAZ-SC 11760.84 62.08 278 .26 7133. 84 7077.74 -1262.43 -8711.69 5956331.02 369133 .30 MWD+IFR-AK-CAZ-SC 11855.58 64.32 282 .26 7176. 57 7120.47 -1247.34 -8794.87 5956347.46 369050 .39 MWD+IFR-AK-CAZ-SC 11951.01 66.75 286. 63 7216. 11 7160.01 -1225.65 -8878.95 5956370.51 368966. 68 MWD+IFR-AK-CAZ-SC 12045.91 69.15 290. 23 7251. 74 7195.64 -1197.83 -8962.36 5956399:68 368883. 74 MWD+IFR-AK-CAZ-SC i 12141.34 70.73 292. 34 7284. 48 7228.38 -1165.28 -9045.88 5956433.57 368800. 77 MWD+IFR-AK-CAZ-SC 12236.60 72.04 297. 49 7314. 90 7258.80 -1127.26 -9127.71 5956472.92 368719. 57 MWD+IFR-AK-CAZ-SC 12331.66 73.58 301. 14 7343. 00 7286.90 -1082.79 -9206.87 5956518:67 368641. 15 MWD+IFR-AK-CAZ-SC 12426.11 74.81 304 .61 7368. 73 7312.63 -1033.46 -9283.18 5956569.22 368565. 66 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ('ompany: ConocoPhillipsAlaskalne. Date: 10/18/2006 time: 14:49:13 Pagc: a Field: Gofville River Unit Co -ordinate(1'VE) [ieferencc: Well: CD4-17, True Noah tine: Alpine CD4 Ve r6ca! (T~'D)-Reference: CD4-17: 56.1 Well: CD4 -17 Section (VS) Reference: Well (O.OON,O. OOE,287.39Azi) Wellp:irh: CD4 -17 Su rvey Caletdati un Jiethi~d: Minimum Curv ature `' Db: Oracle Sur~cc ~1D Intl ,~zim ll~D Sys T~`I) P~'!S F/W ~1apI1 ~lapE; -Cool ft deg de g ft ft ft ft ft ft 12521 .12 75.95 309 .06 7392 .73 7336.63 -978 .36 -9356.73 5956625.51 368493.02 MWD+IFR-AK-CAZ-SC ~ 12615 .84 77.56 312 .08 7414 .43 7358.33 -918 .40 -9426.75 5956686:60 368423.99 MWD+IFR-AK-CAZ-SC 12711 .10 78.92 316 .16 7433 .86 7377.76 -853 .48 -9493.68 5956752.58 368358.13 MWD+IFR-AK-CAZ-SC 12806 .22 80.25 318 .93 7451 .05 7394.95 -784 .46 -9556.81 5956822.61 368296.13 MWD+IFR-AK-CAZ-SC 12901 .31 82.44 321 .91 7465 .37 7409.27 -712 .02 -9616.70 5956896.02 368237.44 MWD+IFR-AK-CAZ-SC 12996 .45 84.67 325 .09 7476 .05 7419.95 -636 .03 -9672.91 5956972.90 368182.46 MWD+IFR-AK-CAZ-SC 13091 .75 86.28 327 .53 7483 .57 7427.47 -556 .99 -9725.60 5957052.78 368131.07 MWD+IFR-AK-CAZ-SC 13186 .85 89.31 329 .01 7487 .23 7431.13 -476 .18 -9775.57 5957134.39 368082.42 MWD+IFR-AK-CAZ-SC 13281 .79 88.68 328 .71 7488 .89 7432.79 -394 .93 -9824.66 5957216.41 368034.67 MWD+IFR-AK-CAZ-SC 13316 .02 87.99 329 .19 7489. 88 7433.78 -365 .62 -9842.31 5957246.01 368017.50 MWD+IFR-AK-CAZ-SC 13422 .08 85.56 329 .61 7495. 85 7439.75 -274 .48 -9896.21 5957338.00 367965.09 MWD+IFR-AK-CAZ-SC 13517 .06 87.05 330 .56 7501. 97 7445.87 -192 .33 -9943.48 5957420.90 367919:17 MWD+IFR-AK-CAZ-SC 13612 .42 88.72 334 .37 7505. 49 7449.39 -107 .85 -9987.52 5957506:08 367876.51 MWD+IFR-AK-CAZ-SC 13707 .64 87.30 334 .10 7508. 80 7452.70 -22 .15 -10028.88 5957592.44 367836.54 MWD+IFR-AK-CAZ-SC 13803 .11 86.43 334 .22 7514. 02 7457.92 63 .65 -10070.43 5957678.89 367796.40 MWD+IFR-AK-CAZ-SC 13898 .61 86.37 334 .10 7520. 02 7463.92 149 .43 -10111.97 5957765.33 367756.26 MWD+IFR-AK-CAZ-SC 13994 .51 86.43 334 .19 7526. 04 7469.94 235 .56 -10153.71 5957852:12 367715.93 MWD+IFR-AK-CAZ-SC 14089 .93 86.31 334 .07 7532. 08 7475.98 321 .25 -10195.26 5957938.46 367675.78 MWD+IFR-AK-CAZ-SC 14185 .33 87.05 333 .31 7537. 60 7481.50 406 .62 -10237.48 5958024.50 367634.96 MWD+IFR-AK-CAZ-SC 14281 .21 87.79 331 .34 7541. 92 7485.82 491 .44 -10281.96 5958110.02 367591.86 MWD+IFR-AK-CAZ-SC i 14376 .58 89.52 330 .36 7544. 16 7488.06 574 .70 -10328.40 5958194.02 367546.79 MWD+IFR-AK-CAZ-SC 14472 .28 93.72 333 .81 7541. 45 7485.35 659 .20 -10373.17 5958279.23 367503.40 MWD+IFR-AK-CAZ-SC i ~ 14567 .66 93.53 333 .90 7535. 42 7479.32 744 .65 -10415.12 5958365.34 367462.85 MWD+IFR-AK-CAZ-SC 14663 .61 93.04 334 .67 7529. 92 7473.82 830 .95 -10456.68 5958452.30 367422.70 MWD+IFR-AK-CAZ-SC I 14759 .06 94.03 335 .32 7524. 04 7467.94 917 .29 -10496.95 5958539.28 367383.84 MWD+IFR-AK-CAZ-SC 14854 .06 93.04 335 .34 7518. 18 7462.08 1003 .46 -10536.53 5958626.06 367345.67 MWD+IFR-AK-CAZ-SC 14949 .18 93.78 334 .74 7512. 52 7456.42 1089 .54 -10576.59 5958712.78 367307.01 MWD+IFR-AK-CAZ-SC 15044 .04 94.27 331 .53 7505. 86 7449.76 1173 .94 -10619.35 5958797.86 367265.64 MWD+IFR-AK-CAZ-SC ~ 15139 .18 91.98 327 .23 7500. 68 7444.58 1255 .67 -10667.72 5958880.35 367218.60 MWD+IFR-AK-CAZ-SC 15234 .50 91.74 326 .51 7497. 58 7441.48 1335 .45 -10719.79 5958960.96 367167.84 MWD+IFR-AK-CAZ-SC ~ r 15329 .45 92.24 327 .86 7494. 28 7438.18 1415 .20 -10771.21 5959041.53 367117.72 MWD+IFR-AK-CAZ-SC ~ 15424. 96 90.81 326. 23 7491. 74 7435.64 1495 .30 -10823.T5 5959122.46 367067.10 MWD+IFR-AK-CAZ-SC 15520. 33 91.06 327. 27 7490. 19 7434.09 1575 .05 -10875.43 5959203.04 367016.12 MWD+IFR-AK-CAZ-SC ~ i 15615. 76 89.58 329. 84 7489. 65 7433.55 1656 .45 -10925.21 5959285.24 366967.68 MIND+IFR-AK-CAZ-SC ~ 15711. 22 89.95 334. 15 7490. 05 7433.95 1740 .72 -10970.02 5959370.21 366924.25 MWD+IFR-AK-CAZ-SC ~ 15806. 67 93.04 337. 45 7487. 55 7431.45 1827 .72 -11009.13 5959457.83 366886.56 MWD+IFR-AK-CAZ-SC 15902. 09 90.50 338. 35 7484. 61 7428.51 1916 .08 -11045.01 5959546.76 366852.13 MWD+IFR-AK-CAZ-SC 15996. 02 88.41 337. 00 7485. 50 7429.40 2002 .96 -11080.68 5959634.20 366817.87 MWD+IFR-AK-CAZ-SC 16093. 25 89.83 334. 47 7486. 99 7430.89 2091 .58 -11120.63 5959723.45 366779.37 MWD+IFR-AK-CAZ-SC 16188. 48 90.63 332. 56 7486. 61 7430.51 2176 .81 -11163.10 5959809.35 366738.30 MWD+IFR-AK-CAZ-SC I 16283. 67 90.94 330. 75 7485. 31 7429.21 2260 .58 -11208.28 5959893.83 366694.48 MWD+IFR-AK-CAZ-SC ~ 16379. 04 89.52 329. 17 7484. 92 7428.82 2343 .13 -11256.02 5959977.14 366648.09 MWD+IFR-AK-CAZ-SC 16474. 34 89.02 327. 57 7486. 14 7430.04 2424 .27 -11306.00 5960059.07 366599.45 MWD+IFR-AK-CAZ-SC ~ 16570. 02 88.35 327. 46 7488. 33 7432.23 2504 .95 -11357.37 5960140.58 366549.40 MWD+IFR-AK-CAZ-SC 16665. 34 88.10 330. 95 7491. 29 7435.19 2586 .78 -11406.14 5960223.18 366501.97 MWD+IFR-AK-CAZ-SC 16760. 20 90.14 333 .12 7492. 75 7436.65 2670 .55 -11450.61 5960307.65 366458.86 MWD+IFR-AK-CAZ-SC ~ 16855. 37 90.51 333. 63 7492. 21 7436.11 2755 .62 -11493.26 5960393.40 366417.61 i MWD+IFR-AK-CAZ-SC 16947. 30 90.07 336. 16 7491. 74 7435.64 2838 .86 -11532.26 5960477.25 366379.97 MWD+IFR-AK-CAZ-SC 17045. 78 90.69 336. 32 7491. 09 7434.99 2928 .99 -11571.94 5960568.01 366341.76 MWD+IFR-AK-CAZ-SC ~ 17141. 04 91.12 333. 49 7489. 58 7433.48 3015 .24 -11612.33 5960654.89 366302.78 MWD+IFR-AK-CAZ-SC I 17236. 36 88.65 332. 51 7489. 77 7433.67 3100 .16 -11655.60 5960740.50 366260.90 MWD+IFR-AK-CAZ-SC 17331. 30 89.33 332. 09 7491. 45 7435.35 3184 .21 -11699.73 5960825.24 366218.15 i MWD+IFR-AK-CAZ-SC ': Halliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. Field: Colville River Unit Site: Alpine CD4 ;, Well: CD4-17 Welbath: GD4-17 Survey MD lncl Azim TVD ft deg deg ft 17426 .68 89.95 332.26 7492. 05 17521 .50 90.57 331.63 7491. 62 17616 .58 90.44 332.01 7490. 78 17711 .77 90.13 332.85 7490. 30 17806 .59 90.63 333.48 7489. 68 17899 .70 89.15 334.33 7489. 85 • 17975 .00 89.15 334.33 7490. 97 . Date: 10/18/2006 Time 14:49:13 1'a~c: c Caordinate(NEpReference: Well: CD4-17; True North Vertical ('TVD) Reference: CD4-17: 56.1 Section (VS) Reference: Weil (O.OON,O.OOE,287.39Azi) Survey Calcnlation Method: Minimum Curvature llb: Oracle tit's ll~ll '~fS EIW Y1apA 11apti 7~uul >ft ft ft ft ft 7435.95 3268.56 -11744.25 5960910 .30 366175.01 MWD+IFR-AK-CAZ-SC 7435.52 3352.23 -11788.84 5960994 .68 366131.78 MWD+IFR-AK-CAZ-SC 7434.68 3436.04 -11833.74 5961079 :20 366088.26 MWD+IFR-AK-CAZ-SC 7434.20 3520.42 -11877.80 5961164 .28 366045.58 MWD+IFR-AK-CAZ-SC 7433.58 3605.03 -11920.60 5961249 .56 366004.16 MWD+IFR-AK-CAZ-SC 7433.75 3688.64 -11961.55 5961333 .82 365964.57 MWD+IFR-AK-CAZ-SC 7434.87 3756.50 -11994.17 5961402 .20. 365933.07. PROJECTED to TD Conv-+coPhii s ~ Time Lo Summa ~ WeJtview Yyeb vrtng Time Lo s Date From To Dur S De th E. De th Phase Code Subcode T COM 09/11/2006 00:00 04:00 4.00 0 0 MIRU MOVE DMOB P Rigged down and moved rig off location to near CD4-17. 04:00 12:00 8.00 0 0 MIRU MOVE RURD P Hanging new wind walls requested by CPAI. 12:00 19:00 7.00 0 0 MIRU MOVE RURD P Hanging new wind walls requested by CPAI. 19:00 23:00 4.00 0 0 MIRU MOVE PSIT P Position rig over well and connect mods. 23:00 00:00 1.00 0 0 COND1 MOVE RURD P Rig up riser and flowline. Prep rig for S ud. 09/12/2006 00:00 01:00 1.00 0 MIRU MOVE RURD P Clean up rig floor - RU service lines 01:00 04:00 3.00 SURFA DRILL OTHR P Nipple up surface riser -Take on spud mud -Load i e shed w/ 24 'ts HWDP 04:00 05:00 1.00 SURFA DRILL PULD P PU & stand back NM flex DC's & jars 05:00 05:30 0.50 SURFA RIGMN SVRG P Service TD 05:30 07:00 1.50 SURFA DRILL PULD P PU & stand back 8 stds HWDP 07:00 09:00 2.00 0 73 SURFA DRILL PULD P MU BHA #1 -Orient motor & MWD - U load MWD 09:00 09:15 0.25 73 73 SURFA DRILL SFTY P Held pre spud safety meeting with crew 09:15 10:15 1.00 73 SURFA DRILL OTHR P Fill riser & check for leaks -Fill drill string & pressure test mud lines to 3500 si 10:15 12:00 1.75 114 168 SURFA DRILL DRLG P Spud in @ 1015 hrs - Drill 12 1/4" hole f/ 114' to 168' -ADT - .58 hrs WOB 10 RPM 40 GPM 450 @ 720 si 12:00 00:00 12.00 168 925 SURFA DRILL DDRL P Drill 12 1/4" hole f/ 168' to 925' MD 920' TVD ADT - 5.83 hrs =ART - 2.81 hrs AST - 3.02 hrs WOB 10/15 K RPM 40/50 GPM 487 @ 1120 psi Stirng wt. PU 123 SO 110 Rot 105 Torque on/off btm - 5,000/4,500 ft/Ibs Gyro surveys @ 81', 166', 259', 350' ,443', 533', 569', 660', 755', 841' 09/13/2006 00:00 12:00 12.00 925 1,923 SURFA DRILL DDRL P Drill 12 1/4" hole f/ 925' to 1923' MD 1766' TVD ADT - 8.07 hrs =ART 5.14 hrs AST 2.93 hrs WOB 15/20 k RPM 60 GPM 600 @ 1700 psi String wt. PU 134 SO 126 Rot 132 Tor ue on/off btm. - 7,000/5,500 ft/Ibs Page ~ of 13 ~~~ F~a`iC~E ~ ~~ ~~ Time Los Date From To Dur th E. De th Phase Code Subcode T _ M 09/13/2006 12:00 00:00 12.00 1,923 2,601 SURFA DRILL DDRL P Drill 12 1/4" hole f/ 1923' to 2601' MD 2142' TVD ADT - 8.52 hrs. =ART - 7.44 hrs. AST - 1.08 hrs. WOB 15/20 k RPM 60 GPM 604 @ 1870 psi String wt. PU 135 SO 124 Rot 130 Tor ue on/off btm. - 7,500/6,500 ft/Ibs. 09/14/2006 00:00 09:00 9.00 2,601 3,020 SURFA DRILL DDRL P Drill 12 1/4" hole f/ 2601' to 3020' MD 2392' TVD ADT - 7.93 hrs = AST - .78 hrs. ART - 7.15hrs WOB 10/20 k RPM 60 GPM 600 @ 1980 psi String wt. PU 140 SO 124 Rot 132 Tor ue on/off btm. - 7,500/6,000 ft/Ibs. 09:00 10:00 1.00 3,020 3,020 SURFA DRILL CIRC P Circ hole clean for wiper trip - 650 gpm 2090 si w/ 60 r m 10:00 16:00 6.00 3,020 3,020 SURFA DRILL WPRT P Wiper trip f/ 3020' to 892' - w/ pump @ 450 gpm @ 1000 psi -Flow check @ 892' Static - RIH f/ 892' to 2986' - Break circ & wash down f/ 2986' to 3020' -hole in ood condition 16:00 16:30 0.50 3,020 3,020 SURFA DRILL CIRC P Circulate hole clean after wiper trip - flow check -static 16:30 19:30 3.00 3,020 892 SURFA DRILL TRIP P POOH on TT f/ 3020' to 892' -hole in good condition & took proper fill -Flow check -static 19:30 22:15 2.75 892 0 SURFA DRILL PULD P LD BHA -jars, NMflex DC's -down load MWD -Break bit - LD MWD & Motor 22:15 00:00 1.75 0 0 SURFA CASIN( RURD P RU to run 9 5/8" csg - LD drilling bails - MU fill u u tool 09/15/2006 00:00 01:00 1.00 0 0 SURFA CASIN( RURD P RU to run 9 5/8" csg 01:00 01:15 0.25 0 0 SURFA CASIN( SFTY P Held pre-job safety meeting 01:15 04:15 3.00 0 1,759 SURFA CASIN( RNCS P Ran 9 5/8" 40# L-80 MBTC casing as follows: FS (Ray Oil Tools Silver bullet) 2 jts.- FC (Halliburton Super Seal) 2jts. ( first 4 connections made up w/ BakerLoc -fill pipe & checked floats) 41 'ts. to 1759' - 45 'ts. total 04:15 05:15 1.00 1,759 1,759 SURFA CASIN( CIRC P Break circulation -stage pumps up to 3.5 bbls/min. @ 400 psi Circulate btms u - PU wt 137 SO wt. 123 05:15 07:15 2.00 1,759 3,009 SURFA CASIN( RNCS P Continue running 9 5/8" 40# L-80 MBTC casing - 31 jts (76 jts total) f/ 1759' to 2970' - PU landing jt w/ FMC fluted mandral hanger & land csg on landing ring w/ shoe @ 3009.33' & float collar 2929.99' 07:15 07:45 0.50 3,009 3,009 SURFA CASIN( RURD P RD csg equipment - RU cmt head & lines Time Logs _ Date From To Dur th E. De th Phase Code Subcode T ,OM 09/15/2006 07:45 09:45 2.00 3,009 3,009 SURFA CEME~ CIRC P Break circulation & stage pump up to 6 bbls/min -Circulate hole clean & condition mud for cement 'ob 09:45 10:00 0.25 3,009 3,009 SURFA CEMEf~ SFTY P Held pre job safety & operation meetin with crew 10:00 12:00 2.00 3,009 3,009 SURFA CEMEI~ DISP P Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pumps -Line up Dowell & pump 5 bbls water -Test lines to 2900 psi -Drop btm plug -Mix & pump 52.29 bbls MudPush @ 10.5 ppg @ 5 bbl/min @ 200 psi -Mix & pump Lead slurry (ASL) @ 10.7 ppg @ 7.5 bbls/min @ 200 psi -Observed nut plug marker @ shakers w/ 300 bbls lead slurry pumped -pumped down f. surge can - 316 bbls lead slurry pumped -Switched to tail slurry (G w/ 1 % -SOO2, .20% DO46, .30% DO65) Mixed & pumped 48.6 bbls @ 15.8 ppg @ 5.4 bbls/min @ 200 psi - dropped top plug & chased w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 9.8 ppg mud @ 7 bbls/ min for 180 bbls (400 to 700 psi) slowed pump to 3.5 bbls/min for last 22 bbls of displacement (500 to 600 psi) 202.4 bbls total displacment - Bumped plug w/ 1100 psi -Checked floats OK - CIP @ 1200 hrs. -Full circulation throughout job w/ 108 bbls 10.7 cmt to surface 12:00 13:00 1.00 3,009 3,009 SURFA CEMEI~ OTHR P RU & pressure test 9 5/8" csg to 2500 si for 30 mins. 13:00 14:30 1.50 3,009 3,009 SURFA CEME~ PULD P Flush surface riser - RD cmt e ui ment - LD landin 't. 14:30 15:30 1.00 3,009 SURFA DRILL PULD P ND surface riser 15:30 16:30 1.00 SURFA DRILL OTHR P Install FMC wellhead & test seals to 1000 si 16:30 18:00 1.50 SURFA WELCT NUND P NU BOPE 18:00 22:30 4.50 SURFA WELCT BOPE P Test BOPE - Hydril to 250 & 3500 psi - Test pipe rams -choke manifold valves - choke & kill line valves -floor safety & dart valves - TD IBOP's -blind rams to 250 & 5000 psi -performed accumulator closure test - RD testing e ui ment 22:30 23:00 0.50 SURFA DRILL OTHR P Install wear bushing -blow down choke & kill lines 23:00 00:00 1.00 SURFA DRILL PULD P PU drilling bails & DP elevators - Chan a out 1 bad 't of 5" DP in derrick 09/16/2006 00:00 00:30 0.50 SURFA DRILL OTHR P Bring Geo Span unit to rig floor 00:30 01:00 0.50 SURFA DRILL OTHR P Change DP elevators to 4" & chnage dies in rou hneck Time Logs _ _ `Date From To Dur th E. Depth Phase Code Subcode T M 09/16/2006 01:00 06:00 5.00 SURFA DRILL PULD P LD 45 stds 4" DP f/ derrick 06:00 07:00 1.00 SURFA DRILL OTHR P Change over to 5" handling equipment 07:00 10:00 3.00 SURFA DRILL PULD P PU 90 jts 5" DP f/ pipe shed to 2865' 10:00 10:30 0.50 SURFA DRILL CIRC P Circ & cond. mud @ 8.5 BPM @ 230 si 10:30 12:00 1.50 SURFA DRILL TRIP P POOH w/ 5" DP & stand back in derrick 30 stds 12:00 19:00 7.00 SURFA DRILL PULD P Continue picking up & standing back 5" DP f/shed 171 'ts. 19:00 00:00 5.00 0 315 SURFA DRILL PULD P MU BHA # 2 -bit -GeoPilot - GeoForce - MWD - 1 NM flex DC - Up load MWD -break in GeoPilot bearings -Pressure test GeoSpan - Shallow test tools -PJSM (loading RA sources) Load RA sources - PU 2 NM Flex DC's - RIH w/ 1 std HWDP to 315' 09/17/2006 00:00 01:45 1.75 315 1,924 SURFA DRILL PULD P Continue PU & RIH w/ BHA #2 - HWDP, Jars, 5" DP f/ pipe shed, Ghost reamers f/ 315' to 1924' 01:45 02:30 0.75 1,924 2,776 SURFA DRILL TRIP P RIH w/ BHA # 2 f/ 1924' to 2776' - Picking up remaining 5" Dp f/ pipe shed 02:30 04:00 1.50 2,776 2,776 SURFA RIGMN SVRG P PJSM -Slip & cut drill line & service TD 04:00 04:15 0.25 2,776 2,909 SURFA DRILL TRIP P Wash down f/ 2776' to 2909' (top of cmt) - 420 gpm @ 1380 psi w/ 10 r m's - 8,500 ft/Ibs for ue 04:15 08:15 4.00 2,909 3,020 SURFA CEME~ DRLG P Clean out shoe track -Drill cmt f/ 2909' to 2926' -Drill wiper plugs to 2929' - Drill out FC @ 2929' -Drill cmt to 3007' - DriA out FS to 3009' -Clean out rat hole to 3020' 08:15 08:45 0.50 3,020 3,040 SURFA DRILL DRLG P Drill 20' new hole f/ 3020' to 3040' MD 2403' TVD ADT - .15 hrs WOB 6/15 RPM 20 GPM 500 @ 1650 si 08:45 09:00 0.25 3,040 3,040 SURFA DRILL CIRC P Circulate hole clean for FIT 09:00 10:00 1.00 3,040 3,040 SURFA DRILL FIT P RU & perform FIT to 18.1 ppg EMW w/ 9.6 ppg mud w/ 1060 psi surface ressure 2387' TVD 10:00 10:45 0.75 3,040 3,040 INTRMI DRILL CIRC P Change well over to 9.6 ppg LSND mud -flow check (static) -Establish base line ECD @ 10.14 ppg w/ 560 mw/100r m 10:45 12:00 1.25 3,040 3,157 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ GP/TMT assembly f/ 3040' to 3157' MD 2461' TVD ADT - .62 hrs. ECD - 10.3 ppg WOB 10/15 k RPM 20 GPM 550 @ 1470 psi String wt. PU 155 SO 120 Rot 130 Tor ue on/off btm. - 9,000/8,500 ft/Ibs. Pace 4 rif 13 Time Logs ~ - Date From To Dur th E. De th Phase Code Subcode T\ ~OM 09/17/2006 12:00 00:00 12.00 3,157 4,270 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ GPlTMT assembly f/ 3157' to 4270' MD 3095' ND ADT - 8.13 hrs. ECD 10.75 ppg WOB 5/10 k RPM 90 GPM 600 @ 2230 psi String wt. PU 165 SO 125 Rot 140 Tor ue on/off btm - 9500/9000 ft/Ibs. 09/18/2006 00:00 01:45 1.75 4,270 4,454 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ GP/TMT combo f/ 4270' to 4454' MD 3138' ND ADT - 1.25 hrs ECD 10.9 ppg WOB 5/10 k RPM 90 GPM 600 @ 2230 psi String wt. PU 170 SO 125 Rot 142 Torque on/off btm. - 9500/9000 ft.lbs MWD failure 01:45 02:30 0.75 4,454 4,454 INTRM1 DRILL CIRC T Pump sweep & circulate btms up @ 500 gpm / 1500 psi w/ 70 rpm Flow check static 02:30 04:30 2.00 4,454 3,062 INTRM1 DRILL TRIP T POOH f/ 4454' to 3062' w/ pump @ 500 gpm 1500 psi w/ 90 rpm Observed large amount of clay across shakers 04:30 05:00 0.50 3,062 3,062 INTRM1 DRILL CIRC T Circulate hole clean @ 3062' - 500 gpm w/ 90 rpm ICP 1625 FCP 1500 psi -flow check (static) Pull 1 std to 2966' -Blow down TD 05:00 07:45 2.75 3,062 218 INTRM1 DRILL TRIP T POOH on TT f! 2966' to 218' - LD ghost reamers 07:45 08:00 0.25 218 218 INTRM1 DRILL SFTY T Held PJSM on unloading RA sources 08:00 16:00 8.00 218 200 INTRM 1 DRILL PULD T POOH f/ 218' -Unload RA sources - Down load MWD - LD TMT -Change out GeoPilot, bit &MWD -Shallow test tools -Load RA sources MU MN flex DC's 16:00 18:30 2.50 200 4,366 INTRM1 DRILL TRIP T RIH f/ 200' to 4366' -Fill pipe @ 1900' 18:30 19:00 0.50 4,366 4,454 INTRM1 DRILL REAM T Wah down f/ 4366' to 4454' - 550 gpm 1660 si w/ 100 r m 19:00 00:00 5.00 4,454 4,880 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ GP f/ 4454' to 4880' MD 3470' TVD ADT - 3.3 hrs. ECD - 11.01 ppg WOB 10/15 k RPM 100 GPM 550 @ 2250 psi String wt. PU 180 SO 128 Rot 147 Tor ue on/off btm. - 11,000/9500 ft/Ibs. 09/19/2006 00:00 12:00 12.00 4,880 6,090 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ GP f/ 4888' to 6090' MD 4109' ND ATD - 8.26 hrs. ECD - 10.74 ppg WOB 10/16 k RPM 120/140 GPM 600 @ psi String wt. PU 185 SO 137 Rot 165 Torque on/off btm. - 12,500/11,500 ft/Ibs, I,~ age 5 ot'E3 Time Los T Date From To Dur pth E. De th Phase Corte Subcode T M 09/19/2006 12:00 00:00 12.00 6,090 7,820 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ GP f/ 6090' to 7820' MD 5010' TVD ADT - 8.49 hrs ECD - 10.92 ppg WOB 18/20 k RPM 140 GPM 630 @ 2220 psi String wt. PU 195 SO 155 Rot 174 Tor ue on/off btm.- 12,500/9,500 ft/Ibs. 09/20/2006 00:00 12:00 12.00 7,820 9,325 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ GP f/ 7820' to 9325" MD 5825' TVD ADT - 8.18 hrs. ECD - 10.86 ppg WOB 18/20 k RPM 140 GPM 625 @ 2230 psi String wt. PU 210 SO 165 Rot 190 Torque on/off btm.- 14,000/12,500 ft/I bs. 12:00 00:00 12.00 9,325 10,939 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ GP f/ 9325' to 10,939' MD 6705' TVD ADT - 8.72 hrs. ECD - 11.09 ppg WOB 18/22 k RPM 140 GPM 630 @ 2500 psi String wt. PU 235 SO 170 Rot 200 Torque on/off btm.- 18,000/15,000 ft/Ibs. 09/21!2006 00:00 12:00 12.00 10,939 11,835 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/GP f/ 10,939' to 11,835' MD 7169' TVD ADT - 9.34 hrs. ECD 10.70 ppg WOB 10/22 k RPM 140/120 GPM 625 @ 2620 psi 550 @ 2050 psi String wt. PU 255 So 175 Rot 215 Torque on/off btm. - 17,000/14,000 ft/Ibs. 12:00 00:00 12.00 11,835 12,750 INTRM1 DRILL DRLG P Drill 8 3/4" hole w/ GP f/ 11,835' to 12,750' MD 7442' TVD ADT - 10.06 hrs. ECD - 10.77 ppg WOB 19/21 k RPM 120 GPM 550 @ 2150 psi String wt. PU 265 SO 165 Rot 213 Torque on/off btm. - 18,500/16,000 ft/Ibs. 09/22/2006 00:00 09:00 9.00 12,750 13,345 INTRM1 DRILL DDRL P Drill 8 3!4" hole w/ GP f/ 12,750' to 13,345' MD 7491' TVD ~ ADT - 7.21 hrs. ECD - 10.5 ppg WOB 19/21 k RPM 120/90 GPM 550 @ 2090 psi String wt. PU 260 SO 155 Rot 200 Torque on/off btm.- 18,000/16,000 ft/I bs 09:00 12:45 3.75 13,345 12,928 INTRM1 DRILL CIRC P Pump sweep & circ 3 x btms up - @ 600/550 gpm @ 2300/2045 psi w/ 90 rpm 16 k torque -Stand back stds f/ 13345' to 12928' 12:45 13:30 0.75 12,928 12,432 INTRM1 DRILL WPRT P Wiper trip f/ 12,928' to 12,432' @ 550 m 2040 si w/ 60 r m 13:30 14:45 1.25 12,432 12,432 INTRM1 RIGMN OTHR T Lost all power to rig - troulbe shoot problem -slack off on pipe every 10 mins. ~ ~g€~ 6 of '!3 ~ Time Lo s Date From To Dur th E. De th Phase Code Subcode T M 09/22/2006 14:45 16:00 1.25 12,432 11,025 INTRM1 DRILL WPRT P Continue with wiper trip w/ pump f/ 12,432' to 11,025' - 16:00 18:30 2.50 11,025 13,345 INTRM1 DRILL TRIP P Monitor well (static) RIH f/ 11,025'to 13,218' -Wash down f/ 13,218' to 13,345' - took wt @ 12,172' - PU went back throu h OK 18:30 19:30 1.00 13,345 13,345 INTRM1 DRILL CIRC P Circ btms up 550 gpm @ 2090 psi w/ 60 r m 19:30 21:30 2.00 13,345 13,345 INTRM1 DRILL WPRT P Flow check (static) Wiper trip f/ 13345' to 12,389' - Flow check - RIH f/ 12,389' to 13,213' -wash down f/ 13,321' to 13,345' 21:30 22:30 1.00 13,345 13,345 INTRM1 DRILL CIRC P Circulate btms up 550 gpm @ 2090 si w/ 60 r m -flow ck static 22:30 00:00 1.50 13,345 INTRM1 DRILL TRIP P Flow check (static) Spot WSP/CRP to bit -POOH spotting pills f/ 13,345' to 09/23/2006 00:00 02:00 2.00 12,833 11,025 INTRM1 DRILL TRIP P Continue POOH spotting WSP & Csg tube pills f/ 12,833' to 11,025' - 2.5 BPM 350 si -Flow check static 02:00 04:30 2.50 11,025 9,121 INTRM1 DRILL TRIP P POOH on TT f/ 11,025' to 9121' -Flow ck Static -Pump dry job -Blow down TD 04:30 11:00 6.50 9,121 1,898 INTRM1 DRILL TRIP P Continue POOH on TT f/ 9121' to 1898' (top of BHA) -Flow checked @ shoe - static 11:00 12:30 1.50 1,898 743 INTRM1 DRILL TRIP P POOH on TT w/ BHA f/ 1898' to 743' - LD ghost reamers -stand back HWDP & 'ars 12:30 15:45 3.25 743 0 INTRM1 DRILL PULD P LD NM flex DC's -Pull RA sources f/ tools -Down load MWD - LD MWD - Geo ilot & bit 15:45 20:00 4.25 0 0 INTRM1 CASIN( RURD P Rig up for casing job -pull wear bushing -Change top rams to 7" & test -change saver sub to 4" -Set thin wall wear bushing -Rig up fill up tool, casin s ider,elevators & ton s 20:00 20:15 0.25 0 0 INTRM1 CASIN( SFTY P Held pre job ops & safety meeting w/ crew on runnin 7" cs 20:15 00:00 3.75 0 2,773 INTRM1 CASIN( RNCS P Run 7" 26# L-80 BTCM casing as follows: Ray Oil Tools Float shoe - 2 jts csg - Halliburton Float collar - 2 jts. csg (first 4 connections made up w/ BakerLoc - Shutoff baffle for stage cmt job in top of jt. # 3 -Fill pipe & check floats) 61 jts csg to 2773.73' (65 jts total of 311 to run 09/24/2006 00:00 00:30 0.50 2,773 3,196 INTRM1 CASIN( RNCS P Run 7" 26# L-80 BTCM casing from 2774' to 3196' 75 'ts total 00:30 01:00 0.50 3,196 3,196 INTRM1 CASIN( CIRC P Circ casing volume - 5 bpm / 350 psi 01:00 05:00 4.00 3,196 7,050 INTRM1 CASIN( RNCS P Run 7" 26# L-80 BTCM casing from 3196' to 7050' 165 'ts total 05:00 06:00 1.00 7,050 7,050 INTRM1 CASIN( CIRC P Stage pumps up from 2 bpm / 400 psi to5b m-CBU-FCP520 si 'age 7 of 13 Time Logs Date From To Dur th E. De th Phase Code Subcode T M 09/24/2006 06:00 10:45 4.75 7,050 10,899 INTRM1 CASIN( RNCS P Run 7" 26# L-80 BTCM casing from 7050' to 10,899' 255 'ts total 10:45 12:30 1.75 10,899 10,899 INTRM1 CASIN( CIRC P Stage pumps up from 2.5 bpm / 650 psi to 5 bpm - CBU -FCP 700 psi - PUW 280k SOW 160K 12:30 16:00 3.50 10,899 13,334 INTRM1 CASIN( RNCS P Run 7" 26# L-80 BTCM casing from 10,899' to 13,297' (311 jts total) - PUW 385K SOW 170K - MU FMC fluted hanger and LJ -Land hanger in wellhead with Shoe @ 13,334', FC @ ~ 13,245' and insert baffle 13,201' 16:00 16:30 0.50 13,334 13,344 INTRM1 CEMEI~ PULD P Lay down fill up tool -blow down top drive - ri u cement head 16:30 19:00 2.50 13,344 13,344 INTRM1 CEMEf~ CIRC P Stage pumps up to 6 bpm - circ and condition mud -FCP 780 psi - 780 tills pumped -Held PJSM w/ Dowell and crew 19:00 21:30 2.50 13,344 13,344 INTRM1 CEME~ DISP P Cemented 7" csg as follows: Pumped 5 bbls CW100 -Tested lines to 4400 psi -pumped 45 bbls of CW100 4.0 bpm @ 500 psi- Mixed & pumped 40 bbls MudPush @ 10.5 ppg - 4.9 BPM @ 575 psi -Mixed and pumped 129 bbls of lead slurry LiteCRETE @ 11.0 ppg @ 5.5 bpm / 615 - 389 psi - Mixed & pumped 34 bbls tail slurry Class G w/additives) - 15.8 ppg @ 5.1 BPM @340 psi -Dropped top plug w/ 20 bbls water f/ Dowell -switched to rig pumps & displaced cmt w/ 10.0 ppg mud @ 7 BPM for 415 bbls / 580 - 840 psi- 6 bpm for 62 bbls / 790 - 940 psi and 4 bpm / 750 - 770 psi last 12 bbls pumped - 509 bbls total displacement -Bumped plug w/ 1200 psi -Check floats OK - CIP @ 2130 hrs.- Full returns throughout - No pipe movement 21:30 22:30 1.00 13,344 6,665 INTRM1 CEMEI~ CIRC P Pressure up on casing -Stage collar shifted open w/ 3600 psi - Circ and cond mud 5 bpm / 330 psi -prepare for second sta a cement o is Wage 8 s~f 1? Time Logs _ Date From To Dur th E. De th Phase Code Subcode T M 09/24/2006 22:30 23:30 1.00 6,665 6,665 INTRM1 CEMEI~ DISP P Second Stage cement opts as follows: Pumped 10 bbls CW100 - 3.5 bpm @ 202 psi- Mixed 8~ pumped 20 bbls MudPush @ 10.5 ppg - 4.8 BPM @ 275 psi -Mixed & pumped 40.4 bbls tail slurry (Class G w/additives) - 15.8 ppg @ 5.1 BPM @ 290 - 100 psi - Dropped top/closing plug w/ 20 bbls water f/ Dowell -switched to rig pumps & displaced cmt w/ 10.0 ppg mud @ 7 BPM for 225 bbls / 225 - 570 psi -then 4 bpm / 420 - 450 psi last 10 bbls pumped - 255 bbls total displacement - Bumped plug w/ 2690 psi (2240 psi over final displacement press.held 5 minutes) - CIP @ 2330 hrs.- Full returns throughout - No pipe movement - annulus static 23:30 00:00 0.50 6,665 6,665 INTRM1 CEMEI~ RURD P blow down lines - RD cement head 09/25/2006 00:00 00:45 0.75 0 0 INTRM1 CEMEf` OTHR P LD landing jt. -Pull thin wall wear bushin 00:45 01:30 0.75 0 0 INTRMI DRILL OTHR P Set 7" pack off & test to 5000 psi 01:30 02:00 0.50 0 0 INTRM1 DRILL OTHR P LD csg elevators & bails 02:00 04:30 2.50 0 0 INTRM1 WELCT OTHR P Change top pipe rams back to VBR - Set test plug & test to 250 & 5000 psi - ull test lu & set wear bushin 04:30 05:00 0.50 0 0 INTRM1 DRILL OTHR P PU drill pipe elevators & and drilling bails - Rearran a HWDP on i e rack 05:00 14:45 9.75 0 0 INTRM1 DRILL PULD P LD jars f/ derrick - LD 5" DP f/derrick - 324 'ts. 14:45 15:15 0.50 0 0 INTRM1 DRILL PULD P Change running tools to 4" - PJSM 15:15 16:30 1.25 0 289 INTRM1 DRILL PULD P MU BHA #4 -Bit, bs, stab, 3 flex collars, xo, 3 'ts hwd , 'ars, 2 'ts hwd 16:30 22:45 6.25 289 6,485 INTRM1 DRILL TRIP P RIH picking up 4" drill pipe to 6485' 195 'ts ,fill i e eve 60 'ts 22:45 00:00 1.25 6,485 6,665 INTRM1 DRILL REAM P Wash down from 6,485', tagged wiper plug @ 6665', drill out stage collar - 6 bpm / 1040 psi / 100 rpm PUW 153K SOW 118K 09/26/2006 00:00 03:00 3.00 6,665 6,480 INTRM1 CEMEt~ COCF P Drill out stage collar @ 6,665' -wash and ream to 6,766' - circ BU - 6 bpm / 1020 psi / 100 rpm -set back 3 stands to 6480' 03:00 04:15 1.25 6,480 8,067 INTRM1 DRILL TRIP P RIH picking up 4" drill pipe from 6480' to 8067' - loosin SOW 04:15 05:15 1.00 8,067 8,067 INTRM1 DRILL CIRC NP Wash and ream from 8,067' to 8,360' 8 bpm / 1600 psi ! 100 rpm - CBU observed strong push of soft cement cuttings at shakers -stand back 2 stands to 8067' 05:15 10:00 4.75 8,067 12,963 INTRM1 DRILL TRIP P RIH picking up 4" drill pipe from 8,067' to 12,682' -RIH with stands from derrick to 12,963' ~~ge 9 of 13~ Time Logs _ Date From To Dur th E. Depth Phase Code Subcode OM 09/26/2006 10:00 11:30 1.50 12,963 12,963 INTRM1 RIGMN SVRG P Slip and cut drilling line- service top drive and drawworks 11:30 12:30 1.00 12,963 13,058 INTRM1 CEME~ COCF P Precautionary wash and ream from 12,963' to 13,058' - circ hole for casing test-7b m/1960 si/100r m 12:30 13:45 1.25 13,058 13,058 INTRMI CASIN( DHEQ P RU and test casing to 3500 psi for 30 minutes - RD and blow down lines 13:45 17:45 4.00 13,058 13,314 INTRM1 CEMEf~ COCF P Precautionary ream from 13058' to 13,110' -clean out cement from 13,110', drill out wiper plug and baffle plate @ 13201' - 7 bpm / 1960 psi / 100 rpm -Drill out cement / FC / cement to 13,314' - circ hole clean @ 9 bpm / 2640 psi / 80 rpm -flow check well, static - um d "ob 17:45 00:00 6.25 13,314 6,480 INTRM1 CEME~ TRIP P POOH from 13,314' to 6,480' on trip tank. 09/27/2006 00:00 02:30 2.50 6,480 287 INTRM1 CEMEf~ TRIP P POOH from 6,480' to 287' -flow check well, static 02:30 03:00 0.50 287 0 INTRM1 CEMEI~ TRIP P Stand back hwdp and flex collars -laid down bit / bs /stab 03:00 03:30 0.50 0 0 INTRM1 WELCT OTHR P Pull wear bushing -set test plug 03:30 08:30 5.00 0 0 INTRM1 WELCT BOPE P Test BOPE -Annular prevetor 250/3500 psi -Pipe and blind rams , kill line, choke line, and manifold valves, Top Drive ibop and floor safety valves 250/5000 psi. AOGCC (John Cris waived witnessin tests. 08:30 09:00 0.50 0 0 INTRM1 WELCT OTHR P Pull test plug -set wear bushing 09:00 12:30 3.50 0 217 INTRMI DRILL PULD P MU BHA #5 -Bit, 5200 GeoPilot, pony flex, DM HOC, DGR-ERW, PWD, TM HOC, fs, IBS, Bat Sonic, xo -initialize tools 12:30 13:30 1.00 217 404 INTRM1 DRILL DHEQ P RIH with flex collars and hwdp - pressure test Geo-Skid to 3500 psi - shallow test tools 13:30 16:15 2.75 404 6,070 INTRM1 DRILL TRIP P RIH from 404' to 6070' -fill pipe every 20 stands 16:15 17:30 1.25 6,070 6,330 INTRM1 EVALVI~ DLOG P RIH - < 300 fph for Bat sonic log from 6070' to 6330'. 17:30 20:15 2.75 6,330 11,790 INTRM1 DRILL TRIP P RIH from 6,330' to 11,790' -fill pipe eve 20 stands 20:15 23:30 3.25 11,790 12,600 INTRM1 EVALV~ DLOG P RIH - < 300 fph for Bat sonic log from 11,790'to 12,600' MADD ass. 23:30 00:00 0.50 12,600 13,268 INTRM1 DRILL TRIP P RIH from 12,600' to 13,268'. 09/28/2006 00:00 00:30 0.50 13,268 13,314 INTRM1 DRILL CIRC P Establish circulation and wash down from 13,268' to 13,314' 200 gpm / 1850 si / 60 r m 00:30 01:15 0.75 13,314 13,345 INTRM1 CEMEI~ DRLG P Drill out cement, float shoe and clean out rathole to 13,345' 200 gpm / 1850 si/80r m ~~~'1Q of ~33 Time Logs Date From To Dur th E. De th Phase Code Subcode T M 09/28/2006 01:15 02:00 0.75 13,345 13,365 INTRM1 DRILL DDRL P Drill 20' of new hole from 13,345' to 13,365' 200 gpm / 1850 psi / 80 rpm ADT - .39 hrs TVD 7491' 02:00 03:00 1.00 13,365 13,365 INTRM1 CEMEf~ FIT P Circulate hole Gleam for PIT. 210 gpm / 1700 si / 60 r m FCP 1580 si 03:00 03:45 0.75 13,365 13,365 INTRM1 CEME~ FIT P RU and perform PIT to 12.5 ppg - RD and blow down lines 03:45 06:00 2.25 13,365 13,365 PROD1 DRILL CIRC P Mix and pump steel tube pill -chase with 80 bbls of Isnd mud -change well over to 9.5 ppg FloPro mud - 210 gpm / 2100 .psi / 80 rpm -flow check well - static 06:00 12:00 6.00 13,365 13,620 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 13,365' to 13,620" MD 7505' TVD ADT - 4.91 hrs. ECD - 10.78 ppg WOB 8/12 k RPM 150 GPM 200 @ 1840 psi String wt. PU 220 SO 150 Rot 180 Torque on/off btm. - 12,500/11,500 ft/Ibs. 12:00 00:00 12.00 13,620 14,290 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 13,620' to 14,290" MD 7542' TVD ADT - 9.84 hrs. ECD - 10.9 ppg WOB 8/12 k RPM 150 GPM 200 @ 1950 psi String wt. PU 225 SO 140 Rot 178 Torque on/off btm. - 13,000/11,000 ft/Ibs. 09/29/2006 00:00 12:00 12.00 14,290 15,200 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 14,290' to 15,200' MD 7499' TVD ADT-9.06 hrs. ECD-11.0-11.1 PP9 WOB 10/15 k RPM 150 GPM 210 @ 2140 psi String wt. PU 225 SO 135 Rot 180 Torque on/off btm. - 14,500/12,000 ft/Ibs. 12:00 00:00 12.00 15,200 15,652 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 15,200' to 16,130' MD 7491' TVD ADT - 8.22 hrs. ECD - 11.0 - 11.17 pP9 WOB 10/15 k RPM 150 GPM 210 @ 2140 psi String wt. PU 230 SO 130 Rot 175 Torque on/off btm. - 15,000/13,000 ft/Ibs. ~.. ~ P~~ 11 ctf 1~~ Time L~ .Date From To Dur th E. De th Phase Code Subcode M 09/30/2006 00:00 12:00 12.00 16,130 16,797 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 16,130' to 16,797' MD 7496' ND ADT - 9.63 hrs. ECD - 11.1 - 11.15 PP9 WOB 10/12 k RPM 150 GPM 210 @ 2290 psi String wt. PU 230 SO 127 Rot 177 Torque on/off btm. - 15,500/13,000 ft/Ibs. "'Control drilled from 16335' - 16,355' (10 fph) to drop down through hard tense 12:00 00:00 12.00 16,797 17,569 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 16,797' to 17,569' MD 7491' ND ADT - 9.2 hrs. ECD - 11.1 - 11.19 PP9 WOB 10/12 k RPM 150 GPM 210 @ 2260 psi String wt. PU 230 SO 130 Rot 175 Torque on/off btm. - 15,000/12,500 ft/Ibs. 10/01/2006 00:00 01:00 1.00 17,569 17,653 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 17,569' to 17,653' MD 7490.5' ND 01:00 02:00 1.00 17,653 17,653 PROD1 DRILL CIRC T Started losing returns -initial losses @ 120 bph -mixed and pumped 40 bbls LCM pill (20 Ibs/bbl) losses slowed to 50-70b h 02:00 08:30 6.50 17,653 17,940 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 17,653' to 17,940' MD 7491' ND ECD - 11.2 - 11.3 ppg WOB 10/12 k RPM 150 GPM 2 @ 2080 psi String wt. PU 232 SO 128 Rot 179 Torque on/off btm. - 16,500/13,500 ft/Ibs. Well breathing on connections Losses 40 - 70 b h 08:30 11:00 2.50 17,940 17,940 PROD1 DRILL CIRC T Unable to hold GeoPilot toolface - Circulate hole clean (2 x BU) - 200 gpm / 2140 psi / 80 rpm Contact Geologists -decision made to tri for new tools. 11:00 11:30 0.50 17,940 17,975 PROD1 DRILL DDRL P GeoPilot status board indicated tool had reset -Drill from 17,940' to 17,975' MD 7491' TVD Unable to controle toolface. ADT last 12 hours 5.1 hrs 11:30 12:00 0.50 17,975 17,975 PROD1 DRILL CIRC T Circ and condition mud -spotted 7 ppb Icm pill to bit -Total mud losses @ noon - 598 bbls 12:00 18:00 6.00 17,975 14,700 PROD1 DRILL TRIP T POOH - backream from 17,975' to 14,700' Pum 4 BPM 60 RPM. 18:00 19:00 1.00 14,700 14,700 PROD1 DRILL OWFF T Observed well until breathing stoped. 19:00 22:30 3.50 14,700 14,700 PROD1 DRILL CIRC T Circulated and raised MW to 10.3 PPG 4 BPM FCP 1790 si.. Page 12 ~# 13~ Time Logs r Date From To Dur th E. De th Phase Code Subcode T OM 10/01/2006 22:30 23:45 1.25 14,700 14,110 PROD1 DRILL TRIP T POOH - backream from 14,700' to 14,110' Pump @ 4 BPM 60 RPM. Hole took 65 Bbls for 5 stands. 23:45 00:00 0.25 14,110 14,110 PROD1 DRILL OWFF T Observed well and weight up mud in its. Well static in 16 Min. 10/02/2006 00:00 08:00 8.00 14,110 9,265 PROD1 DRILL TRIP T Pump out from 14,110' to 9,265' - 2 bpm / 720 psi -flow check well, static - attempted to pull without pump, well swabbin 08:00 11:30 3.50 9,265 6,945 PROD1 DRILL TRIP T Pump out from 9,265' to 6,945' - 2 b m / 575 si 11:30 12:00 0.50 6,945 6,945 PROD1 DRILL OWFF T Monitor well, static -pulled pipe 30' - observed mud in annulus dro 12:00 13:15 1.25 6,945 5,170 PROD1 DRILL TRIP T POOH with pump @ 2 BPM from 6,945' to 5,170'. 13:15 19:00 5.75 5,170 1,262 PROD1 DRILL TRIP T POOH on trip tank from 5,170' to 1,262'. 19:00 00:00 5.00 1,262 0 PROD1 DRILL PULD T Laid down HWDP, flex collars, and BHA. 2 Hours trying to download MWD. 10/03/2006 00:00 00:30 0.50 0 0 PROD1 DRILL RURD P Cleared floor and laid down Geo Span. 00:30 01:00 0.50 0 0 PROD1 RPCOh RURD P Rigged up tongs and pulled wear bushin . 01:00 13:00 12.00 0 11,794 PROD1 RPCOh RCST P PJSM and ran 4.5" completion 294 Jts 4.5" 12.6# L 80 IBTM tubin to 11,794'. 13:00 13:45 0.75 11,794 11,826 PROD1 RPCOti HOSO P Made up tubing hanger and landed tubin 11,825.63'. Installed TWC. 13:45 14:45 1.00 11,826 0 PROD1 RPCOti DHEQ P Laid down landing jt A and picked up landing jt B tested hanger to 5,000 psi. Laid down 't B. 14:45 16:30 1.75 0 0 PROD1 RPCOh NUND P Nippled down BOP and changed saver sub. 16:30 18:00 1.50 0 0 PROD1 RPCOh NUND P Nippled up X Mas Tree and tested to 5,000 si. 18:00 23:30 5.50 0 0 PROD1 RPCOti FRZP P PJSM. Pumped 35 Bbls wash pill followed by 200 Bbls 9.6 PPG Brine, 150 Bbls 9.6 PPG inhibited brine, and 223 Bbls diesel. 1200 psi on tubing. 400 si on annulus. 23:30 00:00 0.50 0 0 PROD1 RPCOCV PACK P RU and Dropped Ball/Rod. 10/04/2006 00:00 00:15 0.25 0 0 PROD1 RPCOh PACK P Test lines to 5000 psi. Pressure tbg to 4600 si to set kr. 00:15 02:00 1.75 0 0 PROD1 RPCOh DHEQ P Test tbg to 3700 psi for 30 min. Test annulus to 3500 si for 30 min. 02:00 02:30 0.50 0 0 PROD1 RPCOti RURD P Blow down lines. RD hard line, hoses and manifold. 02:30 03:30 1.00 0 0 PROD1 RPCOh OTHR P RU lubricator. Set BPV. RD lubricator. Secure well. 03:30 18:00 14.50 0 0 PROD1 DRILL PULD P PJSM and laid down 450 Jts 4" DP from derrick. 18:00 19:00 1.00 0 0 PROD1 DRILL RURD P Cleared rig floor and cleaned up pipe rack. Rig released @ 1900 Hrs. 10/4/06. Passe 13 of 13 • • 30-Oct-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-17 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.60' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 17,975.00' MD 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 Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage e, AK 99518 Date 9 ~(1' d v ~1M1 ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~d e ~ ~ L ~ U WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-17, • November 7, 2006 AK-MW-4612534 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 Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20534-00. ,~s = __~ '; .~ ~j(o -~ t (~ ~ 1 ~1 ~ - ~ FW: PPT for AOGCC • • Subject: FW: PPT far AOGCC From: "Johnson, Vern"<Vern.Johnsoa~t~i`,conocophillips.corn> Date: Tue, l7 Oct 2006 09:18:40 -0800 To: Thom~is 1~~1auf~Jcr <-tom n~aunder(~i~admin.statc.ak.us== Tom, Here are the logs I mentioned this morning. This is the basis for our evaluation that the K2fQannik is not significant and does not warrant isolation. if needed, we can set up a conference call or take a walk over to your office to discuss. Let me knew what you think. Vern -----Original Message----- From: Yeaton, Jeffrey William Sent: Tuesday, October 17, 2006 9:02 AM To: Johnson, Vern Cc: Hannon, Renee; Wiess, JORDAN F Subject: PPT for DNR «CD17_321_loganal_DNR.ppt» Vern Attached is a powerpoint showing prelim log analysis for 17 and 321. Jeff Content-Description: CD17_321_loganal_DNR.ppt CD17_321_loganal_DNR.ppt Content-Type: application/vnd.ms-powerpoint '' Content-Encoding: base64 1 of 1 10/24/2006 8:45 AM ~-,, a o~ - ~ ~g CD4-17 K-2 Log Analysis (Klein Model, real time logs) Net Oil Pay: 12.3ft Avg Por (pay): 23.5% Avg Avg CD4- 17_PRELIM CD4-321_PRELIM 3175ft ~J • ,~ i,IY` j.`~ ?`.ri ' RD 56 ' YA ' Rp 6 5 28 120 Feel -.6 `N Vp5 Rp 58 ~ -_ ~ - i _ ~ _~ t - /~ ~ ~ ~3~ r ,~ _ ' ~- r_ - ~-~~~ ~ .7 28 ~ 76 C m~ CD4-321 Preliminary Log Analysis K-2 Upper Net Oil Pa 3 9ft Y Lobe . • 0 ft Net Oil Avg POr (pay): 24.5% (cemented) Avg Perm (pay):35md K-2 Lower Avg Sw (paY):30% ,. ~; _ ~~,~ ,,,;,~__, Lobe 3.9ft Net Oil IN ITERPD_MWD_ ~ ~ ~'.~:~-.rr~~•.,;rni ' CALCS.PHI_VCL_1 f, '>lM_1 1 HgYA 0 J ~ v. v :: 6 ~ V ~ t , C L .~.GELTA F'I- I 'i;IIF RPS_tvP~trL~ INSITE.N REFER ' -- Nc'E J DEPTH CALCS.VC'LAY_1 CALCt~.PHIT_1 CALCS.PHIT_I ~ s~.ir ~ CALCS,PERM _i ,i+LC~.PMT_.1 rua~n ian so 3G :rnvrs~ro rffr uti n v IN ~ITE.GR_MWD_I SITE.RPP A_fviWD ~eSSITE,RIDIREC ONAL. G~'a 7r ~~try~.~. r ~ir~~~ ~,.I~h~~ ,r., a~n~_ot~b.hh~~.-'.u ,,x ..~ tr~~~G~;_ r~•.E~ aiYr~ ~ ~ iaLC.~~.b~ ~ ll 1 I a~~n i Top K-2 - - r_ --_ __. - 8806 ---~ -- .. .. .._.. -_ ....., i i K- sa " o` ° - --.... ~_ .. 89uu • • J J rz~ ry ~ ~ Re: Question about removal of SSSVs for Alpine wells i Subject: Re: Question about reri~oval o~SSSVs forAlpine wells From: Thomas Maunder <tom maunder@admin.state.ak.us> Date:''I~u~: 17 Oct 2006 14:24:04 -0800 To: N~i~ Problci~~ Well Sulu- ~<=r~1617(a)conocophillips.cotn== CC: jim _re~~~~~.'~aclnlin.statc.ak.us Marie, With the wells SI and secured with the wellhead valves, it is not necessary to install the SSSVs at this time. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 10/17/2006 12:05 PM: Tom & Jim, A question has come up regarding removal of SSSVs at Alpine. CD2-60 and CD4-17 had downhole gauges installed in the past few days to record shut-in bottom hole pressure for the next 4 to 6 weeks. The wells will remain SI at the wellhead during this entire time. CD4-17 doesn't have a flowline and has not been on production since the rig completed drilling operations. With the wells staying SI with wellhead valves closed while the SBHP data is gathered, it seems that it would be permissible to leave the SSSVs out until the gauges are removed. The SSSVs will be installed when slickline pulls the gauges prior to bringing the wells back on line. Please advise if we've interpreted the conservation order and regulations correctly. Thanks, Marie McConnell Problem Well Supervisor (907) 659-7224 n1617 _conocophillips.com 1 of 1 10/17/2006 2:27 FM • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska, Inc Colville River Field /Alpine /CD4 10/04/06 Hill Packer Depth Pretest Initial 15 Min. 30 Min. Well CD4-17 Type Inj. N TVD 7,130' Tubing 1,800 2,000 2,000 2,000 Interval I P.T.D. 206-118 Type test P Test psi 3500 Casing 3,550 3,525 3,525 P/F P Notes: OA 250 250 250 250 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waist G=Gas I =Industrial Waistewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT Form CD4-17.x1s STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim re ~~adn:in.stUte.a>c.u~• ~oq~"~r}_4d~oe brv oiad:-nn.stae.ul`_us bot; fleckensten:~adrr:i:~.state.a>~.us• Contractor: Doyon Rig No.: 19 DATE: 9/27/2006 Rig Rep.: Welsh / Sena Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley /Hill Field/Unit & Well No.: Colville Rv CD4-17 PTD # 206-118 Operation: Drlg: x Test: Initial: Test Pressure: Rams: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Workover: Weekly: Annular: 250/3500 Explor.: Bi-Weekly x Valves: 250/5000 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Resu P Upper Kelly 1 P P Lower Kelly 1 P P Ball Type 1 P Inside BOP 1 P Test Results CHOKE MANIFOLD: Quantity Test R No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3200 P Pressure After Closure 1550 P 200 psi Attained 35 P Full Pressure Attained 3 min 07 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 cr/D 1950 psi Number of Failures: 0 Test Time: 5 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: aim reg~~ yadn:in.state.a>~.us Remarks: Good test. Tested VBRs to 4-1/2" also. 24 HOUR NOTICE GIVEN YES X NO Date 09/25/06 est start Time 7:OOam Finish Waived By Witness John C Sena / Hitl BOP Test (for rigs) BFL 11/09/04 Doyon19 9-27-06 CD4-17.x1s Re: CD4-17 intermediate casing cement plar~ ~~ l Subject: Re: CD4-17 intermediate casing cement plan From: Winton Aubert <wnton_aubert@admin.state.ak.us> Date: Thu, 21 Sep 2006 13:56:45 -0800 To: "Johnson,!Vern" <Vern.Johnson@conocophillips.com> CC: Thomas E Maunder <tom_maunder@admin.state_ak.us> Vern, Pursuant to 20 AAC 25.030 (g), AOGCC hereby approves alternate cement placement in well CD4-17 (PTD 206-118), as described below. All other permit stipulations apply. Winton Aubert AOGCC 793-1231 Johnson, Vern wrote: Winton, As discussed yesterday afternoon, we plan to change our cement plan for the intermediate casing string on CD4-17. Logs through the K2 interval (+/- 6075' MD / 4050' TVD) indicate that it could be considered significant, and therefore require cement isolation. The original planned top of cement was 9450' MD (5896' TVD), which is 500' MD above the top of the Albian 96 (Nanuq) interval, but insufficient to cover the K2. Hydraulic modeling indicates that it is not technically feasible to place cement from the casing shoe up to 500' above the K2, due to the distance between the two points (+/- 7625' MD), so a variance under 20 AAC 25.030 (g) is necessary. Our current plan is to pump lead and tail cement to the original planned top, then open a stage tool and pump a second cement job to isolate the K2. We plan to place +/- 500' MD of cement above and below the K2 interval. This will leave a mud gap between the two stages. If you have any questions or concerns, please contact me at 265-6081. Regards, Vern Johnson Drilling Engineer 1 of 1 9/21/2006 1:56 PM Re: CD4-17 intermediate casing cement plan • Subject: Re: CD4-i7 intermediate casing cement plan From: Winton Aubert <winton_aubert@admin.state.ak.us> Date: Thu; ? 1 Sep 2006 13:56:45 -0800 To: ".lolu~son, Vern" ~--Vern.Johnsonici~conocophillips.com=~ CC: Thomas E i~1auruler ~=tom mau~~der~ii;!admin.state_aku5 Vern, Pursuant to 20 AAC 25.030 (g), AOGCC hereby approves alternate cement placement in well CD4-17 (PTD 206-118), as described below. All other permit stipulations apply. Winton Aubert AOGCC 793-1231 Johnson, Vern wrote: Winton, As discussed yesterday afternoon, we plan to change our cement plan for the intermediate casing string on CD4-17. Logs through the K2 interval (+/- 6075' MD / 4050' TVD) indicate that it could be considered significant, and therefore require cement isolation. The original planned top of cement was 9450' MD (5896' TVD), which is 500' MD above the top of the Albian 96 (Nanuq) interval, but insufficient to cover the K2. Hydraulic modeling indicates that it is not technically feasible to place cement from the casing shoe up to 500' above the K2, due to the distance between the two points (+/- 7625' MD), so a variance under 20 AAC 25.030 (g) is necessary. Our current plan is to pump lead and tail cement to the original planned top, then open a stage tool and pump a second cement job to isolate the K2. We plan to place +/- 500' MD of cement above and below the K2 interval. This will leave a mud gap between the two stages. If you have any questions or concerns, please contact me at 265-6081. Regards, Vern Johnson Drilling Engineer 1 of 1 9/25/2006 3:43 PM `~ STATE OF ALASKA 11/09!04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim regg~~adn:in_5tate.ak.~~s~ uc~cc pr~_~d~oe bn~ ofa~~n.s~tate.ak.us ~3ie~e ?~$.rkenate~#~;`1)c;IL:~'2#'3.Stu~F.ii?i.~1 Contractor: Doyon Rig No.: 19 DATE: 9/15/2006 Rig Rep.: Welsh /Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Mickey Field/Unit & Well No.: Colville Rv CD4-17 PTD # 206-118 Operation: Drlg: x Workover: Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result CHOKE MANIFO LD: Annular Preventer 1 13-5/8 P Quantity Test Result Pipe Rams 1 3-1/2x 6 P No. Valves 16 P Lower Pipe Rams 1 3-1/2x 6 P Manual Chokes 1 P Blind Rams 1 blinds P Hydraulic Chokes 1 P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P ACCUMULATOR SYSTEM: Kill Line Valves 1 3-1/8 P Time/Pressure Test Result Check Valve 0 NA System Pressure 3200 P Pressure After Closure 1550 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 33 P Trip Tank P P Full Pressure Attained 3 min 10 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 4 cLD 1900 psi Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time: 4 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at:~ ~-eg~ :yadmin.state.a>c.u~ Remarks: Good test. 24 HOUR NOTICE GIVEN YES X NO Waived By Chuck Scheve Date 09/12/06 Time 12:45pm Witness Grazulis /Mickey Test start 6:30gm9/15 Finish 10:30om915 BOP Test (for rigs) BFL 11/09/04 Doyon19 9-15-06 CD4-17-1.xls RE: CD4-17 Bond Log Subject: RE: CD4-17 Bonci Lod; From: "Galiunas, Elizab~thC" <Elizabeth.C.Galiunas(a~conocophillips.com= Date: Thu, f 0 Aug 2006 ] 2: X5:00 -OS(~~J To: ~I~1iomas 1~~1aun~~r <tori~ maunder(ci'admin.state.ak.us? Tom, A bond log will be done. We are planning on using the Sperry Drilling Services BAT Sonic tool. I apologize for this being missing. Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 -----Original Message----- From: Thomas Maunder [mailto:tom maunder;~admin.state.ak.us] Sent: Thursday, August 10, 2006 12:07 PM To: Galiunas, Elizabeth C Cc: Noel, Brian Subject: CD4-17 Bond Log Liz, I am completing my review of CD4-17. I did not see a provision for a "bond log" on the 7" casing. Since this will ultimately be an injector, a bond log will be needed. Thanks, Tom Maunder, PE AOGCC 1 of 1 8/10/2006 2:30 PM • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord WNS Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD4-17 ConocoPhillips Alaska, Inc. Permit No: 206-118 Surface Location: 2962' FNL, 380' FEL, SEC. 24, T11N, R4E Bottomhole Location: 3661' FNL, 2294' FEL, SEC. 15, Tl 1N, R4E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) ~9-3607 (pager). DATED this ~~ day of August, 2006 cc: Department of Fish Sv Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory ^ Development Oil ~ Stratigraphic Test ^ Service^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: CD4-17 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 18890' ~ TVD: 7430' ~ 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 2962' FNL, 380` FEL, Sec-24 T11 N R4E ' 7. Property Designation: 3~^^~~ ADL 380077, 3~y2Q8 Alpine Oil Pool Top of Productive Horizon: 3383' FNL, 4870° FEL Sec-23 T11 N R4E 8. Land Use Permit: ALK 380077 13. Approximate Spud Date: 811112006 Total Depth: 3661' FNL, 2294' FEL Sec-15 T11 N R4E 9. Acres in Property: 2560 14. Distance to Nearest Property: 7573 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377$64 ~ y- 5957452 • Zone- 4 10. KB Elevation (Height above GL): 55.1' RKB feet 15. Distance to Nearest Well within Pool: CD2-56L1 , 498 16. Deviated wells: Kickoff depth: 360 ft. Maximum Hole Angle: 90° deg 17. Maximum Anticipated Pressures in psig (see zo AAC 25.os5) Downhole: 3389 psig • Surface: 2640 psig 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size ons pec ca Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 96" 62.5 H-~i3 ei~~c3 77 37 37 114 114' pre-installed 12.5" ~-5t8" 4C3 L_gn STC 2976 37 37 3013 - 2400 ~ 562 sx AS Lite, 230 sx cl. G 15.8 8.75" 7" 26# L-80 BTCM 13163 37 37 13200 ~ 7490 - 696 sx Class G 6.125" 4.5" 12.6# L-80 IBT-M 11730 32 32 11762 ~ 7128 - tubing to ~ -' 'ZCiC~ 1 70t7 l~-l~ `1'\Sl~ '<<13® o E~ ~o 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ff): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Ada Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling Program^ Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 20 AAC 25.050 requirements^ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. Johnsen Printed Name C. Alvord Sy Title WNS Drilling Team Lead Signature %~ T /l ~ Phone ZGS_GCO~~ Date ~// /v .~ J v. ohn n Commission Use Only Permit to Drill Number: ~~~, ^ ~~~ API Number: 50- ~d~~ ~s3 ~ Q Permit proval Date: • b~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me hane, gas hydrates, or gas contained in shales: '~j~ ,~~ ai/.Z~~oKV~ ~~ ~S Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No Other: `k~_-~ H2S measures: Yes ^ No d Directional svy req'd: Yes [~ No ^ ~'\ \T'~ C~~d~i^~-~'` w~~a ~ ~~\ v~ta~ ~ccv.~Soc~~ `~ r c>cc "'" / ~+.\ O `~ 7~v~,~~C=rwc0.'tv~~ a0~`q'Cc~-J'~03SC1~~j~•Poc~~ ~LF ~OAAC~~',4lS~~cx> APPROVED BYTHE COMMISSION DATE: ~ ~ -~ ~ ~ COMMISSION R Form 10-401 Revised 12/2005 ~ -~~ i ~`~ i '`~ ~ ~ ~ ~~ ~ ~ s ~ ~t U ~ ~ ~ S'g`K Submit in Duplicate e~ d~&~~, • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 1, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-17 Dear Sir or Madam: • ConocoPhilli s p ~Ive~,~~ AuG o 2 zoos Alaska Oit & Gas Cons. Commission ~- Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Nanuq CD4 drilling pad. The intended spud date for this well is 08/11/2006. It is intended that Doyon Rig 19 be used to drill the well. CD4-17 will be drilled to penetrate the Alpine reservoir horizontally. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as an open hole injector. At the end of the rig work program, the well will be flowed back to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities construction that will allow the well to begin injection fourth quarter 2006. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) be granted. There have been 7 surface holes drilled at CD4 and there has not been a significant show of shallow gas or gas hydrates. It is also requested that the packer placement requirement be relaxed to place the completion packer +/- 400 ft TVD above the Alpine reservoir. 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 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. 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: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. nn~GINAL • • If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. Sin ely, g~/ a~ =~- ~-' ern Johnson Drilling Engineer Attachments cc: CD4-17 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation • • CD4-17 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casin Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G o sin le shots, travelin c finder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers O~lGINAL • ~ Fiord : CD4-17 Procedure 1. Move on Doyon 19. Dewater cellar as needed. 2. Drill 12-'/" hole to the surface casing point as per the directional plan. (Directional/MWD). 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 8-3/4" drilling BHA. 8. Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 9. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 10. BOPE test to 5000 psi. 11. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 12. Drill 6-1 /8" horizontal section to well TD (LWD Program: GR/RES/PWD). V`~C~~ , 13. Circulate the hole clean and pull out of hole. ~~`~~~~'~~~\~~ ~©~ ~-~1~~ 14. Run 4-%2, 12.6#, L-80 tubing with D nipple, gas lift mandrel, packer and tailpipe and XN profile. Land hanger, run in lock down screws. 15. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 16. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 17. Circulate tubing to diesel and install freeze protection in the annulus. 18. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 19. Set BPV and secure well. Move rig off. ^^.161NAL • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD4-318 is the closest well. Center to center well separation is 33.5' @ 1150' MD. Anti-collision scans show the ellipse to ellipse separation to be 36.1' at 1150' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. 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. Drilling Fluid Program SPUD to 9-5/8"surface casing oint -12'/" Intermediate hole to 7" casing point - 8 3/" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-g.3 ppg PV 10 - 25 10 -15 YP 20-60 15-25 25-30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 -15 10 minute gels <18 12 - 20 API Filtrate NC -10 cc / 30 min 4 -12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 1 0.0 9.0 - 9.5 KCL 6 Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a M-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. ~~IGINAL • • Nanuq (CD4) Colville River Field CD4-17 Alpine A Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812') at 2000' TVD = 2278' MD 9-5/8" 40 ppf L-80 BTC Surface Casing @ 3013' MD / 2400' ND cemented to surface 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Com lei Updated 07/27/06 Sperry Sun Directional Plan WP02 Packer Fluid mix: 9.2 pga KCI Brine with 1600' ND diesel cao Tubing_su5pended with diesel Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB nipple 4-1/2", 12.6#!ft, IBT-Mod Tubing Camco KBG2-GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) Baker Premier Packer 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725")-64.2° inc 4-1/2", 12.6#/ft, IBT-Mod 10' pup joint WEG TOC @ +/- 9449' MD / 6472' ND (500' MD above top Albian 96) Top Nanuq (Albian 96) 9949' MD / 5896' NC Top Kuparuk at 11807' M Camco KBG-2 GLM (3.909" DRIFT ID) w/ dummy Baker Premier Packer +/-11690' MD/ 7095' ND < 400' ND from top of Alpine A Top Alpine A at 13055' MD / 7484' ND 7" 26 ppf L-80 BTC Mod Production Casing @ 13200' / 7490' TVD @+/- 88.9° ORIGINAL MD ND 32' 32' 2278' 2000' 11600' 7053' 11690' 7095' 11750' 7123' 11762' 7128' Well TD at 18890' MD / - 7430' ND • CD4-17 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) • The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 3013 / 2400 14.5 1087 1571 7" 13200 / 7490 16.0 3389 ~ 2640 N/A 18890 / 7430 16.0 3362 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1087 - (0.1 x 2400') = 847 psi Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1 ] x 2400 = 1571 psi OR ASP =FPP - (0.1 x D) = 3389 - (0.1 x 7490) = 2640 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3362 - (0.1 x 7430') = 2619 psi ~21GINAL • • Cementing Program: 9 5/8" Surface Casing run to 3013' MD / 2400' TVD. Cement from 3013' MD to 2513' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2513' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1700 MD). Lead slurry: (2513'-1700') X 0.3132 ft3/ft X 1.5 (50% excess) = 385.8 ft3 below permafrost 1700' X 0.3132 ft3/ft X 4 (300% excess) = 2129.8 ft3 above permafrost Total volume = 385.8 + 2129.8 = 2514.6 ft3 => 562 Sx @ 4.48 ft3/sk System: 562 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOW' D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate CasinE run to 13200' MD / 7490' TVD ~ ,~ Cement from 13200' MD to +/-9449' MD (minimum 500' MD above top of Nanuq reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (13200' - 9449') X 0.1503 ft3/ft X 1.4 (40% excess) = 789.3 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 789.3 + 17.2 = 806.5 ft3 => 696 Sx @ 1.16 ft3/sk System: 696 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk NOTE: Modeling may indicate the need for a lighter weight system for the 7" casing to prevent breaking down the Alpine. A "LiteCrete" 11 ppg cement slurry maybe used instead of the system above if it appears that equivalent circulating density will be too high. ' By Weight Of mix Water, all other additives are BWOCement 0 ~~ Iz D r WELL DETAILS Name +N/-S +E-W Northing Fasting Latitude Longitude Slot Plan: CD4-l7 -79.49 -309.85 5957451.65 377863.63 70°1T32.184N 150°59'19.793W N/A WELLPATH DETAILS Plan: CD4-17 Rig: Doyon 19 Ref. Datum: Plan: CD4-17 SS.SOft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 290.21° 0.00 0.00 36.30 T M Azimuths to True North Magnetic North: 23.27° Magnetic Field Strength:57501nT Dip Angle: 80.63° Date: 7/20/2006 Model: bggm2005 SURVEY PROGRAM Depth Fm Depth To Survey/Plan 36.30 1000.00 Planned: CD4-17wp02 V5 1000.00 18890.13 Planned: CD4-17wp02 V5 Ktck off Dint 2" U1.S, 235" 7 Be,in Dir 3° DLS 27° TFO p9 ' ~ l0° Start SaiP 57.1° INC 23: 1gP 'p~ ~ 9 5/8" cs - 12 1 /4" hoh ' 9 5/8" Cs Pr, 3013' r ~ ~~. yn Tool CB-GYRO-SS MWD+IFR-AK-CAZ-SC ~ 7" cs - 8 i i i~ 7 Cs 13 ~ ~~ ~ bo n° o 6000 9000 Vee6cal Sa4°n az 29031° 13oooNiul CD4-17 2 6 1/8" O Hol e Tar et Toe 18 890' MD 7430' TVD ~~ SHL~ 2962' FNL 380' FEL Sec-24 T-11 N R-04E Kick ofT oink 2° DLS, 235° TFO, 360' MD 360' TV ~ 2 Be in Dir 3° DLS 27° TFO 520' MD 520' T VD ~ '~ ~ T ar et HeeP 13288' MD 7490' TVD 7" cs - 8 3/4" hole ~ ~ ~ ' Stag Sail; 57.1° INC 2328' MD, 2028' T VD ~~ a ~~ -12 9 -6 _-? --- 300O,r~2000 -.- 0 ~ \ 4000 ,, \ .---- -_ ~ 7000_--- 6000-I 5000 Cont Dir 3.5° DLS 78° TFO 11178' MD 6835' TVD 9 5/8" Cs Pt; 3013' MD 2400' TVD _000 9 5/8" u - 12 I/4" hole 7 Cs 13200' MD 3383' FNL, 4870' FEL S23 Tl t N R4 w u-lam +t*t ROmw~l PLAN DETAILS CD4-17wp02 Alpine tazgets Version 5 6835' TVD 7/20/2006 Start Point MD Inc Azi TVD +N/-S +E/-W FNL, 4870' FEL S23 Tl I R4 6.30 0.00 0.00 36.30 0.00 0.00 ConocoPhillips -~ Alaska REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: Plan: CD4-17, Ttue North ~- r Vertical (TVD) Reference: Plan: CD4-17 55.80 T 15000 Section (VS)Reference: Slot- (O.OON,O.OOE) Measured Depth Reference: Plan: CD4-17 55.80 Calculation Method: Minimum Curvature • 7/20/2006 11:42 AM • • Sperry Drilling Services CPAI Plan Report Company: ConocoPhiliips Alaska Inc. Date: 7/20!2006 Time: 11:29:43 Page: 1 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD4-17, True North Site: Alpine CD4. Vertical (TVD} Reference: Plan: CD4-17 55.8 .Welt: Plan: CD4-1'7 Section (VS) Reference: Weil (O.OON,O.OOE,290.21Azi) Wellpath: Plan: CD4-17 Survey Calcalatioa Method: Minimum Curvature Db: Oracle Plan: CD4-17wp02 Date Composed: 7/20/2006 Alpine targets Version: 5 Principal: Yes Tied-to: From Well Ref. Point Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2005 Site: Alpine CD4 Site Position: Northing: 5957526.10 ft Latitude: 70 17 32.966 N From: Map Fasting: 378174.70 ft Longitude: 150 59 10.763 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.93 deg Well: Plan: CD4-17 Slot Name: Alpine CD4 Well Position: +N/-S -79.49 ft Northing: 5957451.65 ft Latitude: 70 17 32.184 N +E/-W -309.85 ft Fasting : 377863.63 ft Longitude: 150 59 19.793 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD4-17 Drilled From: Well Ref. Point Tie-on Depth: 36.30 ft Current Datum: Plan: CD4-17 Height 55.80 ft Above System Datum: Mean Sea Level Magnetic Data: 7/20/2006 Declination: 23.27 deg Field Strength: 57501 nT Mag Dip Angle: 80.63 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 290.21 Survey Program for Defmitive Wellpath Date: 7/13/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information MD - Inc1-' Azim TVD . +1'~l-S +E1-W DLS Build Turn TFO Target ft deg deg ft ft ft degN00ft deg/100ft deg/100ft deg 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 360.00 0.00 0.00 360.00 0.00 0.00 0.00 0.00 0.00 0.00 520.00 3.20 235.00 519.92 -2.56 -3.66 2.00 2.00 0.00 235.00 2328.12 57.10 261.41 2028.03 -156.53 -860.51 3.00 2.98 1.46 27.40 11178.62 57.10 261.41 6835.71 -1266.15 -8208.04 0.00 0.00 0.00 0.00 13288.61 90.61 331.64 7490.80 -337.86 -9813.65 3.50 1.59 3.33 78.43 CD4-17wp01 Heel 18890.13 90.61 331.64 7430.80 4591.18 -12474.10 0.00 0.00 0.00 0.00 CD4-17wp01 Toe ~''?!GINAL Sperry Drilling Services CPAI Plan Report Company: GonocoPhillips Alaska Inc. Dste: 7!2012006 Time: 11:29:43 Page: 2 Field: Colville River Unit ~o-ordinate(NE) Reference: Well: Plan: CD4-17, True North Site: Alpine CD4 Vertical (TVD) Reference: Plan' CD4-1755.8 Well: Plan: CD4-17 Section (VS) Reference: Well (O.OON,O.OOE,29021Azi) Wellpath: Plan: CD4-17 SnrveyGalcalat;onMethod: Minimum Curvature Db: Oracle Survey Ml) tt 36.30 100.00 200.00 300.00 360.00 400.00 500.00 520.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2328.12 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3012.89 3029.09 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3706.54 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 Inc! Azim TVD Sys TVD N/S E/W deg deg ft ft ft ft 0.00 0.00 36.30 -19.50 0.00 0.00 0.00 0.00 100.00 44.20 0.00 0.00 0.00 0.00 200.00 144.20 0.00 0.00 0.00 0.00 300.00 244.20 0.00 0.00 0.00 0.00 360.00 304.20 0.00 0.00 0.80 235.00 400.00 344.20 -0.16 -0.23 2.80 235.00 499.94 444.14 -1.96 -2.80 3.20 235.00 519.92 464.12 -2.56 -3.66 5.44 246.72 599.69 543.89 -5.34 -8.97 8.37 252.31 698.95 643.15 -9.43 -20.27 11.34 255.00 797.46 741.66 -14.19 -36.70 14.32 256.59 894.96 839.16 -19.60 -58.23 17.30 257.63 991.17 935.37 -25.66 -84.78 20.29 258.38 1085.82 1030.02 -32.34 -116.30 23.29 258.94 1178.67 1122.87 -39.62 -152.70 26.28 259.38 1269.45 1213.65 -47.49 -193.86 29.28 259.74 1357.91 1302.11 -55.93 -239.69 32.27 260.03 1443.82 1388.02 -64.91 -290.05 35.27 260.28 1526.94 1471.14 -74.41 -344.82 38.27 260.50 1607.04 1551.24 -84.39 -403.83 41.26 260.69 1683.90 1628.10 -94.84 -466.92 44.26 260.85 1757.31 1701.51 -105.73 -533.93 47.26 261.00 1827.07 1771.27 -117.02 -604.67 50.26 261.14 1892.98 1837.18 -128.69 -678.95 53.26 261.27 1954.88 1899.08 -140.70 -756.55 56.25 261.38 2012.58 1956.78 -153.01 -837.28 57.10 261.41 2028.03 1972.23 -156.53 -860.51 57.10 261.41 2067.07 2011.27 -165.54 -920.18 57.10 261.41 2121.39 2065.59 -178.08 -1003.20 57.10 261.41 2175.71 2119.91 -190.62 -1086.22 57.10 261.41 2230.03 2174.23 -203.15 -1169.24 57.10 261.41 2284.36 2228.56 -215.69 -1252.26 57.10 261.41 2338.68 2282.88 -228.23 -1335.27 57.10 261.41 2393.00 2337.20 -240.77 -1418.29 57.10 261.41 2400.00 2344.20 -242.38 -1428.99 57.10 261.41 2408.80 2353.00 -244.41 -1442.44 57.10 261.41 2447.32 2391.52 -253.30 -1501.31 57.10 261.41 2501.64 2445.84 -265.84 -1584.33 57.10 261.41 2555.96 2500.16 -278.38 -1667.35 57.10 261.41 2610.28 2554.48 -290.91 -1750.37 57.10 261.41 2664.60 2608.80 -303.45 -1833.38 57.10 261.41 2718.92 2663.12 -315.99 -1916.40 57.10 261.41 2773.24 2717.44 -328.53 -1999.42 57.10 261.41 2776.80 2721.00 -329.35 -2004.85 57.10 261.41 2827.57 2771.77 -341.06 -2082.44 57.10 261.41 2881.89 2826.09 -353.60 -2165.46 57.10 261.41 2936.21 2880.41 -366.14 -2248.48 57.10 261.41 2990.53 2934.73 -378.68 -2331.49 57.10 261.41 3044.85 2989.05 -391.21 -2414.51 57.10 261.41 3099.17 3043.37 -403.75 -2497.53 57.10 261.41 3153.49 3097.69 -416.29 -2580.55 57.10 261.41 3207.81 3152.01 -428.83 -2663.57 57.10 261.41 3262.13 3206.33 -441.36 -2746.59 MapN MapE DLS VS Comma ft 13 deg/100ft ft , 5957451.65 377863.63 0.00 0.00 SHL; 2962' FNL, 5957451.65 377863.63 0.00 0.00 5957451.65 377863.63 0.00 0.00 5957451.65 377863.63 0.00 0.00 5957451.65 377863.63 0.00 0.00 Kick off point; 2° 5957451.49 377863.40 2.00 0.16 5957449.73 377860.80 2.00 1.95 5957449.15 377859.93 2.00 2.55 Begin Dir; 3° DL; 5957446.45 377854.57 3.00 6.58 5957442.55 377843.21 3.00 15.76 5957438.06 377826.71 3.00 29.54 5957433.00 377805.10 3.00 47.87 5957427.38 377778.45 3.00 70.70 5957421.21 377746.83 3.00 97.97 5957414.52 377710.32 3.00 129.61 5957407.32 377669.04 3.00 165.52 5957399.63 377623.08 3.00 205.61 5957391.47 377572.58 3.00 249.77 5957382.86 377517.68 3.00 297.88 5957373.84 377458.52 3.00 349.81 5957364.41 377395.27 3.00 405.41 5957354.62 377328.09 3.00 464.53 5957344.48 377257.19 3.00 527.02 5957334.02 377182.74 3.00 592.69 5957323.27 377104.96 3.00 661.37 5957312.27 377024.05 3.00 732.87 5957309.13 377000.76 3.00 753.46 Start Sail; 57.1 ° 5957301.09 376940.96 0.00 806.34 5957289.91 376857.75 0.00 879.92 5957278.72 376774.55 0.00 953.49 5957267.54 376691.34 0.00 1027.07 5957256.35 376608.14 0.00 1100.64 5957245.16 376524.94 0.00 1174.22 5957233.98 376441.73 0.00 1247.80 5957232.54 376431.01 0.00 1257.28 9 5/8" csg - 12 1. 5957230.72 376417.53 0.00 1269.20 C-30 5957222.79 376358.53 0.00 1321.37 5957211.61 376275.32 0.00 1394.95 5957200.42 376192.12 0.00 1468.52 5957189.23 376108.91 0.00 1542.10 5957178.05 376025.71 0.00 1615.68 5957166.86 375942.51 0.00 1689.25 5957155.68 375859.30 0.00 1762.83 5957154.94 375853.86 0.00 1767.64 C-20 5957144.49 375776.10 0.00 1836.40 5957133.30 375692.89 0.00 1909.98 5957122.12 375609.69 0.00 1983.56 5957110.93 375526.49 0.00 2057.13 5957099.75 375443.28 0.00 2130.71 5957088.56 375360.08 0.00 2204.28 5957077.37 375276.87 0.00 2277.86 5957066.19 375193.67 0.00 2351.44 5957055.00 375110.46 0.00 2425.01 ~~4rL Sperry Drilling Services CPAI Plan Report Company: ConocoPhiRips Alaska Inc. Date: 7/20/2006 Time: 11:29:43 Page: 3 Field: 'Colville River Un it Caordinate(NE) Referenc e: Well: Pfan: CD4- 17, True North Site: A{pirte CD4 Vertical (TVD) Reference: P lan: CD4-17 55. 8 Well: Plan: CD4-1 7 Section (VS)12eference: Well ( O.OON,O.OO E,290 .21 Azi) Wellpath: Plan: CD4-1 7 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl -Azim TVD Sys TVD N/S E/~V Mapi~i MapE DLS VS Comm t ft deg deg ft ft ft ft _ ft ft deg/100ft ft 4700. 00 57.10 261 .41 3316 .46 3260. 66 -453 .90 -2829 .60 5957043. 82 375027. 26 0.00 2498 .59 4800. 00 57.10 261 .41 3370 .78 3314. 98 -466 .44 -2912 .62 5957032. 63 374944. 06 0.00 2572 .16 4900. 00 57.10 261 .41 3425 .10 3369. 30 -478 .98 -2995. 64 5957021. 44 374860. 85 0.00 2645 .74 5000. 00 57.10 261 .41 3479 .42 3423. 62 -491 .51 -3078 .66 5957010. 26 374777. 65 0.00 2719 .32 5100. 00 57.10 261 .41 3533 .74 3477. 94 -504 .05 -3161 .68 5956999. 07 374694. 44 0.00 2792 .89 5200. 00 57.10 261 .41 3588 .06 3532. 26 -516 .59 -3244 .70 5956987. 89 374611. 24 0.00 2866 .47 5300. 00 57.10 261 .41 3642 .38 3586. 58 -529 .13 -3327 .71 5956976. 70 374528. 04 0.00 2940 .04 5400. 00 57.10 261 .41 3696 .70 3640. 90 -541 .66 -3410 .73 5956965. 51 374444. 83 0.00 3013 .62 5500. 00 57.10 261 .41 3751 .02 3695. 22 -554 .20 -3493 .75 5956954. 33 374361. 63 0.00 3087 .19 5600. 00 57.10 261 .41 3805 .34 3749. 54 -566 .74 -3576 .77 5956943. 14 374278. 42 0.00 3160 .77 5678. 16 57.10 261 .41 3847 .80 3792. 00 -576 .54 -3641 .65 5956934. 40 374213. 39 0.00 3218 .28 K-3 Marker 5700. 00 57.10 261 .41 3859 .67 3803. 87 -579 .27 -3659 .79 5956931. 96 374195. 22 0.00 3234 .35 5800. 00 57.10 261 .41 3913 .99 3858. 19 -591 .81 -3742 .81 5956920. 77 374112. 02 0.00 3307 .92 5900. 00 57.10 261 .41 3968 .31 3912. 51 -604 .35 -3825 .82 5956909. 58 374028. 81 0.00 3381 .50 6000. 00 57.10 261 .41 4022 .63 3966. 83 -616 .89 -3908 .84 5956898. 40 373945. 61 0.00 3455 .07 6086. 84 57.10 261 .41 4069 .80 4014. 00 -627 .77 -3980 .93 5956888. 68 373873. 35 0.00 3518 .97 K-3 Basal 6100. 00 57.10 261 .41 4076 .95 4021. 15 -629 .42 -3991 .86 5956887. 21 373862. 40 0.00 3528 .65 6151. 27 57.10 261 .41 4104 .80 4049. 00 -635 .85 -4034 .42 5956881. 48 373819. 74 0.00 3566 .37 K-2 Marker 6200. 00 57.10 261 .41 4131 .27 4075. 47 -641 .96 -4074 .88 5956876. 03 373779. 20 0.00 3602 .23 6300. 00 57.10 261 .41 4185 .59 4129. 79 -654 .50 -4157 .90 5956864. 84 373695. 99 0.00 3675 .80 6335. 36 57.10 261 .41 4204 .80 4149. 00 -658 .93 -4187 .25 5956860. 88 373666. 57 0.00 3701 .82 K-2 Basal 6400. 00 57.10 261 .41 4239 .91 4184. 11 -667 .04 -4240 .92 5956853. 65 373612. 79 0.00 3749 .38 6500. 00 57.10 261 .41 4294 .23 4238. 43 -679 .57 -4323 .93 5956842. 47 373529. 59 0.00 3822 .95 6600. 00 57.10 261 .41 4348 .55 4292. 75 -692 .11 -4406 .95 5956831. 28 373446. 38 0.00 3896 .53 6700. 00 57.10 261 .41 4402 .88 4347. 08 -704 .65 -4489. 97 5956820. 10 373363. 18 0.00 3970 .11 6800. 00 57.10 261 .41 4457 .20 4401. 40 -717 .19 -4572 .99 5956808. 91 373279. 97 0.00 4043 .68 6900. 00 57.10 261 .41 4511 .52 4455. 72 -729 .72 -4656 .01 5956797. 72 373196. 77 0.00 4117 .26 7000. 00 57.10 261 .41 4565 .84 4510. 04 -742 .26 -4739 .02 5956786. 54 373113. 57 0.00 4190 .83 7100. 00 57.10 261 .41 4620 .16 4564. 36 -754 .80 -4822 .04 5956775. 35 373030. 36 0.00 4264 .41 7200. 00 57.10 261 .41 4674 .48 4618. 68 -767 .34 -4905 .06 5956764. 17 372947. 16 0.00 4337 .99 7300. 00 57.10 261 .41 4728 .80 4673. 00 -779 .87 -4988 .08 5956752. 98 372863. 95 0.00 4411 .56 7400. 00 57.10 261 .41 4783 .12 4727. 32 -792 .41 -5071 .10 5956741. 79 372780. 75 0.00 4485 .14 7500. 00 57.10 261 .41 4837 .44 4781. 64 -804 .95 -5154 .12 5956730. 61 372697. 54 0.00 4558 .71 7600. 00 57.10 261 .41 4891 .76 4835 .96 -817 .48 -5237 .13 5956719. 42 372614 .34 0.00 4632 .29 7700. 00 57.10 261 .41 4946 .09 4890 .29 -830 .02 -5320 .15 5956708. 24 372531 .14 0.00 4705 .86 7800. 00 57.10 261 .41 5000 .41 4944 .61 -842 .56 -5403 .17 5956697. 05 372447 .93 0.00 4779 .44 7900. 00 57.10 261 .41 5054 .73 4998. 93 -855 .10 -5486 .19 5956685. 86 372364 .73 0.00 4853 .02 8000. 00 57.10 261 .41 5109 .05 5053 .25 -867 .63 -5569 .21 5956674. 68 372281 .52 0.00 4926 .59 8100. 00 57.10 261 .41 5163 .37 5107 .57 -880 .17 -5652 .23 5956663. 49 372198. 32 0.00 5000 .17 8200. 00 57.10 261 .41 5217 .69 5161. 89 -892 .71 -5735 .24 5956652. 31 372115. 12 0.00 5073 .74 8300. 00 57.10 261 .41 5272 .01 5216. 21 -905 .25 -5818 .26 5956641. 12 372031. 91 0.00 5147 .32 8400. 00 57.10 261 .41 5326 .33 5270. 53 -917 .78 -5901 .28 5956629. 93 371948. 71 0.00 5220 .90 8500. 00 57.10 261 .41 5380 .65 5324. 85 -930 .32 -5984 .30 5956618. 75 371865. 50 0.00 5294 .47 8600. 00 57.10 261 .41 5434 .97 5379. 17 -942 .86 -6067 .32 5956607. 56 371782. 30 0.00 5368 .05 8700. 00 57.10 261 .41 5489 .30 5433. 50 -955 .40 -6150 .34 5956596. 38 371699. 10 0.00 5441 .62 8800. 00 57.10 261 .41 5543 .62 5487. 82 -967 .93 -6233 .35 5956585. 19 371615. 89 0.00 5515 .20 8900. 00 57.10 261 .41 5597 .94 5542. 14 -980 .47 -6316 .37 5956574. 00 371532. 69 0.00 5588 .78 9000. 00 57.10 261 .41 5652 .26 5596. 46 -993 .01 -6399 .39 5956562. 82 371449. 48 0.00 5662 .35 9100. 00 57.10 261 .41 5706 .58 5650. 78 -1005 .55 -6482 .41 5956551. 63 371366. 28 0.00 5735 .93 9186. 93 57.10 261 .41 5753 .80 5698. 00 -1016 .44 -6554 .58 5956541. 91 371293. 95 0.00 5799 .89 Albian 97 9200. 00 57.10 261 .41 5760 .90 5705. 10 -1018 .08 -6565 .43 5956540. 45 371283. 07 0.00 5809 .50 9300. 00 57.10 261 .41 5815 .22 5759. 42 -1030 .62 -6648 .45 5956529. 26 371199. 87 0.00 5883 .08 ORIGINAL Sperry Drilling Services CPAI Plan Report Company: ` ConocoPhillips Alaska Ina Date: 7/20!2006 'rime: 11:29:43 Page: 4 Field: Colville River Un it Co-ordinate(NE) Re ferenc e: Well: PIarY. CD4-17, Tr ue North Site: Alpine CD4 Vertical (TVD) Refe rence: Pl an: GD4-17 55. 8 Well: Plan; GD4-1 7 Section (VS) Reference:. Well (O.OON,O.OOE,290.21Azi) Wellpath: Klan: GD4-1 7 Survey Calculation Method: M inimum Curvature Db: -.Oracle Survey MD Inc! Azim TVD Sys TVD N/S E/W MapN MapE bLS' VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 9400. 00 57.10 261 .41 5869. 54 5813. 74 -1043 .16 -6731 .46 5956518. 08 371116. 67 0.00 5956 .66 9500. 00 57.10 261 .41 5923. 86 5868. 06 -1055 .70 -6814. 48 5956506. 89 371033. 46 0.00 6030 .23 9600. 00 57.10 261 .41 5978. 19 5922. 39 -1068 .23 -6897. 50 5956495. 70 370950. 26 0.00 6103 .81 9700. 00 57.10 261 .41 6032. 51 5976. 71 -1080 .77 -6980. 52 5956484. 52 370867. 05 0.00 6177 .38 9800. 00 57.10 261 .41 6086. 83 6031. 03 -1093 .31 -7063. 54 5956473. 33 370783. 85 0.00 6250 .96 9900. 00 57.10 261 .41 6141. 15 6085. 35 -1105 .84 -7146 .56 5956462. 15 370700. 65 0.00 6324 .54 9949. 06 57.10 261 .41 6167. 80 6112. 00 -1112 .00 -7187 .29 5956456. 66 370659. 82 0.00 6360 .63 Albian 96 10000. 00 57.10 261 .41 6195 .47 6139. 67 -1118 .38 -7229 .57 5956450. 96 370617. 44 0.00 6398 .11 10100. 00 57.10 261 .41 6249 .79 6193. 99 -1130 .92 -7312 .59 5956439. 77 370534. 24 0.00 6471 .69 10200. 00 57.10 261 .41 6304 .11 6248. 31 -1143 .46 -7395 .61 5956428. 59 370451. 03 0.00 6545 .26 10300. 00 57.10 261 .41 6358 .43 6302. 63 -1155 .99 -7478 .63 5956417. 40 370367. 83 0.00 6618 .84 10400. 00 57.10 261 .41 6412 .75 6356. 95 -1168 .53 -7561 .65 5956406. 22 370284. 62 0.00 6692 .41 10500. 00 57.10 261 .41 6467 .07 6411. 27 -1181 .07 -7644 .67 5956395. 03 370201. 42 0.00 6765 .99 10600. 00 57.10 261 .41 6521 .40 6465. 60 -1193 .61 -7727 .68 5956383. 84 370118. 22 0.00 6839 .57 10700. 00 57.10 261 .41 6575 .72 6519. 92 -1206 .14 -7810 .70 5956372. 66 370035. 01 0.00 6913 .14 10800. 00 57.10 261 .41 6630 .04 6574. 24 -1218 .68 -7893 .72 5956361. 47 369951. 81 0.00 6986 .72 10900. 00 57.10 261 .41 6684 .36 6628. 56 -1231 .22 -7976 .74 5956350. 29 369868. 60 0.00 7060 .29 11000. 00 57.10 261 .41 6738 .68 6682. 88 -1243 .76 -8059 .76 5956339. 10 369785. 40 0.00 7133 .87 11100. 00 57.10 261 .41 6793 .00 6737. 20 -1256 .29 -8142 .78 5956327. 91 369702. 20 0.00 7207 .45 11178. 62 57.10 261 .41 6835 .71 6779. 91 -1266 .15 -8208 .04 5956319. 12 369636. 78 0.00 7265 .29 Cont Dir; 3.5° DL 11180. 63 57.11 261 .49 6836 .80 6781. 00 -1266 .40 -8209 .72 5956318. 90 369635. 11 3.50 7266 .77 HRZ 11200. 00 57.25 262 .28 6847 .30 6791. 50 -1268 .70 -8225 .83 5956316. 86 369618. 96 3.50 7281 .10 11300. 00 58.05 266 .32 6900 .82 6845. 02 -1277 .07 -8309 .86 5956309. 86 369534. 81 3.50 7357 .07 11400. 00 58.97 270 .28 6953 .08 6897. 28 -1279 .59 -8395 .07 5956308. 72 369449. 58 3.50 7436 .16 11500. 00 60.01 274 .16 7003 .87 6948. 07 -1276 .24 -8481 .13 5956313. 47 369363. 59 3.50 7518 .08 11600. 00 61.16 277 .95 7053 .00 6997. 20 -1267 .03 -8567 .72 5956324. 08 369277. 17 3.50 7602 .52 11620. 39 61.40 278 .72 7062 .80 7007. 00 -1264 .44 -8585 .41 5956326. 96 369259. 52 3.50 7620 .02 Base HRZ 11700. 00 62.41 281 .66 7100 .29 7044. 49 -1252 .01 -8654 .52 5956340. 51 369190. 63 3.50 7689 .17 11707. 58 62.51 281 .94 7103 .80 7048 .00 -1250 .63 -8661 .10 5956341. 99 369184. 07 3.50 7695 .82 K-1 Marker 11800. 00 63.76 285 .28 7145 .57 7089. 77 -1231 .22 -8741 .21 5956362. 70 369104. 30 3.50 7777 .70 11807. 32 63.86 285 .55 7148 .80 7093. 00 -1229 .48 -8747 .54 5956364. 55 369098. 00 3.50 7784 .24 Kuparuk Fm 11886. 07 64.99 288 .33 7182 .80 7127. 00 -1208 .77 -8815 .49 5956386. 35 369030. 40 3.50 7855 .16 LCU /Miluveach 11900. 00 65.20 288 .82 7188 .66 7132. 86 -1204 .75 -8827 .46 5956390. 57 369018. 50 3.50 7867 .78 12000. 00 66.72 292 .27 7229 .41 7173. 61 -1172 .69 -8912 .95 5956424. 01 368933. 55 3.50 7959 .09 12100. 00 68.31 295 .64 7267 .66 7211. 86 -1135 .16 -8997 .36 5956462. 90 368849. 76 3.50 8051 .27 12200. 00 69.97 298 .94 7303 .27 7247. 47 -1092 .31 -9080 .38 5956507. 10 368767. 45 3.50 8143 .98 12300. 00 71.69 302 .17 7336 .11 7280. 31 -1044 .28 -9161 .70 5956556. 43 368686. 94 3.50 8236 .88 12400. 00 73.47 305 .33 7366 .05 7310. 25 -991 .27 -9241 .01 5956610. 72 368608. 50 3.50 8329 .62 12500. 00 75.29 308 .44 7392 .98 7337. 18 -933 .47 -9318 .02 5956669. 76 368532. 45 3.50 8421 .86 12543. 76 76.10 309 .78 7403 .80 7348. 00 -906 .72 -9350 .92 5956697. 04 368499. 99 3.50 8461 .98 Miluveach A 12600. 00 77.15 311 .49 7416 .81 7361 .01 -871 .09 -9392 .44 5956733. 33 368459. 06 3.50 8513 .24 12622. 80 77.58 312 .18 7421 .80 7366 .00 -856 .25 -9409 .02 5956748. 44 368442. 72 3.50 8533 .93 Alpine D 12700. 00 79.04 314 .50 7437 .44 7381 .64 -804 .38 -9463 .99 5956801. 20 368388. 60 3.50 8603 .44 12800. 00 80.97 317 .46 7454 .80 7399 .00 -733 .56 -9532 .41 5956873. 11 368321. 35 3.50 8692 .11 12846. 95 81.88 318 .85 7461 .80 7406 .00 -698 .98 -9563 .38 5956908. 19 368290. 95 3.50 8733 .12 UJU 12900. 00 82.92 320 .40 7468 .82 7413 .02 -658 .92 -9597 .44 5956948. 79 368257 .55 3.50 8778 .92 13000. 00 84.88 323 .31 7479 .45 7423 .65 -580 .73 -9658 .84 5957027. 96 368197 .43 3.50 8863 .55 13054. 55 85.96 324 .89 7483 .80 7428 .00 -536 .68 -9690 .72 5957072. 52 368166 .27 3.50 8908 .69 Alpine A 13100. 00 86.86 326 .21 7486 .64 7430 .84 -499 .28 -9716 .38 5957110. 33 368141 .23 3.50 8945 .69 13200. 00 88.85 329 .09 7490 .39 7434. 59 -414 .87 -9769 .84 5957195. 59 368089 .15 3.50 9025 .02 7" csg - 8 3/4" ho 13288. 61 90.61 331 .64 7490 .80 7435 .00 -337 .86 -9813 .65 5957273. 30 368046. 60 3.50 9092 .74 CD4-17wp01 He I 13300. 00 90.61 331 .64 7490 .68 7434 .88 -327 .84 -9819 .06 5957283. 40 368041. 36 0.00 9101 .27 13400. 00 90.61 331 .64 7489 .61 7433 .81 -239 .84 -9866 .56 5957372. 15 367995. 30 0.00 9176 .24 nr~!GINAL M • Sperry Drilling Services CPAI Plan Report Company: GonocoPhil(ipsAlaska Inc: - Date: 7/20/2006 Time: 11:29:43 Page._ 5 Field: Colville River Un it Co-ordinate(NE) Re fereuc e: We11: Plan: CD4-17, True North - Site: Al pine CD4 Vertical (TVD) Refe reuce: Plan: CD4-17 55.8. Well: Plan: C D4-1 7 Section (VS) Reference: Well (O.OON,O .OOE,290 .21Az) Wellpath: Plan: GD4-1 7 Survey Calculation Method: Minimum Curvature Dbd Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comore t ft deg_ deg ft ft ft ft ft ft deg/100ft ft 13500. 00 90. 61 331 .64 7488 .54 7432. 74 -151 .85 -9914.05 5957460. 90 367949. 24 0.00 9251 .21 13600. 00 90. 61 331 .64 7487 .46 7431. 66 -63 .85 -9961.55 5957549. 64 367903. 19 0.00 9326 .18 13700. 00 90. 61 331 .64 7486 .39 7430. 59 24 .14 -1.Oe04 5957638. 39 367857. 13 0.00 9401 .15 13800. 00 90. 61 331 .64 7485 .32 7429. 52 112 .14 -1.Oe04 5957727. 14 367811. 08 0.00 9476 .12 13900. 00 90. 61 331 .64 7484 .25 7428. 45 200 .13 -1.Oe04 5957815. 89 367765. 02 0.00 9551 .09 14000. 00 90. 61 331 .64 7483 .18 7427. 38 288 .13 -1.Oe04 5957904. 63 367718. 97 0.00 9626 .06 14100. 00 90. 61 331 .64 7482 .11 7426. 31 376 .12 -1.Oe04 5957993. 38 367672. 91 0.00 9701 .03 14200. 00 90. 61 331 .64 7481 .04 7425. 24 464 .12 -1.Oe04 5958082. 13 367626. 86 0.00 9776 .00 14300. 00 90. 61 331 .64 7479 .97 7424. 17 552 .11 -1.Oe04 5958170. 88 367580. 80 0.00 9850 .97 14400. 00 90. 61 331 .64 7478 .90 7423. 10 640 .10 -1.Oe04 5958259. 62 367534. 75 0.00 9925 .94 14500. 00 90. 61 331 .64 7477 .82 7422. 02 728 .10 -1.Oe04 5958348. 37 367488. 69 0.00 10000 .91 14600. 00 90. 61 331 .64 7476 .75 7420. 95 816 .09 -1.Oe04 5958437. 12 367442. 64 0.00 10075 .88 14700. 00 90. 61 331 .64 7475 .68 7419. 88 904 .09 -1.Oe04 5958525. 87 367396. 58 0.00 10150 .85 14800. 00 90. 61 331 .64 7474 .61 7418 .81 992 .08 -1.Oe04 5958614. 61 367350. 52 0.00 10225 .82 14900. 00 90. 61 331 .64 7473 .54 7417 .74 1080 .08 -1.Oe04 5958703. 36 367304. 47 0.00 10300 .79 15000. 00 90. 61 331 .64 7472 .47 7416 .67 1168 .07 -1.Oe04 5958792. 11 367258. 41 0.00 10375 .76 15100. 00 90. 61 331 .64 7471 .40 7415 .60 1256 .07 -1.Oe04 5958880. 86 367212. 36 0.00 10450 .73 15200. 00 90. 61 331 .64 7470 .33 7414 .53 1344 .06 -1.Oe04 5958969. 60 367166. 30 0.00 10525 .70 15300. 00 90. 61 331 .64 7469 .26 7413 .46 1432 .06 -1.Oe04 5959058. 35 367120. 25 0.00 10600 .67 15400. 00 90. 61 331 .64 7468 .18 7412 .38 1520 .05 -1.Oe04 5959147. 10 367074. 19 0.00 10675 .64 15500. 00 90. 61 331 .64 7467 .11 7411 .31 1608 .05 -1.Oe04 5959235. 84 367028. 14 0.00 10750 .61 15600. 00 90. 61 331 .64 7466 .04 7410 .24 1696 .04 -1.Oe04 5959324. 59 366982. 08 0.00 10825 .58 15700. 00 90. 61 331 .64 7464 .97 7409 .17 1784 .04 -1.Oe04 5959413. 34 366936. 03 0.00 10900 .55 15800. 00 90. 61 331 .64 7463 .90 7408 .10 1872 .03 -1.1e04 5959502. 09 366889. 97 0.00 10975 .52 15900. 00 90. 61 331 .64 7462 .83 7407 .03 1960 .02 -1.1e04 5959590. 83 366843. 92 0.00 11050 .49 16000. 00 90. 61 331 .64 7461 .76 7405 .96 2048 .02 -1.1e04 5959679. 58 366797. 86 0.00 11125 .46 16100. 00 90. 61 331 .64 7460 .69 7404 .89 2136 .01 -1.1e04 5959768. 33 366751. 80 0.00 11200 .43 16200. 00 90. 61 331 .64 7459 .62 7403 .82 2224 .01 -1.1e04 5959857. 08 366705. 75 0.00 11275 .40 16300. 00 90. 61 331 .64 7458 .54 7402 .74 2312 .00 -1.1e04 5959945. 82 366659. 69 0.00 11350 .37 16400. 00 90. 61 331 .64 7457 .47 7401 .67 2400 .00 -1.1e04 5960034. 57 366613. 64 0.00 11425 .34 16500. 00 90. 61 331 .64 7456 .40 7400 .60 2487 .99 -1.1e04 5960123. 32 366567. 58 0.00 11500 .31 16600. 00 90. 61 331 .64 7455 .33 7399. 53 2575 .99 -1.1e04 5960212. 07 366521. 53 0.00 11575 .28 16700. 00 90. 61 331 .64 7454 .26 7398 .46 2663 .98 -1.1e04 5960300. 81 366475. 47 0.00 11650 .25 16800. 00 90. 61 331 .64 7453 .19 7397 .39 2751 .98 -1.1e04 5960389. 56 366429. 42 0.00 11725 .22 16900. 00 90. 61 331 .64 7452 .12 7396 .32 2839 .97 -1.1e04 5960478. 31 366383. 36 0.00 11800 .19 17000. 00 90. 61 331 .64 7451 .05 7395 .25 2927 .97 -1.1e04 5960567. 05 366337. 31 0.00 11875 .16 17100. 00 90. 61 331 .64 7449 .97 7394 .17 3015 .96 -1.1e04 5960655. 80 366291. 25 0.00 11950 .13 17200. 00 90. 61 331 .64 7448 .90 7393 .10 3103 .96 -1.1 e04 5960744. 55 366245. 19 0.00 12025 .10 17300. 00 90. 61 331 .64 7447 .83 7392 .03 3191 .95 -1.1e04 5960833. 30 366199 .14 0.00 12100 .07 17400. 00 90. 61 331 .64 7446 .76 7390 .96 3279 .94 -1.1e04 5960922. 04 366153 .08 0.00 12175 .04 17500. 00 90. 61 331 .64 7445 .69 7389 .89 3367 .94 -1.1e04 5961010. 79 366107 .03 0.00 12250 .01 17600. 00 90. 61 331 .64 7444 .62 7388 .82 3455 .93 -1.1e04 5961099. 54 366060 .97 0.00 12324 .98 17700. 00 90 .61 331 .64 7443 .55 7387 .75 3543 .93 -1.1e04 5961188. 29 366014 .92 0.00 12399 .94 17800. 00 90 .61 331 .64 7442 .48 7386 .68 3631 .92 -1.1e04 5961277. 03 365968 .86 0.00 12474 .91 17900. 00 90 .61 331 .64 7441 .41 7385 .61 3719 .92 -1.2e04 5961365. 78 365922 .81 0.00 12549 .88 18000. 00 90 .61 331 .64 7440 .33 7384 .53 3807 .91 -1.2e04 5961454. 53 365876 .75 0.00 12624 .85 18100. 00 90 .61 331 .64 7439 .26 7383 .46 3895 .91 -1.2e04 5961543. 28 365830 .70 0.00 12699 .82 18200. 00 90 .61 331 .64 7438 .19 7382 .39 3983 .90 -1.2e04 5961632. 02 365784 .64 0.00 12774 .79 18300. 00 90 .61 331 .64 7437 .12 7381 .32 4071 .90 -1.2e04 5961720. 77 365738 .59 0.00 12849 .76 18400. 00 90. 61 331 .64 7436 .05 7380 .25 4159 .89 -1.2e04 5961809. 52 365692 .53 0.00 12924 .73 18500. 00 90 .61 331 .64 7434 .98 7379 .18 4247 .89 -1.2e04 5961898. 27 365646 .47 0.00 12999 .70 18600. 00 90. 61 331 .64 7433 .91 7378 .11 4335 .88 -1.2e04 5961987. 01 365600 .42 0.00 13074 .67 "?!.FINAL Sperry Drilling Services CPAI Plan Report Company: ConocoPhiHips Alaska lnc. Date: 7!20!2006 Time: 11:29:43 Page: 6 Field: Colville`River Unit Co-ordinate(NE) Referenc e: Well: Plan: CD4-17, True North Site: Alpine CD4- Vertical (TVD) Reference: Plan: CD4-17 55.8 Well: Plan: CD4-17 Section (VS) Reference: Well (O.OON,O.OOE,290.21Azi) Wellpath: Plan: CD4-17 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD' locl Azim TVI) SysTVD N/S E/W MapN MapE DLS VS Commeet ft deg 'deg ft ft ft ft ft ft degl100ft ft j 18700.00 90.61 331.64 7432.84 7377.04 4423.88 -1.2e04 5962075.76 365554.36 0.00 13149.64 18800.00 90.61 331.64 7431.77 7375.97 4511.87 -1.2e04 5962164.51 365508.31 0.00 13224.61 18890.1 3 90.61 331.64 7430.80. 7375.00 4591.18 -1.2e04 5962244.50 365466.80 0.00 13292.19 CD4-17wp01 To ~R!61NAL Sperry Drilling Services Anticollision Report Company: ConocoPhillipsAlaska Inc... Date: 7/20/2006' Time: 10:39:58 Page: 1 Field: Colville River Unlt Reference Slte: Alpine CD4 Co-ordinate(NE) Refe rence: Well: Plan: CD4-17, True North Reference Well: Plan: CD4-17 Vertical (TVD) Reference: Plan: CD4-17 55.8 $eference Wellpath: Plan: CD4-1T Db: Orate GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan : CD4-17wp02 & NOT PLANNED PR Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 36.30 to 18890.13 ft Scan Method: Trav Cylinder No rth Maximum Radius: 2085.38 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 3012.89 2400.00 9.625 12.250 9 5/8" csg - 12 1/4" hole 13200.00 7490.39 7.000 8.750 7" csg - 8 3/4" hole 18890.13 7430.80 6.125 6.125 6 1/8" Open H ole Plan: CD4-17wp02 Date Composed: 7/20/2006 Alpine targets Version: 5 Principal: Yes Tied-to: From Well Ref. Point Summary ---- Offset Wellpath Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath 1VID MD Distance Area Deviation Warning ft ft ft ft ft Alpine CD2 CD2-43 CD2-43 V15 18878.23 18925.00 1881.36 278.36 1603.00 Pass: Major Risk Alpine CD2 CD2-56 CD2-56 V8 Out of range Alpine CD2 CD2-56 CD2-56L1 V10 Out of range Alpine CD4 CD4-208 CD4-208 V7 374.77 375.00 178.84 6.87 171.97 Pass: Major Risk Alpine CD4 CD4-208 CD4-208P61 V6 374.77 375.00 178.84 6.87 171.97 Pass: Major Risk Alpine CD4 CD4-209 CD4-209 V4 421.26 425.00 155.71 7.82 147.88 Pass: Major Risk Alpine CD4 CD4-210 CD4-210 V3 392.11 375.00 139.73 7.05 132.68 Pass: Major Risk Alpine CD4 CD4-318 CD4-318 V6 1158.60 1150.00 33.47 18.94 14.53 Pass: Major Risk Alpine CD4 CD4-318 CD4-318P61 V3 1158.60 1150.00 33.47 18.94 14.53 Pass: Major Risk Alpine CD4 CD4-319 CD4-319 V5 300.25 300.00 42.17 6.06 36.12 Pass: Major Risk Alpine CD4 Nanuq 3 Nanuq 3 V1 2708.67 2525.00 114.61 86.66 27.95 Pass: Major Risk Alpine CD4 Nanuq 5 Nanuq 5 V1 253.09 250.00 101.51 4.56 96.95 Pass: Major Risk Alpine CD4 Nanuq 5 Plan: CD4-212 VO Plan: 253.09 250.00 101.51 4.59 96:93 Pass: Major Risk Alpine CD4 Plan: CD4-16 Plan: CD4-16 VO Plan: 499.47 500.00 19.03 9.41 9.61 Pass: Major Risk Alpine CD4 Plan: CD4-16 Prelim: CD4-216 V2 36.80 36.10 19.87 No Offset Stations Alpine CD4 Plan: CD4-205 Plan: CD4-205 V1 Plan: 397.74 400.00 240.13 8.05 232.07 Pass: Major Risk Alpine CD4 Plan: CD4-206 Plan: CD4-206 V4 Plan: 125.67 125.00 220.74 2.59 218.15 Pass: Major Risk Alpine CD4 Plan: CD4-207 Plan: CD4-207 V2 Plan: 398.20 400.00 200.13 8.08 192.05 Pass: Major Risk Alpine CD4 Plan: CD4-211 Plan: CD4-211 V2 Plan: 399.16 400.00 120.13 8.09 112.04 Pass: Major Risk Alpine CD4 Plan: CD4-213 Plan: CD4-213 V1 Plan: 617.21 625.00 75.69 9.21 66.49 Pass: Major Risk Alpine CD4 Plan: CD4-214 Plan: CD4-214 V1 Plan: 399.92 400.00 60.13 8.11 52.03 Pass: Major Risk Alpine CD4 Plan: CD4-215 Plan: CD4-215 V1 Plan: 744.75 750.00 26.78 12.34 14.44 Pass: Major Risk Alpine CD4 Plan: CD4-222 Plan: CD4-222 VO Plan: 324.80 325.00 100.39 6.56 93.83 Pass: Major Risk Alpine CD4 Plan: CD4-321 Plan: CD4-321 V2 Plan: 375.92 375.00 80.43 7.81 72.63 Pass: Major Risk Alpine CD4 Plan: CD4-321 Prelim: CD4-321 P61 V1 36.80 36.30 80.08 No Offset Stations Alpine CD4 Rig: CD4-320 CD4-320 V5 299.05 300.00 59.16 5.48 53.69 Pass: Major Risk Alpine CD4 Rig: CD4-320 CD4-320P61 V3 299.05 300.00 59.16 5.48 53.69 Pass: Major Risk Alpine CD4 Rig: CD4-320 lookahead: CD4-320 V4 299.05 300.00 59.16 5.48 53.69 Pass: Major Risk Alpine CD4 Rig: CD4-320 Plan: CD4-320 V5 Plan: 299.05 300.00 59.16 5.59 53.58 Pass: Major Risk Alpine Nanuq EIS Pa~lan: Nanuq 4 Prelim: Nanuq 4 Lat A 55.80 0.00 50.01 No Offset Stations Alpine Nanuq EIS Pa~lan: Nanuq 4 Prelim: Nanuq 4 Lat B 55.80 0.00 50.01 No Offset Stations Prelim: Alpine CD2 Prelim: AW from CD2Prelim: AW-3G VO Plan: 18890.66 16225.00 141.49 198.68 -57.20 FAIL: Major Risk Prelim: Alpine GD2 Ptelim: AW from CD2Prelim: AW-4F VO Plan: Out of range SRAM n'~!~IN~L +~~-~J //~~\ V ~ moral O~~s~-s MTILOWSION SEIl1NG5 ~ ~MP~M' DEtMs Nom. WS tEw N Ir~uEe r siU InLLipolNiw Mahon AID lelwek 50.00 ~ Ra t'w ~ y a9 aw es Sn3 a5i c5 1] ae ~n I xav ISa 59 5'saw • n - - ~. - ~ muro~ M~ TOa p8990.13 30fli.lr e! I~¢CO41]vPOI t, yn® •urt o ~ ro F]4q~ 1 invg From Colour To MD 36 250 , .y01 250 500 S 500 750 750 1000 1000 1250 1250 1500 ~'L~ 1500 - ~-_---- 1750 C~ 1750 2000 175 I z ` IY" 2000 2250 7 ~ _"~= 4 ~Y"' 2250 2500 2500 2750 67 ISO 33 0 2750 3000 ~ 3000 3250 ~~ ~ 3250 3500 So • " 3500 3750 J ~ \ 3750 4000 I \ 4000 4250 37 ' \ \ 4250 4500 00 4750 ~ \ 1 `• F.h 5000 . ~\\~ n 6500 6750 8250 ' ~ ~:~~~~ ~ / ~~ ~ 11000 ~'' ~ ~ 0 11250 ~ ~ ~ Izso nsoo ' ~ ~ S1 1 ! 1500 11750 , ~~. ~ ~ 1 ,G~ 11750 12000 `~ \rs' 12000 12250 150 ~i~f '` 50 12250 12500 ~ 12500 12750 ` 12750 13000 175 13000 13250 180 13250 13500 13500 13750 1 !3750 14000 - r~+ua,:.,x M.iwa.k - zoel,Nlo. a;.~ 14000 14250 ~r w;w w.u - (;: 'ol Wi ivi~l c~ =~ ~1. M.~.. Ri•t 14250 14500 1. mwl. Myu a;r io.l~~~.rn O M. ~w.n ~~ si.x M.~a w.k ,, - iii ~n ~ c"w-~i,x w x .k 14500 `~ 14750 . , - glow-~9i, Mn~,a~ e . . ~ c ei~ a„-zisl,>m~~. w.k i' ~ 14750 15000 - -mlat~linl. M,i~w~ ~env~nal. Mgma~.k ivi~ . a~-znl, W4~~.auk -izi cei~~. a„-=zi4u.~.. „k 15000 15250 - ,ielaN.3ixauit M„ia a,.r riol<vo-,iwl, M.i~w,t ~zu~w~,i~-,,..„u. a.,~~a~ noccw-~xm, MOi~. a.k 15250 -~_ - 15500 - a~cNN„q ». M.io•a,k - 5 M ar r m -__ mn~w ~maa~l. w,~~a.,n zo ~ ~ow+,~, a;a 15500 15750 . .;v . 4 mm~a ]4 5 m.d ow-n.1,Mo,a a~ no~ , l. a,~. -,.o ca~~~. c~w-~:~I w,~~...a 15750 16000 ~acrkhm: c~l>e-:gal. M.,~~w•c - a,..r,..,,o: 16000 16250 - rim.<o.mslw~, ~'w-1osl, mop. aNx 16250 16500 16500 16750 Travelling Cylinder Azimuth (TFO+AZn [deg] vs Centre to Centre Separation [75Win] 16750 17000 17000 17250 17250 17500 oo. ~ nw ~ yr.. r M • wv rx urnz sc I xw. uw' - ~ ~' 'es~w ~Q~ ~ From Colour To MD `~ J6 ~ 250 .,r-v 250 500 0 ~ 500 750 +- 7N7 looo ~ loco Isso - 1250 1500 - IsuO t750 '~ 1750 2000 - zzsa ;~ ,~''. ~ 1, ,: ,t '-II 4zso asoo ~ - 3s ~ 6 4750 0 27 _ SIH10 ~ \ E 501111 5250 ~ `'9a V. ~. ' 5250 5500 ~` ~ sson s7so u ~ y 19- ~ nso/ ~ 1 caoo r ~ ~ 1~1 ~~ ~ 8250 5 C s J ~ _ 6 6500 _ _ v i ~' _ _ _ c7so 13 ~ 6 ~/ /'~ ~ 50 7000 24 ' , 7IX)0 F2fr- 7250 - ." ' ~ 725 \ 7500 50 ~_ 7' - / t ~~ '~ 50 8000 \ ~Q~ 250 _ q.S 8 8500 57 21 -- ~ 50 8500 8750 8750 9000 17 9000 9250 IS 9250 9s00 9500 - - 9750 9750 IIN)00 10000 111250 10250 10500 losoo Imsa Tmvelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Septll~4Wn 111011 jSONin] nouo 11250 n2so nsoo usoo Ipso n7sa Izooo 12000 12250 12250 12500 ~~~~ ~r.~o.~, „o.a~ S~~.w ,.w.w .:9~.~. .iu~..~o o.~ ono uz9als cw:;'rrvp09o;'r"m°' • 7/20/2006 11:26 AM v G7 z n r ConocoPhillips PLAN DETAILS ~~ CD4-17w 02 p Quarter Mile Alpine targets (1320 feet) radius plot Version 5 7/20/2006 1500 ' ~ - -- ------ 10000 _ _ C D2 33 CD2 3 3A - - CD2-43 CD 2-43 o CD2-56 CD2-56L1 0 0 - \ 500 CD4 -17w 02 - - t~ ~ CD2-60 CD 2-60 0 -500 -35000 -30000 -25000 -20000 -15000 -10000 -5000 0 5000 10000 West(-)/East(+) [2000ft/in] s s s ~ ~ ~ ~ s ~ ~ ~ ~ ~ ~ R ~ ~ ~ ~ ~ ~ ~ bLLEee CLLZBE 4LLl8E \ $ 3 i 6LL08E € - s 6LL6CE 8 < ~ 4LLBLE bLLLCE bLL9LE 4LLBLE 4LLVLE 4LLELE 6LLZLE bLL ILE £ 6(LOLE i 6LL69E ;~~~ ~ ~ i ~ ~ ~ ~ 6LLB9E $ < 6LLL9E 4LL99E bLLS9E bLL69E bLLE9E bLLL9E bLLl9E bLL09E N N R per, p 9LC6SE N N bLLBSE S G~ j bLLLSE O 6LC9S£ a bCCSS£ 1-I 41^oS / la) 4NON v 0 d c y O N ~! L ~ ~ c ; OI N ~~a~o> t ~ ~ t ~ $ n a CO C O O N dl ~ ~ 0 r ~ ~ ~ t[1 t1") ~ti~~d' O ~ ~ ~ r f~ 1~ p a~_...+~ in M ifl t[) -~ O ~ M M ~ 3 i~tiQ I~tDMOM J r ~ d' O M O e1'NNNN ~ ~ ~ 0 ~ tl UUUUU S c $ N ti ~ ~ 0 ~~~ d c O V d h '?RIGINAL • ~ ~ ~ ~ ~ £ZEIZ £Z£OZ i £Z£bl £Z£eI £Z£Ll EZ£9l EZES t - - - EZev 1 --i - - - EZE£ l I i EZ£Z l=~ c -43 0 a ~- ..--. _. £ZEl l3 N _~ c __ - £ZEO t o c O U £ZE6 ~ U t N 1 -- - £ZE8 i EZEL £ZE9 £Z£S i i -_ EZE7 i I --- - £ZEE £Z£Z £Z£l I - - £Z£ --- - LC9- i -- LL9l- CL9Z- yydaa lo~iuan anal waysAg Closest in POOL Closest Approach: Reference Well: CD4-17wp02 Plan Offset Well: CD2-5 6L1 Coords. Coords. - 3-D ctr- ASP ASP ctr Min. '~ ' Meas. Incl. TRUE Subsea N(+)/S(-) Vew VS Meas. Incl. TRUE Subsea N(+)/S(-) mew VS Dist. Depth Angle Azi. ND E(+)iW(- (290.21°) Comments Depth Angle Azi. ND E(+~W(_ (290.21° Comments POOL Min POOL Min Distance (498.45 ft Distance (498.45 ft in POOL (13055 - in POOL (13055 - 18890 MD) to CD2 18890 MD) to CD4 56L1 (7375 - 7455 17wp02 Plan (737 498.4 1889 90.61 331.6 7374.75 596223 365461. 13294.2 NDSS) 1955 84.2 151. 7406.64 596267 365226. 13671. 7455 TVDss) Closest Approach: Reference Well: CD4-17wp02 Plan Offset Well: CD2-4 3 Coords. Coords. - 3•D ctr• ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) Vew VS Dist. Depth Angle Azi. TVD E(+)/W(- (290.21°) Comments Depth Angle Azi. ND E(+)~W(_ (290.21°) Comments POOL Min POOL Min Distance (1893.34 Distance (1893.34 ft) in POOL (13055 ft) in POOL (13055 -18890 MD) to -18890 MD) to CD2-43 (7375 - CD4-17wp02 Plan 1893.3 1889 90.61 331.6 7374.75 596223 365461. 13294.2 7455 TVDss) 1888 87.4 150. 7380. 596312 367132. 12057.5 (7375 - 7455 Closest Approach: Reference Well: C D4-17wp02 Plan Offset Well: CD2-6 0 Coords. Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) Yew VS Meas. Incl. TRUE Subsea N(+yS(-) View VS Dist. Depth Angle Azi. ND E(+)/W(- (290.21°) Comments Depth Angle Azi. ND E(+)/yy(_ (290.21°) Comments POOL Min POOL Min Distance (3896.23 Distance (3896.23 ft) in POOL (13055 ft) in POOL (13055 -18890 MD) to - 18890 MD) to CD2-60 (7375 - CD4-17wp02 Ptan 3896.2 15411 90.61 331.6 7411.79 595915 367066. 10684.3 7455 NDss) 1653 86.9 148. 7375.00 596094 370526. 8102.55 (7375-7455 Closest Approach: Reference Well: C D4-17wp02 Plan Offset Well: CD2-3 3A Caords.- Coords.- 3•D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) mew VS Dist. Depth Angle Azi. ND E(+~W(- (290.21° Comments Depth Angle Azi. ND E(+)rVy(_ (290.21° Comments POOL Min POOL Min Distance (5910.17 Distance (5910.17 ft) in POOL (13055 ft) in POOL (13055 -18890 MD) to -18890 MD) to CD2-33A (7375 - CD4-17wp02 Plan 5910.1 1889 90.61 331. 7374.75 596223 365461. 13294.2 7455 TVDss) 1528 69.0 222. 7446.36 596719 3622 18092.1 (7375-7455 CD4-17wp02 POOLSummary.xis 7!20/2006 3:42 PM • CD4-17wp02 Surface Location ~..~ Datu<rr NAD27 Region: alaska • !" LatdudelLongitude Decimal Degrees C' UTM Zone: ~ r South r State Plane Zone: i" J UnRs: us~ft • ~" L a~~ r _. ordyl Starting CD4-17 To: D~'Aa NAD27 R~~: alaska • C' Latitude/Longitude Decimal Degrees C' UTM Zoe: True r South C State Plane Zone: I" J UnRs: us-ft C•' Legal Description (NAD27 only) Legal Description - ---~ X: 377863.63 Township: 011 ~ Range 004 Y: 5957451.65 Mreridian: ~~ Section: 24 ~ ___-_-------- I ~ ~ ~ ~ I FNL 2962.0707 FEL 379.95674 ~ --- ___ _- _. -____.__ .............__....J 7" From: Datum: NAD27 Region: alaska • l' Latitude/LongRude DecimalDegrees f UTM Zone: ~ (- South f• Stye Plane Zone: r~ Units: us-ft • C' Lei IC ~cu~+r _~ - -_ Starting Coordinates: -- X 368089.03 Y: 5957195.79 CD4-17wp02 Toe From: _.__ .._._~~..~.v__..,_ Datum: NAD27 Regi l" Latitude/Longitude Decimal [ f UTM Zone: r G State Plane Zone:r~ r ~ -- ~_ To: Datum: NAD27 Region: alaska • f Latitude/Longitude DecimalDegrees • C' UTM Z~: True (- South (' State Bane Zone: 1" ~ Unds: us-ft • ~' Legal Description (NAD27 only] Legal Description- Township: 011 ~ Rage: 004 Meridian: ~~ Section: 23 FNL • 3383.0766 FEL • 4869.9252 ~~ r Legal Descriptron Township: 011 ~ Rarge: 004 ~ ! Meriden: ~~ Section: 15 i FNL 3661 2407 FEL 2293.8082 Coordinates: 365466.8 Y: 5962244.5 ORIGINAL • • 7/20/2006 9:11 AM '~~~''..4q'~~,~G,~'n e ,~ .... V a L :, ~. dom.. • • ~, _ _- ... -- .~ ~: o Responsible: 0 Complete Surface Location* Coordinate System: X / Y (ASP) Coord. Latitude: (Decimal Degrees) Longitude: (Decimal Degrees) Geolo is Tar et s Formation TVD (SS) (ft) MD (ft) X Y Desired Hole Angle Target Boundaries Comments I ine A 7,428 368,177 5,957,058 88 Heel Tar et 7,435 368,040 5,957,285 7 feet below top Alpine A reservoir oe Target 7,375 365,554 5,962,077 Geolo is Tar et Discussion Geolo is Pro nosis Formation (SS) (ft) MD (ft) Two-Wa Time y Uncertaint y Gross Thickness Net Pa y Tem p Porosit y Perm Comments (ft) (ft) (miliseconds) (ft) (ft) (ft) (deg C) (%) (mD) C-40 C-30 2,353 C-20 2,721 K-3 Marker 3,792 K-3 Basal 4,014 K-2 Marker 4,049 K-2 Basal 4,149 Ibian 97 5,698 Ibian 96 6,112 HRZ 6,781 Base HRZ 7,007 K-1 Marker 7,048 Ku aruk Fm 7,093 LCU/Miluveach 7,127 Miluveach A 7,348 Ipine D 7,366 UJU 7,406 Alpine A Reservoir 7,428 25 16 17 5 Geolo is Pro nosis Discussion - oss A ., ., A see o ~ ~ pro , ea io be approx ~ ~trl~y `Lti rce`±hlcl~ e ~ ~~ - ~7 lar :q cor~ ~ o P50 case, a pred cted ~ ,~ _ .~ approximately 15 feet. Net pay thickness is expected to increase slightly along the planned wellpath towards the toe of CD2-56L1 where approximately 18 feet of ne pay was intersected. It is planned to land the well approximately 7 feet below the top of the Alpine A reservoir sequence at an angle of about 88 degrees. Upon drilling out from 7" casing the strategy is to continue to steer the well down-section until resistivity of less than 10ohmm is encountered. This should aid in defining net pay thickness and provide geosteering guidance along the wellbore. The target interval for geosteering the remainder of the well is defined as > 10ohmm resistivity. The well wil be steered to the landing point from the office; two wellsite geologists will be employed during the drilling of the horizontal section. Seismic mapping does not indicate the presence of any faults along the wellbore, but it is possible that faults or fractures with a throw less than seismic resolution (appnc. 40ft1 could he intersected In the nearby CD2-60 well, asub-seismic fracture system was intersected near the toe of the well: this was associated with increased re Offset Pore Pressure -Fracture Gradient Profile* Well Name or Seismic Line TVD (SS) (ft) Fracture Gradient EMW pore Pressure (EMw) Measurement Method CD2-60 7,000 11.07 Static surve 5-25-06 data CD2-55 7,000 11.62 Static surve 5-25-06 data CD2-56 7,000 10.94 Static surve 5-25-06 data ~~q 7/20/2006 9:1++1 AM k '~~ • • • ~ esponsible: ~. i ~faxlNeil M b x, m i: o W e i l V o l u e ~ Complete Casing Prog ram Hole Size (in.) Casing Size (in.) Setting Depth (MD) (ft) TVD (SS) (ft) TVD (RKB) (ft) Proposed TOC (ft) Centr ali- zation Comments 12.25 9.625 3,013 8.75 7 13,200 6.125 18,888 Fluids From MD (RKB) (ft) To MD (RKB) (ft) Mud Type Density (PPG) Viscosity (sec/quart) Fluid Loss (CC/30 min) Other Comments 114 3,013 resh Water Bas 9.8 3,013 13,200 resh Water Bas 9.8-10 13,200 18.888 resh Water Bas 9.6 May need to use barite for wei ht Final Directi onal Profile Responsible: Status: Q From MD (RKB) (ft) To MD (RKB) (ft) Azimuth Max DLS Desired Hole Angle Max Hole Angle Comments 114 3,013 4 3,013 13,200 4 13,200 18,888 6 90 Drilling Issues Issue Detailed Description Mitigation bnormal Pressure there ma be hi h or low unexpected pressure attempt to mana a reservoir and/or use n ri20/20~06 ~:~ ~ M I ~ '~ BB, . , ~ .. • ~ 7/20/2006 11 M '~.t ~i~ CD4-17 Surface Location Nad83 to Nad27 Ending Coordinates: X: 1517897.14 Y: 5957198.$ • X: 377563.625861487 Y: 5957451.65405351 ORIGINAL SHARON K. ALLSUP-DRAKE 1154 CONOCOPHILLIPS ATO1530 ~~j 700GST. DATE ~- US ~ ~ -"""56-1561/441 ANCHORAGE AK 99501 PAY TO THE C~ S ~ ~ ~ ~~ ~,' ORDER OF r ~ j r ' p, ,~--.."' ~ `CE^U~-n-~..s/ d-D ~ ~'S L' ~~~ ~~'' ` ppLLARS U " ~ ~,,, 3 ack - JPMorganChaSe ~ j Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH ~ t ;~,L~ MEMO ~:0441L55LL~:528747L907927ii'L154 • • • TRANSMITTAL LETTER CHECKLIST WELL NAIVTE ~~rj~ ~ ~'' ~ 7 PTD# Z(,~~- ~~~ Development `~ Service Exploratory Stratigraphic Test Non-Conventional Welt Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CI-IECK ~ ADD-ONS WHAT ~ (OPTIONS) APPLIES TEXT FOR APPROV:4L LETTER MliLTI LATERAL ~ The permit is for a new wellbore segment of existing +.' (If last two digits ~ well in ~ permit No. API No. 50- - - API number are ~ ' between 60-69) i Production should continue to be reported as a function of the i original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and Logs acquired for the pilot hole must be clearly differentiated in both well name ( PH} and API number ~ (50- -_) from records, data and logs acquired for well SPACING ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 25.05. Approval to perforate and produce ; inLct is contingent upon issuance of a conservation order approving a spacing j exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the Commission must be in SAMPLE I no greater than 30' sample intervals from below the permafrost or ~ from where samples are first caught and 10' sample intervals I through target zones. Non-Conventional i Please note the following special condition of this permit: ;production or production testing of coal bed methane is not allowed Well ~ for (name of well) until after (Company Name) has designed and I implemented a water well testing program to provide baseline data ~ on water quality and quantity. SCompany Name) must contact the ~ Commission to obtain advance approval of such water well testing ~ Rev: [;25/06 C:~jodyitransmittal checklist 1 i ^^ ~ a 'mL ~ -' ~ E~ y c L N. ~, N N. D: y U, ~, U c ° o U' v. o o o, n ~ ' O. y, c m ~ O cY ~ ~ ~, ~ y v. a i, c L ~ C. 9~ y. y. 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O, L, m m U ° ~ ~ `~~ ~ d, ~, a O o, a~, U U o, U D W a , , , , , , , , , , , , . , . , , , . : , , . ~31 = O r N M V' ~ CO 1~ CO O O N r M et ~ r r (O f~ a0 O O N N N N M ~I' N N LL'1 (D N 00 N N N N O O N_ M M N M I M M M ~ c0 M_ M I~ W M M 07 M U FC`-' U ~ N ~ o ~ ,... ~ .. c U C O ~ C ~ ~ ~ ~ N o ~ R N ~ ° ° W ''' ao °~ . ao N ~ ~ ~ ~ Q O .J N - ~ o U C.... W U a ~ a a a ~ `~ ~ w a a w ~~ ~ a~ a cn 3 c • • 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 simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Nov 07 07:50:10 2006 Reel Header Service name .............LISTPE Date .....................06/11/07 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/11/07 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library 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 MWD RUN 2 JOB NUMBER: MW0004612534 LOGGING ENGINEER: D. RICHARDSO OPERATOR WITNESS: D. MICKEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: • Scientific Technical Services Scientific Technical Services CD4-17 501032053400 ConocoPhillips Alaska Inc Sperry Drilling Services 07-NOV-06 MWD RUN 3 MWD RUN 4 MW0004612534 MW0004612534 D. RICHARDSO A. SHANAHAN D. MICKEY D. BURLEY 24 11N 4E 2318 380 55.80 19.50 WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 8.750 2ND STRING 6.125 3RD STRING PRODUCTION STRING CASING DRILLERS SIZE (IN) DEPTH (FT) 9.625 3010.0 7.000 13334.0 ~-ri~r ~ ~~/a ~ ~ REMARKS: ~ • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEOPILOT ROTARY-STEERABLE BHA (GP) MWD RUNS 2,3 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND ACOUSTIC CALIPER (ACAL). ADDITIONALLY, MWD RUN 4 INCLUDED BI-MODAL ACOUSTIC TOOL (BAT) CONFIGURED IN RECORD-ONLY MODE. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-4 REPRESENT WELL CD4-17 WITH API#: 50-103-20534-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17975'MD/7492'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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.75" BIT) MUD WEIGHT: 9.6 - 9.85 PPG MUD SALINITY: 200 - 1000 PPM CHLORIDES FORMATION WATER SALINITY: 25,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SA~TONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/07 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2959.0 17918.0 PEF 2990.0 13270.0 RPM 2990.0 17924.5 NPHI 2990.0 13256.5 RPD 2990.0 17924.5 RHOB 2990.0 13270.0 RPS 2990.0 17924.5 FET 2990.0 17924.5 FONT 2990.0 13256.5 RPX 2990.0 17924.5 DRHO 2990.0 13270.0 NCNT 2990.0 13256.5 ROP 3020.5 17975.0 C BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2959.0 4454.5 MWD 3 4454.5 13345.0 MWD 4 13345.0 17975.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 ~ • DRHO MWD G/CM 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2959 17975 10467 30033 2959 17975 FCNT MWD CNTS 528.69 4328.46 1100.18 20534 2990 13256.5 NCNT MWD CNTS 103282 190487 134958 20534 2990 13256.5 RHOB MWD G/CM 1.023 3.152 2.42523 20561 2990 13270 DRHO MWD G/CM -4.474 0.207 0.0153023 20561 2990 13270 RPD MWD OHMM 0.35 2000 12.0327 29817 2990 17924,5 RPM MWD OHMM 0.29 2000 9.3981 29817 2990 17924.5 RPS MWD OHMM 0.16 2000 6.30515 29817 2990 17924.5 RPX MWD OHMM 0.14 1611.62 6.13893 29817 2990 17924.5 FET MWD HOUR 0.16 142.67 1.23373 29817 2990 17924.5 GR MWD API 37.83 376.61 98.9644 29919 2959 17918 PEF MWD BARN 2.02 15.03 2.92169 20561 2990 13270 ROP MWD FT/H 0.3 405.57 144.013 29910 3020.5 17975 NPHI MWD PU-S 8.45 62.85 30.4782 20534 2990 13256.5 First Reading For Entire File..........2959 Last Reading For Entire File...........17975 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/07 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.......06/11/07 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH GR 2959.0 STOP DEPTH 4391.5 FET 2990. 0 4382.0 NPHI 2990.0 4339.0 FCNT 2990.0 4339.0 PEF 2990.0 4352.5 NCNT 2990.0 4339.0 RPS 2990.0 4382.0 RHOB 2990.0 4352.5 RPX 2990.0 4382.0 RPM 2990.0 4382.0 DRHO 2990.0 4352.5 RPD 2990.0 4382.0 ROP 3020.5 4454.5 LOG HEADER DATA DATE LOGGED: 18-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION:. 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4454.0 TOP LOG INTERVAL (FT) 3020.0 BOTTOM LOG INTERVAL (FT) 4454.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 52.4 MAXIMUM ANGLE: 58.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 145654 CTN COMP THERMAL NEUTRON 174114 ALD Azimuth. Lit ho-Den 105075541 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 3010.0 BOREHOLE CONDITIONS • MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.60 MUD VISCOSITY (S): 78.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3) 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.200 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .830 104.0 MUD FILTRATE AT MT: .950 70.0 MUD CAKE AT MT: 1.100 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....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...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD020 CNTS 4 1 68 4 2 NCNT MWD020 CNTS 4 1 68 8 3 RHOB MWD20 G/CM 4 1 68 12 4 DRHO MWD020 G/CM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HOUR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 BARN 4 1 68 44 12 ROP MWD020 FT/H 4 1 68 48 13 NPHI MWD020 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2959 4454.5 3706.75 2992 2959 4454.5 FONT MWD020 CNTS 528.69 2848.51 830.986 2699 2990 4339 NCNT MWD020 CNTS 103282 180459 124429 2699 2990 4339 RHOB MWD20 G/CM 1.023 2.703 2.24308 2726 2990 4352,5 DRHO MWD020 G/CM -4.474 0.207 -0.00238518 2726 2990 4352.5 RPD MWD020 OHMM 0.35 2000 34.9487 2732 2990 4382 RPM MWD020 OHMM 0.29 1570.18 16.1369 2732 2990 4382 RPS MWD020 OHMM 0.68 2000 6.1046 2732 2990 4382 RPX MWD020 OHMM 1.25 1611.62 5.91817 2732 2990 4382 FET MWD020 HOUR 0.26 74.49 2.50001 2732 2990 4382 GR MWD020 API 51.99 196.22 119.295 2866 2959 4391.5 PEF MWD020 BARN 2.23 15.03 3.05225 2726 2990 4352.5 ROP MWD020 FT/H 3.54 373.45 176.902 2869 3020.5 4454.5 NPHI MWD020 PU-S 12.92 62.85 37.0012 2699 2990 4339 First Reading For Entire File..........2959 Last Reading For Entire File...........4454.5 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/07 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 Nuntber...........1.0.0 Date of Generation.......06/11/07 Maximum Physical Record..65535 File Type ................LO Previous File Name.......~LIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 4339.5 13256.5 FONT 4339.5 13256.5 NCNT 4339.5 13256.5 PEF 4353.0 13270.0 DRHO 4353.0 13270.0 RHOB 4353.0 13270.0 FET 4382.5 13302.5 RPX 4382.5 13302.5 RPS 4382.5 13302.5 RPM 4382.5 13302.5 RPD 4382.5 13302.5 GR 4392.0 13310.0 ROP 4455.0 13345.0 LOG HEADER DATA DATE LOGGED: 22-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13345.0 TOP LOG INTERVAL (FT) 4454.0 BOTTOM LOG INTERVAL (FT) 13345.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.1 MAXIMUM ANGLE: 89.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 10505932 CTN COMP THERMAL NEUTRON 174114 ALD Azimuth. Litho-Den 10507541 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 3010.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.65 MUD VISCOSITY (S) 9.8 MUD PH: 9.4 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 5.000 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.680 140.0 MUD FILTRATE AT MT: 3.700 72.0 MUD CAKE AT MT: 2.800 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: • HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4339.5 13345 8842.25 18012 4339.5 13345 FCNT MWD030 CNTS 658.27 4328.46 1140.92 17835 4339.5 13256.5 NCNT MWD030 CNTS 114726 190487 136551 17835 4339.5 13256.5 RHOB MWD030 G/CM 2.165 3.152 2.45307 17835 4353 13270 DRHO MWD030 G/CM -0.087 0.201 0.0180058 17835 4353 13270 RPD MWD030 OHMM 1.43 2000 7.43218 17841 4382.5 13302.5 RPM MWD030 OHMM 1.3 298.35 6.70201 17841 4382.5 13302.5 RPS MWD030 OHMM 1.33 182.16 6.35967 17841 4382.5 13302.5 RPX MWD030 OHMM 1.42 204.91 6.31327 17841 4382.5 13302.5 FET MWD030 HOUR 0.16 18.15 0.554296 17841 4382.5 13302.5 GR MWD030 API 37.83 376.61 110.361 17837 4392 13310 PEF MWD030 BARN 2.02 8.49 2.90173 17835 4353 13270 ROP MWD030 FT/H 0.3 405.57 165.126 17781 4455 13345 NPHI MWD030 PU-S 8.45 49.64 29.491 17835 4339.5 13256.5 First Reading For Entire File..........4339.5 Last Reading For Entire File...........13345 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/07 Maximum Physical Record..65535 File Type ................LO Next File Name...........~LIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/07 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 13303.0 17924.5 FET 13303.0 17924.5 RPX 13303.0 17924.5 RPM 13303.0 17924.5 RPD 13303.0 17924.5 GR 13310.5 17918.0 ROP 13345.5 17975.0 LOG HEADER DATA DATE LOGGED: O1-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 17975.0 TOP LOG INTERVAL (FT) 13345.0 BOTTOM LOG INTERVAL (FT) 17975.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.6 MAXIMUM ANGLE: 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 13334.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.50 MUD VISCOSITY (S): 41.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 34000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .120 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 178.0 MUD FILTRATE AT MT:~ MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 .225 .130 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 13303 17975 15639 9345 RPD MWD040 OHMM 4.12 2000 14.1392 9244 RPM MWD040 OHMM 3.02 2000 12.61 9244 RPS MWD040 OHMM 0.16 21.91 6.25922 9244 RPX MWD040 OHMM 0.14 18.05 5.86769 9244 FET MWD040 HOUR 0.33 1 42.67 2.17081 9244 GR MWD040 API 39.93 122.7 70.5854 9216 ROP MWD040 FT/H 6.76 2 37.74 93.2828 9260 First Reading For Entire File..........13303 Last Reading For Entire File...........17975 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/07 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF 6 68.0 First Last Reading Reading 13303 17975 13303 17924.5 13303 17924.5 13303 17924.5 13303 17924.5 13303 17924.5 13310.5 17918 13345.5 17975 Tape Trailer Service name .............~TPE Date .....................06/11/07 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date .....................06/11/07 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF • Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services End Of LIS File
