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Home My WebLink About206-145CAUTION: 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 6-18-25 Date:Thursday, June 19, 2025 7:27:59 AM Attachments:image001.png MIT CRU CD4 PAD SI TESTS 06-18-25.xlsx Morning, Please see the attached 10-426 form from the CD4-pad SI non-witnessed MIT-IA that was performed on 6-18-25. 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 2100910 Type Inj N Tubing 435 795 790 790 Type Test P Packer TVD 7044 BBL Pump 3.3 IA 800 4240 4160 4140 Interval V Test psi 4000 BBL Return 3.4 OA 515 540 540 540 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2120050 Type Inj N Tubing 1180 1510 1510 1510 Type Test P Packer TVD 7291 BBL Pump 3.2 IA 460 3300 3250 3245 Interval V Test psi 3000 BBL Return 3.2 OA 10 14 16 16 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2061450 Type Inj N Tubing 2390 2895 2890 2890 Type Test P Packer TVD 5967 BBL Pump 2.4 IA 970 4220 4130 4120 Interval V Test psi 4000 BBL Return 2.4 OA 470 650 640 635 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 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: 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 18E.006. CD4-214 Notes:MITIA to maximum gas injection pressure per AIO 28.006 AMENDED Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD4 PAD Non-witnessed Van Camp 06/18/25 Notes:MITIA to maximum gas injection pressure per AIO 18D.005 AMENDED Notes: Notes: Notes: CD4-12 CD4-213B Form 10-426 (Revised 01/2017)2025-0618_MIT_CRU_CD4-214 9 9 9 9 999 99 99 9 9 -5HJJ CD4-214 AIO 28.006 MITIA 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 CD4-214 50103205370000 2061450 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 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD4-214 (PTD# 206-145) IA Suspect Date:Monday, December 4, 2023 4:54:41 PM Attachments:AnnComm Surveillance TIO for CD4-214.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Saturday, December 2, 2023 10:37 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD4-214 (PTD# 206-145) IA Suspect Chris, CRU CD4-214 (PTD# 206-145) was reported by operations for high IA. The well has been shut it and initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com CD4-214 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD4-214 2023-10-16 314 1018 704 IA CD4-214 2023-11-12 2379 1407 -972 IA CD4-214 2023-11-15 2420 1200 -1220 IA CD4-214 2023-11-18 2235 150 -2085 IA CD4-214 2023-11-25 2440 700 -1740 IA CD4-214 2023-11-29 2400 700 -1700 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CD4-214 claytg Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull Evo, Set Inj Valve CD4-214 1/24/2022 boehmbh Notes: General & Safety Annotation End Date Last Mod By NOTE: Slip Retainer Spring and 1/4" of Evo Slip- **LEFT IN HOLE 1/23/2022 boehmbh Note: Waivered for Water-Only Injection due to TxIA on gas 9/25/2017 pproven NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/7/2008 lmosbor NOTE: TREE: FMC 4-1/16" 5000 psi - TREE CAP CONNECTION: 7" OTIS 11/13/2006 triplwj General Notes: Last 3 entries Com Date Last Mod By 35 bbls NaCl/NaBr left in open hole, 186 bbls NaBr lost to hole, 3166 bbls Duo-Vis lite lost to hole. 3/15/2020 ncdr3cm ** Liner set on bottom @ 10812’, TOL 8725' 3/15/2020 ncdr3cm Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.25 37.0 114.0 114.0 68.00 H-40 SURFACE 9 5/8 8.83 36.4 2,677.0 2,365.4 40.00 L-80 BTC-M INTERMEDIATE 7 6.28 34.2 8,696.0 6,210.4 26.00 L-80 OPEN HOLE 258' 6 1/8 14,814.3 15,072.0 6,279.7 LINER 4 1/2 3.99 8,493.9 14,814.3 6,263.8 12.60 L-80 SLHT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.9 Set Depth … 8,506.8 Set Depth … 6,198.0 String Ma… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.9 31.9 0.00 HANGER 10.850 FMC TUBING HANGER 4.500 2,189.2 1,983.2 37.45 NIPPLE 5.620 DB NIPPLE 3.812 7,419.0 5,915.3 58.15 GAS LIFT 5.984 CAMCO KBG-2 3.938 7,523.5 5,967.5 62.04 PACKER 5.970 BAKER PREMIER PACKER Baker 3.875 7,580.8 5,993.5 63.89 NIPPLE 5.000 XN NIPPLE. 3.725 XN Nipple Milled to 3.80" 3.800 8,494.6 6,197.2 86.15 WLEG 4.500 BAKER FLUTED WLEG ASSEMBLY 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,189.2 1,983.2 37.45 INJ VALVE 3.81" A-1 INJ VLV (S/N:HABS- 0555) 1/24/2022 1.250 8,750.0 6,214.4 85.55 WHIPSTOCK - MONOBORE 4.5" monobore whipstock - BOT tray 180° ROHS 12/7/2019 1.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,419.0 5,915.3 58.15 1 Gas Lift DMY BK 1 6/25/2019 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,493.9 6,197.1 86.14 SLEEVE 5.790 BAKER 'HR' LINER SETTING SLEEVE 4.420 8,506.9 6,198.0 86.17 NIPPLE 5.600 BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 8,520.5 6,198.9 86.20 XO 5x4.5 5.570 CROSSOVER 5" x 4.5" 4.000 14,814.3 6,263.8 85.89 OPEN HOLE 6.125 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,688.0 14,773.0 6,209.8 6,260.9 11/10/2006 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 12,230.0 14,820.0 1 ACID STIM 4/13/2007 0.0 0.00 0.00 CD4-214, 6/13/2023 12:32:24 PM Vertical schematic (actual) OPEN HOLE 258'; 14,814.3- 15,072.0 LINER; 8,493.9-14,814.3 ACID STIM; 12,230.0 SLOTS; 8,688.0-14,773.0 WHIPSTOCK - MONOBORE; 8,750.0 L1 Slotted Liner; 8,725.1- 10,812.0 INTERMEDIATE; 34.2-8,696.0 PACKER; 7,523.4 GAS LIFT; 7,419.0 SURFACE; 36.4-2,677.0 INJ VALVE; 2,189.2 NIPPLE; 2,189.2 CONDUCTOR; 37.0-114.0 WNS INJ KB-Grd (ft) 43.34 RR Date 11/14/200 6 Other Elev… CD4-214 ... TD Act Btm (ftKB) 15,072.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053700 Wellbore Status INJ Max Angle & MD Incl (°) 93.59 MD (ftKB) 9,890.12 WELLNAME WELLBORECD4-214 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: INJ VALVE 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. CD4-214 COLVILLE RIV NAN-N CD4-214 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 CD4-214 50-103-20537-00-00 206-145-0 W SPT 5967 2061450 4000 2020 2012 2016 2018 445 725 717 710 REQVAR P Adam Earl 6/18/2023 MIT IA tested as per AIO 28.006 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 NAN-N CD4-214 Inspection Date: Tubing OA Packer Depth 740 4400 4325 4320IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230620135001 BBL Pumped:2.9 BBL Returned:2.9 Thursday, July 27, 2023 Page 1 of 1           P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 13, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Brennen Green ConocoPhillips Well Integrity Field Supervisor Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.04.13 11:34:18-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green ConocoPhillips Alaska Inc.Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-offReport of Sundry Operations (10-404)Alpine FieldWell Name API # PTD #Initial top of cementVol. of cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant dateft bbls in galCD3-106 5010320611-0000 210-001 N/APost Conductor Ext10.75" 4/5/2022 2 4/12/2023CD3-117 5010320596-0000 209-026 N/APost Conductor Ext13" 4/5/2022 3 4/12/2023CD3-127 5010320634-0000 211-005 18' 1.0 8" 4/9/2022 1 4/12/2023CD3-302A 5010320522-0100 210-035 N/APost Conductor Ext9" 4/5/2022 2 4/12/2023CD4-214 5010320537-0000 206-145 22' 8" 1.6 7" 4/9/2022 1.5 4/12/2023CD4-319 5010320516-0000 205-148 22' 3" 1.5 7" 4/9/2022 1.5 4/12/2023Date 04/13/2023CD3 & CD4 PadsCD4-2145010320537-0000206-14522' 8"1.67"4/9/20221.54/12/2023 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD4-214 (PTD# 206-145-0) MI Injection Date:Wednesday, May 25, 2022 9:52:23 AM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday, April 20, 2022 3:44 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD4-214 (PTD# 206-145-0) MI Injection Hello Chris— Sorry for the delay in the response on this follow-up. I wanted to let you know of a few tentative mitigations we’re working after this inadvertent injection at CRU CD4-214. The following three action items were identified and are being pursued or are already completed: 1. Alpine Ops is adding additional physical signage at each injection well that is not allowed to inject gas. Currently, there is a “Waivered Well” sign hung on each of these wellheads. They have added a sign that says “Do Not WAG” that is physically attached to the blinds on the MI line of these wells. That way, a person has to cut off and remove a “Do Not WAG” sign before they could possibly remove the blind for gas injection. 2. Our internal software that tracks deadlines, well status, and other data for compliance did not flag CD4-214 when it was placed on gas injection. After investigation, this was due to a slight bug from a recent version change. It hadn’t been noticed as this particular error is relatively rare. This issue has been resolved. This notification is a trailing indicator, of course, it only alerts once the well has incorrectly been put on gas injection—but it does limit the exposure time if this ever occurs again. 3. Alpine Ops is looking into a possible update to the SCADA software system that will add another level of protection against WAG’ing wells. This change would prevent any WAG changes on waivered wells at the Board Operator level. This software change is being worked and is not yet complete. Let me know if you have any questions. Travis From: Smith, Travis T Sent: Saturday, February 26, 2022 9:36 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD4-214 (PTD# 206-145-0) MI Injection Chris— CRU injector CD4-214 (PTD# 206-145-0) was placed on MI injection erroneously earlier this week. The well is designated as a water-only injector per the terms of AIO 28.006. We discovered this error during normal surveillance, no IA pressure or other limits were exceeded. This was noticed this morning and the well was immediately shut-in awaiting a WAG back to water injection. I will be reviewing the circumstances to identify if there is a systemic issue that allowed the well to be mis- handled. A 90-day TIO is attached. Please let me know if you have any questions. 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"# #2$$CG.6 -=&08> 0=/(8> " -=(/> #$ %&'# 0=(8/> &=,-(> -=&8> -=&08> &=-//> -=&0'>'( 0=--&> '=0'> '> '> (=8/&> -=,&8 0-4-> //> -E 4-&(E /E &-'> .# 9 2 4&/H &(0> 8%'8, # ,2&8&8 ' ( )# ( *' ! +#$ *'+ #$ (# * ', By Samantha Carlisle at 3:21 pm, Aug 13, 2021 321-399 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.08.13 15:00:52-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Mouser ADL 380077 SFD 8/13/2021 10-404 SFD 8/13/2021 NANUQ DSR-8/16/21 Photo document damage and repair to be submitted with 10-404. VTL 8/19/21 X dts 8/19/2021 JLC 8/19/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.19 11:14:22 -08'00' RBDMS HEW 8/20/2021 !""# $ % &'(&)*'' ( &+'' ( ,' - ./,$*) *0,1$ 2)*#3 '( . , 4 4 5 2#")#2(+ +6 . + 4 5 -+7&' ,' - . Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.08.13 14:58:43-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Mouser Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:CD4-214 claytg Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SBHP & Set Injection Valve post CTD 3/26/2020 CD4-214 claytg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD)… 114.0 Wt/Len (l… 68.00 Grade H-40 Top Thread Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.4 Set Depth (ftKB) 2,677.0 Set Depth (TVD)… 2,365.4 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC-M Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.2 Set Depth (ftKB) 8,696.0 Set Depth (TVD)… 6,210.4 Wt/Len (l… 26.00 Grade L-80 Top Thread Casing Description OPEN HOLE 258' OD (in) 6 1/8 ID (in)Top (ftKB) 14,814.3 Set Depth (ftKB) 15,072.0 Set Depth (TVD)… 6,279.7 Wt/Len (l…Grade Top Thread Casing Description LINER OD (in) 4 1/2 ID (in) 3.99 Top (ftKB) 8,493.9 Set Depth (ftKB) 14,814.3 Set Depth (TVD)… 6,263.8 Wt/Len (l… 12.60 Grade L-80 Top Thread SLHT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,493.9 6,197.1 86.14 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 8,506.9 6,198.0 86.17 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 8,510.7 6,198.2 86.18 HANGER BAKER 'DG' FLEX LOCK LINER HANGER 4.400 8,520.5 6,198.9 86.20 XO 5x4.5 CROSSOVER 5" x 4.5" 4.000 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 31.9 Set Depth (ft… 8,506.8 Set Depth (TVD) (… 6,198.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 31.931.90.00 HANGER FMC TUBING HANGER 4.500 2,189.21,983.237.45 NIPPLE DB NIPPLE 3.812 7,523.5 5,967.5 62.04 PACKER BAKER PREMIER PACKER 3.875 7,580.8 5,993.5 63.89 NIPPLE XN NIPPLE. 3.725 XN Nipple Milled to 3.80"3.800 8,494.6 6,197.2 86.15 WLEG BAKER FLUTED WLEG ASSEMBLY 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 2,189.2 1,983.2 37.45 INJ VALVE 3.81" A-1 INJ VLV (S/N:HRS-44) ON 3.812" DB LOCK 3/26/2020 1.250 8,750.06,214.4 85.55 WHIPSTOCK - MONOBORE 4.5" monobore whipstock - BOT tray 180° ROHS 12/7/2019 1.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 8,688.0 14,773.0 6,209.8 6,260.9 11/10/2006 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Frac Summary Start Date 4/13/2007 Proppant Designed (lb)Proppant In Formation (lb) Stg # 1 Start Date 4/13/2007 Top Depth (ftKB) 12,230.0 Btm (ftKB) 14,820.0 Link to Fluid System Vol Clean (bbl)Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Ty pe Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 7,419.0 5,915.3 CAMCO KBG-2 1 Gas Lift DMY BK 0.000 6/25/2019 Notes: General & Safety End Date Annotation 9/25/2017Note: Waivered for Water-Only Injection due to TxIA on gas 7/24/2009 NOTE: ZONES NOT LOADED TO WELLVIEW YET 11/7/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 CD4-214, 5/29/2020 11:16:11 AM Vertical schematic (actual) OPEN HOLE 258'; 14,814.3- 15,072.0 LINER; 8,493.9-14,814.3 ACID STIM; 12,230.0 SLOTS; 8,688.0-14,773.0 WHIPSTOCK - MONOBORE; 8,750.0 L1 Slotted Liner; 8,725.1- 10,812.0 INTERMEDIATE; 34.2-8,696.0 WLEG; 8,494.6 NIPPLE; 7,580.8 PACKER; 7,523.4 GAS LIFT; 7,419.0 SURFACE; 36.4-2,677.0 INJ VALVE; 2,189.2 NIPPLE; 2,189.2 CONDUCTOR; 37.0-114.0 HANGER; 31.9 WNS INJ KB-Grd (ft) 43.34 Rig Release Date 11/14/2006 CD4-214 ... TD Act Btm (ftKB) 15,072.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053700 Wellbore Status INJ Max Angle & MD Incl (°) 93.59 MD (ftKB) 9,890.12 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment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hoto document Photo document with photo documentation Wallace, Chris D (CED) From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, August 6, 2021 1:39 PM To: Wallace, Chris D (CED) Cc: Earhart, Will C; Smith, Travis T; Well Integrity Specialist CPF2 Subject: Alpine Injector CD4 -214 (PTD# 206-145) report of online in "Troubled" status Attachments: CD4-214.pdf; CD4 -214 90 Day TIO plot.pdf Chris - Alpine Injector CD4 -214 (PTD# 206-145) was reported to the AOGCC with an shallow surface casing leak on 27 July 21. The well was labeled as "Troubled" and was communicated that the well was to remain shut in until the surface casing repair was complete. This morning CPAI's WELL TRAK system reported the well to be online so an investigation into the current status occurred. The well was indeed online and was immediately shut in and freeze protected. After investigating, operations verified the well status in the IP21 program which was labeled as "Waivered" and the AnnComm system was labeled as "Troubled". A correction to the IP21 system has now been made and it is now labeled as "Troubled" in both systems. The WELL TRAK system worked as designed and identified the well at the first synchronization point which allowed the well to be identified and shut in within 24 hours of bringing the well online. During this time frame the SC leak did not yield any gas or fluids to surface. Operations has been notified that both systems should be checked prior to bringing a well on injection and a reminder was also sent to ensure both systems are labeled with the well's current status. Attached is a current 90 day TIO plot and well bore schematic. Please let myself or Travis Smith (907-350-9119) know if you have any questions or concerns. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELL,� TEAM Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Monday, July 26, 2021 3:08 PM To: Wallace, Chris D (CED) Subject: CRU Well CD4 -214 (PTD# 206-145) Surface Casing Leak Chris— Over the weekend, CRU Well CD4 -214 (PTD# 206-145) was found with a small surface casing leak. The leak appears to be very small, perhaps to gas only. The leak was identified with nitrogen diagnostics, no fluids were returned to surface. The well is currently shut-in, and passed additional diagnostics including wellhead packoff testing and an MITIA. CD4 -214 operates under NO 28.006 that allows water -only injection due to slow TAA while on gas service. We are currently evaluating repair options and will submit proper paperwork to pursue a path forward. In the meantime, the well will remain shut-in. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com MEMORANDUM TO: Jim Regg 'Ref, P.I. Supervisor 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 -214 COLVILLE RIV NAN-N CD4 -214 Src: Inspector Reviewed By: P.I. Supry li—— Comm Well Name COLVILLE RIV NAN-N CD4 -214 API Well Number 50-103-20537-00-00 Inspector Name: Lou Laubenstein Permit Number: 206-145-0 Inspection Date: 6/11/2021 Insp Num: mitLOL21061 1133 t 13 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4 -214 Type Inj w - TVD 5967 - Tubing 2063 2063 2063 2063 PTD 2061450 Type Test sPT'Test psi 3000 jfj 1390 3300 7 3200 3200 _ BBL Pumped: 1.5 BBL Returned: 1.5 OA 9 10 10 10 - Interval REQVAR _1P/F P Notes' MIT -IA to Maximum anticipated injection pressure per AIO 28.006 Thursday, June 17, 2021 Page 1 of I 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: WHIPSTOCK Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,072 feet None feet true vertical 6,280 feet None feet Effective Depth measured 8,750 feet 7,524 feet true vertical 6,157 feet 5,967 feet Perforation depth: feet feet Tubing (size, grade, measured and true vertical depth)4.5 ''L-80 8,507' MD 6,198' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER PREMIER PACKER 7,524' MD 5,968' TVD MD12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name:James Hayes Authorized Title: Contact Email:james.c.hayes@cop.com Contact Phone:(907) 265-6927 3. Address:P. O. Box 100360, Anchorage, Alaska 99510 50-103-20537-00 8. Well Name and Number:CRU CD4-214ADL 380077, ADL 384209, ADL 388902 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name:ConocoPhillips Alaska, Inc.4. Well Class Before Work: 5. Permit to Drill Number: 206-145 Packer measured true vertical Casing Length Size MD TVD N/A Colville River Field / Nanuq Oil Pool Plugs measured Junk measured Burst Collapse CONDUCTOR 77 feet 16 '' 114' MD 114' TVD INTERMEDIATE 8,662 feet 7 '' 8,696' MD 6210' TVD SURFACE 2,641 feet 9 5/8 ''2,677' MD 2365' TVD OPEN HOLE 258' 258 feet 6 1/8 '' 15,072' MD 6280' TVD LINER 6,320 feet 4 1/2 '' 14,814' MD 6284' TVD Measured depth: True Vertical depth: Water-Bbl Casing Pressure Tubing Pressure դ դ 475 880 2050 N/A Representative Daily Average Production or Injection Data Authorized Name: Authorized Signature with date: Senior Engineer: Senior Res. Engineer: 8688-14773 6210-6261 James Ohlinger CTD Team Leader Printed and Electronic Fracture Stimulation Data WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-588 դ դ 1070 363 1387 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Oil-Bbl Gas-Mcf GINJ SUSP SPLUG Gas Service Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:09 am, Apr 16, 2020 DSR-4/16/2020 RBDMS HEW 4/16/2020 VTL 4/17/20 CD4 -214 Final CTD Schematic ?" 9.3# IBTM from 8,506' RKB to surface ?" 9.3# L-80 liner from 14,814' RKB to surface DB Nipple @ 2,189' RKB (3.812" ID) co KBG-2-9 GLM @ 7,419' RKB ;r Premier Packer @ 7,523' RKB (3.875" ID) XN Nipple @ 7,581' RKB (milled out to 3.80") itor/WLEG No -Go @ 8,495' RKB (3.958" ID) _finer Setting Sleeve @ 8,494' RKB ar RS Sealing Nipple @8,507' RKB ;r Flex Lock DG Liner Hanger @ 8,511' RKB nating solid/slotted pipe from 8,688' to 14,773' RKB MD 4-1/2" Liner shoe KOP @ 8,750' @ 14,814' MD --------------------------------------- ---------------------------------------------- --------------------------------------- m m CD4 -214L1 TD @ 10,812' MD Slotted Liner 8,725-10,812' MD Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:CD4-214 claytg Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SBHP & Set Injection Valve post CTD 3/26/2020 CD4-214 claytg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD)… 114.0 Wt/Len (l… 68.00 Grade H-40 Top Thread Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.4 Set Depth (ftKB) 2,677.0 Set Depth (TVD)… 2,365.4 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC-M Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.2 Set Depth (ftKB) 8,696.0 Set Depth (TVD)… 6,210.4 Wt/Len (l… 26.00 Grade L-80 Top Thread Casing Description OPEN HOLE 258' OD (in) 6 1/8 ID (in)Top (ftKB) 14,814.3 Set Depth (ftKB) 15,072.0 Set Depth (TVD)… 6,279.7 Wt/Len (l…Grade Top Thread Casing Description LINER OD (in) 4 1/2 ID (in) 3.99 Top (ftKB) 8,493.9 Set Depth (ftKB) 14,814.3 Set Depth (TVD)… 6,263.8 Wt/Len (l… 12.60 Grade L-80 Top Thread SLHT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,493.9 6,197.1 86.14 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 8,506.9 6,198.0 86.17 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 8,510.7 6,198.2 86.18 HANGER BAKER 'DG' FLEX LOCK LINER HANGER 4.400 8,520.5 6,198.9 86.20 XO 5x4.5 CROSSOVER 5" x 4.5" 4.000 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 31.9 Set Depth (ft… 8,506.8 Set Depth (TVD) (… 6,198.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 31.931.90.00 HANGER FMC TUBING HANGER 4.500 2,189.2 1,983.2 37.45 NIPPLE DB NIPPLE 3.812 7,523.5 5,967.5 62.04 PACKER BAKER PREMIER PACKER 3.875 7,580.8 5,993.5 63.89 NIPPLE XN NIPPLE. 3.725 XN Nipple Milled to 3.80" 3.800 8,494.6 6,197.2 86.15 WLEG BAKER FLUTED WLEG ASSEMBLY 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 2,189.2 1,983.2 37.45 INJ VALVE 3.81" A-1 INJ VLV (S/N:HRS-44) ON 3.812" DB LOCK 3/26/2020 1.250 8,750.0 6,214.4 85.55 WHIPSTOCK - MONOBORE 4.5" monobore whipstock - BOT tray 180° ROHS 12/7/2019 1.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 8,688.0 14,773.0 6,209.8 6,260.9 11/10/2006 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Frac Summary Start Date 4/13/2007 Proppant Designed (lb)Proppant In Formation (lb) Stg # 1 Start Date 4/13/2007 Top Depth (ftKB) 12,230.0 Btm (ftKB) 14,820.0 Link to Fluid System Vol Clean (bbl)Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 7,419.0 5,915.3 CAMCO KBG-2 1 Gas Lift DMY BK 0.000 6/25/2019 Notes: General & Safety End Date Annotation 9/25/2017 Note: Waivered for Water-Only Injection due to TxIA on gas 7/24/2009 NOTE: ZONES NOT LOADED TO WELLVIEW YET 11/7/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 CD4-214, 4/14/2020 4:21:24 PM Vertical schematic (actual) OPEN HOLE 258'; 14,814.3- 15,072.0 LINER; 8,493.9-14,814.3 ACID STIM; 12,230.0 SLOTS; 8,688.0-14,773.0 WHIPSTOCK - MONOBORE; 8,750.0 L1 Slotted Liner; 8,725.1- 10,812.0 INTERMEDIATE; 34.2-8,696.0 WLEG; 8,494.6 NIPPLE; 7,580.8 PACKER; 7,523.4 GAS LIFT; 7,419.0 SURFACE; 36.4-2,677.0 INJ VALVE; 2,189.2 NIPPLE; 2,189.2 CONDUCTOR; 37.0-114.0 HANGER; 31.9 WNS INJ KB-Grd (ft) 43.34 Rig Release Date 11/14/2006 CD4-214 ... TD Act Btm (ftKB) 15,072.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053700 Wellbore Status INJ Max Angle & MD Incl (°) 93.59 MD (ftKB) 9,890.12 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: INJ VALVE Page 1/12 CD4-214 Report Printed: 4/15/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/4/2020 00:00 3/4/2020 07:00 7.00 MIRU MOVE MOB P Continue working rig down check list 0.0 0.0 3/4/2020 07:00 3/4/2020 08:00 1.00 MIRU MOVE MOB P Disconnect from highline power 0.0 0.0 3/4/2020 08:00 3/4/2020 14:00 6.00 MIRU MOVE MOB P PJSM, NES on location, Load shop and halfway house. Pull modules from well. Hook up cat to tail down to Ice pad. Jeep up modules. Hook cats up to pull modules to CD5 pad enterance 0.0 0.0 3/4/2020 14:00 3/5/2020 00:00 10.00 MIRU MOVE MOB P Leave CD5 pad for CD4 0.0 0.0 3/5/2020 00:00 3/5/2020 03:00 3.00 MIRU MOVE MOB P Boilers going down on pit module. Call out mechanic 0.0 0.0 3/5/2020 03:00 3/5/2020 04:30 1.50 MIRU MOVE MOB P Boilers stabilized. Continue move to CD4. Parted winch line on NES dozer. Call out mechanic to repair 0.0 0.0 3/5/2020 04:30 3/5/2020 05:30 1.00 MIRU MOVE MOB P Continue move 0.0 0.0 3/5/2020 05:30 3/5/2020 09:30 4.00 MIRU MOVE MOB P Crew change out, Continue move, arrive on CD4-Pad at 9AM, drop jeeps 0.0 0.0 3/5/2020 09:30 3/5/2020 11:00 1.50 MIRU MOVE MOB P Wait on hand-rail removal 0.0 0.0 3/5/2020 11:00 3/5/2020 14:00 3.00 MIRU MOVE MOB P Spot sub & pits over CD4-214 0.0 0.0 3/5/2020 14:00 3/5/2020 18:00 4.00 MIRU MOVE RURD P Begin RU, drop stair & landings, MU PUTZ, spot tiger-tand, MU hard-line 0.0 0.0 3/5/2020 18:00 3/5/2020 20:00 2.00 MIRU WHDBOP NUND P Continue RU checklist, grease tree valves & tango's, NU BOP's Rig Accepted: 3/5/2020 at 20:00. 0.0 0.0 3/5/2020 20:00 3/5/2020 20:54 0.90 MIRU WHDBOP RURD P Complete RU checklist, clear rig floor, unlock injector 0.0 0.0 3/5/2020 20:54 3/5/2020 23:24 2.50 MIRU WHDBOP CTOP P Cut off CTC, protect e-line end, take on sea-water, stab on, energize koomey 0.0 0.0 3/5/2020 23:24 3/6/2020 00:00 0.60 MIRU WHDBOP CTOP P Initiate pumping at low rate and check for leaks. Packoff leaking. Change out packoff and energizers. Confirm old packoffs are 2 3/8" ID Bring on pumps and check new packoff - good. Unable to reverse circulate at 1,700 psi. Troubleshoot. 0.0 0.0 3/6/2020 00:00 3/6/2020 00:12 0.20 MIRU WHDBOP CTOP T Continue to troubleshoot circ path. Pop off injector and check eline end. Suspect ice in reel, apply max heat to reel area. Reverse circulate at .28 bpm, pipe is clear. 0.0 0.0 3/6/2020 00:12 3/6/2020 01:12 1.00 MIRU WHDBOP CTOP P Reverse circulate at minimum rate to warm CT. Pump slack back 3 times ramping up to 5.2 bpm. 0.0 0.0 3/6/2020 01:12 3/6/2020 05:00 3.80 MIRU WHDBOP CTOP P Cut coil. 1,230' of 3,000' 0.0 0.0 3/6/2020 05:00 3/6/2020 08:36 3.60 MIRU WHDBOP CTOP P Continue cutting coil. Cut 3000' 0.0 0.0 3/6/2020 08:36 3/6/2020 09:00 0.40 MIRU WHDBOP CTOP P Rig down CT cutter. Clear floor. Prep to pump slack 0.0 0.0 3/6/2020 09:00 3/6/2020 10:00 1.00 MIRU WHDBOP CTOP P Boot E-line, Stab on injector. revese circulate coil, Surge 3 times to 4800 PSI 0.0 0.0 Rig: NABORS CDR3-AC Page 2/12 CD4-214 Report Printed: 4/15/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/6/2020 10:00 3/6/2020 11:12 1.20 MIRU WHDBOP CTOP P Test wire, Make up CTC, Pull test to 35K 0.0 0.0 3/6/2020 11:12 3/6/2020 13:48 2.60 MIRU WHDBOP CTOP P Head up E-line, trouble shoot e-line 0.0 0.0 3/6/2020 13:48 3/6/2020 14:36 0.80 MIRU WHDBOP CTOP P Pressure test CTC 4000 PSI. Unstab injector, Skid back and install night cap 0.0 0.0 3/6/2020 14:36 3/6/2020 15:48 1.20 MIRU WHDBOP RURD P Prep for initial BOPE test, Obtain shell test 0.0 0.0 3/6/2020 15:48 3/6/2020 16:00 0.20 MIRU WHDBOP BOPE P Start full BOPE test. Test witness waived by Matt Herrera, AOGCC 250 psi low / 3800 psi high Test 1. Swab 2, fail to hold pressure on swab 2, carry on w/ test 0.0 0.0 3/6/2020 16:00 3/6/2020 20:30 4.50 MIRU WHDBOP BOPE P Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Bravo 5, and Tango 1 – install TIW test joint Test 7. Lower 2” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2” pipe slip rams, Bravo 6, & 8 Test 10. Bravo 7 – swap out 2” test joint for 2-3/8” Test 11. 2-3/8” pipe slip rams, TIW#2 – check N2 levels, swap to 2” test joint Test 12. Draw down accumulator Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Tested all gas detectors, pits, cellar, Verified flow alarms - PVT Regrease swab 2, retest, good 0.0 0.0 3/6/2020 20:30 3/6/2020 21:36 1.10 MIRU WHDBOP CTOP P MU nozzle, fluid pack CT and pump slack forward at 4 bpm. 0.0 0.0 3/6/2020 21:36 3/7/2020 00:00 2.40 MIRU WHDBOP PRTS P Pressure test inner reel valve, PDL's, and tiger tank line 0.0 0.0 3/7/2020 00:00 3/7/2020 00:18 0.30 MIRU WHDBOP PRTS P Complete PDL presure test 0.0 0.0 3/7/2020 00:18 3/7/2020 02:00 1.70 MIRU WHDBOP PRTS P Attempt to open master valve, unable, pressure to 1200 psi above master, no good, call out DSO & valve crew and open master valve. Clear rig floor, PJSM, pre-load DS PDL 0.0 0.0 3/7/2020 02:00 3/7/2020 06:00 4.00 MIRU RPEQPT WAIT T Wait on replacement accumulator motor from Prudhoe, Change out motor and contacts 0.0 0.0 3/7/2020 06:00 3/7/2020 08:06 2.10 PROD1 RPEQPT PULD P Crew change, Run valve check list. PJSM. PD BHA #1 whipstock from pre loaded PDL. Make up to coil and surfae test tools 0.0 78.5 3/7/2020 08:06 3/7/2020 10:42 2.60 PROD1 RPEQPT TRIP P RIH BHA #1, EDC open pumping .6 BPM seawater 78.5 7,450.0 Rig: NABORS CDR3-AC Page 3/12 CD4-214 Report Printed: 4/15/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/7/2020 10:42 3/7/2020 11:18 0.60 PROD1 RPEQPT DLOG P Start logging down 5 FPM. Unable to achieve tie in log. 7,450.0 7,611.0 3/7/2020 11:18 3/7/2020 11:30 0.20 PROD1 RPEQPT TRIP P RIH to log deeper interval 7,611.0 8,638.0 3/7/2020 11:30 3/7/2020 12:06 0.60 PROD1 RPEQPT DLOG P Start logging down, Call -5' correction. Geo / MWD not confident. Study log 8,638.0 8,745.0 3/7/2020 12:06 3/7/2020 12:24 0.30 PROD1 RPEQPT TRIP P PUH to relog upper interval, PUW=45K 8,745.0 7,500.0 3/7/2020 12:24 3/7/2020 13:06 0.70 PROD1 RPEQPT DLOG P 7500', Log down. Call -4' correction 7,500.0 7,669.2 3/7/2020 13:06 3/7/2020 13:42 0.60 PROD1 RPEQPT TRIP P RIH 7,669.2 8,650.0 3/7/2020 13:42 3/7/2020 14:06 0.40 PROD1 RPEQPT DLOG P Run CCL log 8650 to 8850, Evaluate log, Closest 4 1/2" liner collar is @ 8769' 8,650.0 8,850.0 3/7/2020 14:06 3/7/2020 14:12 0.10 PROD1 RPEQPT TRIP P PUH to setting depth, PUW=43K 8,850.0 8,762.0 3/7/2020 14:12 3/7/2020 14:24 0.20 PROD1 RPEQPT OTHR P At set depth, 8762, TOWS=8750. Orient to 180°. Close EDC. Bring pumps online. .34 BPM See tool shift @ 3350. Whipstock set. Set down 5.1K. PUH to 8,762.0 8,740.0 3/7/2020 14:24 3/7/2020 15:06 0.70 PROD1 RPEQPT CIRC P Displace well to duo vis light 8,740.0 8,740.0 3/7/2020 15:06 3/7/2020 16:42 1.60 PROD1 RPEQPT TRIP P POOH, PUW=41K 8,740.0 65.0 3/7/2020 16:42 3/7/2020 17:36 0.90 PROD1 RPEQPT PULD P PUD whipstock setting BHA 65.0 0.0 3/7/2020 17:36 3/7/2020 18:30 0.90 PROD1 WHPST PULD P Crew change. PJSM for PU milling BHA 0.0 0.0 3/7/2020 18:30 3/7/2020 19:18 0.80 PROD1 WHPST PULD P PU milling BHA 0.0 80.0 3/7/2020 19:18 3/7/2020 20:42 1.40 PROD1 WHPST TRIP P RIH 80.0 7,500.0 3/7/2020 20:42 3/7/2020 21:12 0.50 PROD1 WHPST DLOG P Tie in. 7,500' to 7,666' +10.5' correction 7,500.0 7,666.0 3/7/2020 21:12 3/7/2020 21:36 0.40 PROD1 WHPST TRIP P Close EDC and RIH. Dry tag WS at 8,750' PU wt 40K 7,666.0 8,750.0 3/7/2020 21:36 3/8/2020 00:00 2.40 PROD1 WHPST WPST P Bring on pumps 2.8 bpm in / out Free spin 2,800 psi tag at 8,750.2' begin time milling at 1ft/ hr. switch from manual to auto drill at 8,751.08' 8,750.0 8,752.0 3/8/2020 00:00 3/8/2020 03:24 3.40 PROD1 WHPST WPST P Continue time milling window. Call BOW 8,755.3' based on milling parameters 8,752.0 8,755.3 3/8/2020 03:24 3/8/2020 07:48 4.40 PROD1 WHPST WPST P Time mill rate hole to 8,754.8' to 8759.5 string reamer all out 8,755.0 8,759.5 3/8/2020 07:48 3/8/2020 11:00 3.20 PROD1 WHPST WPST P Mill rathole @ 5 FPM, 2.81 BPM @ 2856 PSI FS, BHP=3803 8,759.5 8,775.0 3/8/2020 11:00 3/8/2020 12:06 1.10 PROD1 WHPST WPST P Ream up / down 2 passes at as drilled TF, PUW=46K up to 8766 8,775.0 8,766.0 3/8/2020 12:06 3/8/2020 14:48 2.70 PROD1 WHPST WPST P Make down reaming passes @ 0°, 30R, 150R, 150L, 30L, 8,766.0 8,744.0 3/8/2020 14:48 3/8/2020 14:54 0.10 PROD1 WHPST WPST P Dry drift window 8744 to 8775 clean, PUW=42K 8,744.0 8,738.0 Rig: NABORS CDR3-AC set depth, 8762, TOW S=8750. Orient to 180°. Close EDC. Bring pumps online. .34 BPM See tool shift @ 3350. Whipstock set. Set down 5.1K. PUH to MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO. Jim ReggDATE: Monday, April 6, 2020 P.1. Supervisor L 4h3I �� SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD4 -214 FROM: Austin McLeod COLVILLE RIV HAWN C134-214 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry -J-��r— NON -CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-N CIX -214 API Well Number 50-103-20537-00-00 Inspector Name: Austin McLeod Permit Number: 206.145-0 Inspection Date: 4/5/2020 Insp Num: mitsAM200405183608 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well cw-214 TYPe Inj w 'TVD 5967 - Tubing UI-, 1319 134 ilio PPD 2061450 1 Type Test] 3PTTes4psi 1500 - IA 300 1 2010 - lvso 1975 - BBL Pumped: 1.3 BBL Returned: 12 OA 1110 - 120 120 120 Interval I OTHER P/F P Notes: post initial injection per PTD # 2200180 for CD4 -214L I. Monday, April 6, 2020 Page I of I THE STATE ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger CTD Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Pool, CD4 -214 Permit to Drill Number: 206-145 Sundry Number: 319-588 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Moir: 907.279.1433 Fax: 907.276.7542 www.aogcc.cilaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, a VJece DATED this"5 day of January, 2020. 3BDMS-` L/'1AN 0 6 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n ACL` 9s 9an DEC 31 2019 9'7-S /! 3 (2o A®CCC 1. Type of Request: Abandon ❑ Plug Perforations p Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ �1 X- Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing f F T - Other: Whlos ock n 2. Operator Name. 4. Current Well Class: 5. Permit to Drill Number: H ICL XN ConowPhillips Alaska Inc Exploratory ❑ Development 206-145 �—./ 6. API Number: Stratigraphic ❑ Service NCJ 3. Address: PO Box 100360, Anchorage AK 99510 50-103-20537-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A CD4 -214 Will planned perforations require a spacing exception? Yes ❑ No ❑Q 9. Property Designation (Lease Number): , 10. Field/Pool(s): V% ADL 3080077, 384209, 388902 Colville River Filed/ Nanuq Oil Pool . 11. j, Z PRESENT WELL CONDITION SUMMARY Tool Deepth.M,rD�(ft): TotaallDDeeptth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 15Z -7j -o�» �"�Tr,26tt'� 8,750' 6,157' 21184 N/A N/A Casing j ZCLength Size MD TVD Burst Collapse Structural Conductor 82' 16" 114' 114' Surface 2,645' 9-5/8" 2,677' 2,365' Production 8,664' 7" 8,696' 6,210' Liner 6,320' 4-1/2" 14,814' 161264' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,688'-14,773' 6,210'-6,261' 4/1/2" L-80 8,507' Packers and SSSV Type: Baker Premier Packers and SSSV MD (ft) and TVD (ft): 7,524' MD / 5,968' TVD 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑✓ ' 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/30/2019 OIL ❑ WINJ ❑✓ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger es James Ha Contact Name: Y Authorized Title: CTD Team Lead Contact Email: James.C.Ha es CO .COm Contact Phone: 265-6927 x.240 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify eTminission so that a representative may witness Sundry Number: C'Dk3/ - Plug Integrity ❑ BOP Test C9' Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4-'� 3J/,s < A&,,"ks l`-3BDMS AN 0 6 2020 Post Initial Injection MIT Req'd? Yes ❑ No /y Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY 1r � 1^,� Approved by: COMMISSIONER THE COMMISSION Date: /-Z-- .PC Form 10-403 Revised 4/2017 Approved applicatioQjsRd forte IpoptFr6;k[he date of approval. Submit Form and Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 31, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits application to millout XN nipple in CD4 -214 (PTD# 206-145) to allow CTD operations to drill a single lateral out of the CD4 -214 using the coiled tubing drilling rig, Nabors CDR3-AC. A sundry application is attached to millout the XN nipple in CD4 -214 to allow a lateral to be drilled. Attached to this application are the following documents: — 10-403 Sundry Application for CD4 -214 — Operations Summary in support of the 10-403 Sundry Application — Proposed CTD Schematic — Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-265-6927. Sincerely, Vz L James Hayes ConocoPhillips Alaska Coiled Tubing Drilling Engineer CD4 -214 CTD Summary for Whipstock Sundry (10-403) Summary of Operations: CD4 -214 is a Nanuq injector equipped with 4-1/2" tubing and 7" production casing. The CTD sidetrack will utilize one lateral to target Nanuq to the Northeast of CD4 -214. This lateral will increase sweep injection area in the Nanuq for other wells Prior to CTD operations, service coil will need to move in and millout the XN at 7,581' R 3.80". Once the nipple is milled out a 4-1/2" though tubing whipstock can be set at 8,75 for a high side exit on rig. This lateral will be completed with 2-7/8" slotted liner from TD the final liner top located inside the 4-1/2" tubing tail. Using the maximum formation pressure in the area of 3,714 psi in CD4 -214, the maximum potential surface pressure in CD4 -214, assuming a gas gradient of 0.1 psi/ft, would be 3,092 psi. L� BOP Test Pressure= 3,500 psi CTD Drill and Complete CD4 -214 Lateral: March 2020 �O Pre -CTD Work 1. RU Service Coil: RIH & mill out XN nipple at 7,581' RKB to 3.80" 2. Prep site for Nabors CDR3-AC. Rig Work /1 bF03 _ A 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Set whipstock & mill window 3. CD4 -214L1 Sidetrack (Nanuq — Northeast) a. Set top of whipstock at 8,750' RKB b. Mill 3.80" window at 8,750' RKB. c. Drill 3" bi-center lateral to TD of 13,325' MD. {t d. Run 2%" slotted liner with LTP from TD up to 8,740' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. N- rhi Y Z J�cst-Riq Work 1. Return to production Page 1 of 1 12/31/2019 WNS INJ WELLNAME CD4 -214 WELLBORE CD4 -214 ConoCOPflillips Well Att ibutes Max Angle & MD TD Flela Name We"here Alugave Walloons Brarm ncI l°I MD( BI Pnt Bim lttKB) A1aalW. MIC. NANUO 501 M2053700 [NJ IP3.59 19,690.12 15,0720 Comment HRS prand Annctatlon Entl WR KB�G,d gg Rip Release Date Jorge $SSV'. WRDP Last WO: 43.34 11/14/2006 CpG319, lyToce1e11010JAM ILast Tag "grim, yousi wamp Annotainn DIMEMMIft8) Ena pale W.'"i be, MM By Last Tag: CD4 -214 Incest., Last Rev Reason Mmlaean End Dine yMpon. Last Mctl By Rev Reason: CTO Prep Drift B BEHR 1111712019 CD4 -214 Cut" Casing Suilgs Casing Develop- OR (In) in (in) TopinKBl set Depth MKS] Sel peptnlrvpl l... WI/Len IL.. Grafts Top rnread CONDUCTOR 16 1525 3>0 114.0 1114.0 168 I 00 [H.4G Casing peoription OD (177) ID la TopinKBl Set Depth abbig Bat Depth TRA.) T.. ei Ill. Grad. TaPThread SURFACE 95/8 8.83 364 2,677.0 2,365.4 4000 L-80 BTC -M L Oescrlpres Do (in) 1. pre Top MKS) Set Depth Mi Set Depth TAD) p.. M C(I Grade Topnewd coNDOcroa; al.0wap Tloj INTERMEDIATE 7 628 34.2 8,6960 6210.4 26.00 L-80 Lasing Mrcrlaan .0 (in)ID(in) Tap gKB) Set Depth InKB) set Depth IND) L. VWLen 11 Grana Top Thr. OPEN HOLE 258' 61/8 14,814.3 15,072.0 62797 CesNg DesaipHon OO(inl Ip pin) Top RMS) Sall Depth InKB) set Depth Drop) I... WULen(I... Gentle Top Thread wwLE 2,1@12 be2,,esz LINER 41/2 399 8,4939 14,814.3 6263.8 12,60 L-80 SLHT Liner Details ominal m Top IkKD) Top ITVp)1nKB1 Tapinel l'1 Item Oes Cam (in) 8493.9 6,197.1 86.14 SLEEVE BAKER -HR' LINER SETTING SLEEVE 4.420 8,5069 6,198.0 86.17 NIPPLE eAKER'HIS' RACKOFF SEAL NIPPLE 4,250 60REACE, 0s 4-16770 8,510.7 6,198.2 86.18 HANGER BAKER LC FLEX LOCK LINER HANGER 4.400 8,520.5 6198.9 65.20 1 XO 5x4.5 CROSSOVER FX4,F 4.000 Tubing Strings GAS LIFT, ].41ap ,"stop Descriptionstring Max.. IDlml ropinnR) set p.pih n... Sat OapinINO11n.. wglem crane Top Connection TUBING d V2 3.96 31.9 8,506.8 6.1980 12.fi0 L-80 Completion Details mp Dri Nominal ToplftKB) @KSI rap lna1l°1 Dem Do. sem In Dol 31.9 31.9 0.00 HANDLE FMC TUBINGHANGER 4500 PACKER, T,52i.< 2,189.2 1,983.2 37.45 NIPPLE OB NIPPLE 3.812 7,5235 5.987.5 62.04 PACKER BAKER PREMIER PACKER 3.875 7,580.8 5,993.5 63.89 NIPPLE XN NIPPLE 3725 84946 6,1972 86.15 AILED BAKERFLUTEOWLEG ASSEMBLY 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, flab, etC j ro"001 Top Ind lop In KB) (tIKB (°) Des Co. anti Ip (in) 2,189.2 I .983.2 I ]d51NJ VALVE 3.81"A-11NJ VLV (SIN H55-15])) 11/17/2019 1.250 Perforations $ Slots .hot Top To,.) elm(rvp) [hens Papal elm IM1KB) (ttHBI group) B) Llnkna al2o pain (s Aatsll, Type Com 8,668.0 14,773.0 6.209.8 6,2609 11/1042006 32.0 SLOTS Alternating solid/slolledpipe - 0.125" 2.5" @ 4 droonperantial adjacent IN,ERMEDIAr E; ]I]- rows, T C¢Mers staggered B,NE b 18 deg, 3non-Blotted ends a A Frac Summary Pel Start Dole Propwnt...... Npel prapwnl In Formation pr) 4/1312007 slptl atar[Oah Top Oterrible) erig ) Link to Fluid System volc,ean (Ed) Vol slmrylbbg 1 d/13200> 1$230.0 14820.0 l Mandrel Inserts sl al TopIND) Valve Lald, Pon Size TRO Run o Tap(XKB) MKS) Make MMeI OOIN) Sery Tyw Tyw Iln) (wi) Run.a- Com ],419.0 5.915.3 CAMCO NBG-2 1 Gas Lift DMV BK 0000 62512019 es: General 8 Safety End Dale Annousen 017 Note'. Weiverei for Water -Only Injection due to TJA on gas 7 09 NOTE: ZONES NOT LOADED TO WELLVIEW VET 110 NOTE'. VIEW SCHEMATIC w/Alaska Scrematic9.0 SLOTS; s,6B6b14M O. e, r- I AMD STM; 12 gale I I.S.E. ,Ae3.e.Lalas 0v6N xoLE 26a': 14.eua�" „ ts.arza A QC VI �v uN N 0 � I u: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim RQ / C(1 -,,— 7 DATE: Monday, July 15, 2019 P.I. Supervisor SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD4 -214 FROM: LOU Laubenstein COLVILLE RIV NAN-N CD4 -214 Petroleum Inspector Src: Inspector Reviewed By: P.1. Supry Q�L NON -CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-N C134-214 API Well Number 50-103-20537-00-00 Inspector Name: Lou Laubenstein Permit Number: 206-145-0 Inspection Date: 7/2/2019 ' Insp Num: mitLOL190704080354 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Mitt Well CUA -214 Type Inj ti' `',TVD 5962ITUhing 2025 - 2025. 2020 2020' — -- - PTD 1 2061450 -- 'I'ypQ Test SPT 'Test psi 3000 IA 818 3300 �.00 3240 3330 BBL Pumped 2.1 BBL Returned: 1.9— OA 317 345 342 337 Interval REQVAR P/F P Notes: (Retest) MIT -1A to the Maximum anticipated injection pressure per AIO 28.006 Monday, July 15, 2019 Pagel of I Wallace, Chris D (GED) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday, June 25, 2019 5:01 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: CRU CD4 -214 (PTD# 206-145) Report of Failed MITIA Attachments: CD4 -214 MIT CRU 06-25-2019.xlsx Hi Chris, CRU injector CD4 -214 (PTD# 206-145) is waivered under AIO 28.006 for water injection only due to known TxIA communication on gas injection. This well failed its state -witnessed MIT -IA on 6/20/2019. The well was shut in, secured, then circulated to clean fluid. The well achieved a passing MIT -IA to 3300 psi after circulating the gas -entrained fluid from the IA (likely from gas injection before the well was waivered to water—only). We intend to return this well to water injection only then will schedule another witnessed MIT -IA to fulfill the waiver compliance testing requirements. Attached is the non -witnessed MIT -IA 10-426 form. Please let us know if you have any questions or disagree with this plan. Sincerely, scwa, carUs1&('T1E'e444,0 /2achel Kai tk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549C@cop.com Cell: 907-331-7514 I sara.e.carlisleC@cop.com From: NSK Well Integrity Supv CPF3 and WNS Sent: Friday, June 21, 2019 7:39 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: CRU CD4 -214 (PTD# 206-145) Report of Failed MITIA Hi Chris, CRU injector CD4 -214 (PTD# 206-145) is waivered under NO 28.006 for water injection only due to known TxIA communication on gas injection. This well failed its state -witnessed MIT -IA last night. The well has been SI and freeze protected and will be secured as soon as possible. We will circulate the IA to clean fluids and progress diagnostics and repair. We suspect there may be residual gas in the IA from when it was previously leaking on gas injection. A 90 -day TIO trend and 10-426 are attached. Please let us know if you have any questions or disagree with this plan. Sincerely, Sara-CcwUg&(ReA vv)/12a Ae.,Kautk Wallace, Chris D (CED) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Friday, June 21, 2019 7:39 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CRU CD4 -214 (PTD# 206-1451 Report of Failed MITIA Attachments: CD4 -214 AnnComm Surveillance TIO 6.21.19.pdf, MIT CRU CD4 Pad (2of3) 06-20-19 .xlsx Hi Chris, CRU injector CD4 -214 (PTD# 206-145) is waivered under AIO 28.006 for water injection only due to known TxIA communication on gas injection. This well failed its state -witnessed MIT -IA last night. The well has been SI and freeze protected and will be secured as soon as possible. We will circulate the IA to clean fluids and progress diagnostics and repair. We suspect there may be residual gas in the IA from when it was previously leaking on gas injection. A 90 -day TIO trend and 10-426 are attached. Please let us know if you have any questions or disagree with this plan. Sincerely, Scwa.CCWUSZ i Nwa w) / Ra.chob Ka utk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop.co Cell: 907-331-7514 1 Sara a carlisle0cop com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I DATE: Tuesday, July 2, 2019 [)� q P.I. Supervisor % �1 Ill C" SUBJECT: Mechanical Integrity Tests ( ConocoPbillips Alaska, Inc. CD4 -214 FROM: Adam Earl COLVILLE RIV NAN-N CD4 -214 Petroleum Inspector Sre: Inspector Reviewed By: P.I. SuprvyTPJ2— NON -CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-N CD4 -214 API Well Number 50-103-20537-00-00 Inspector Name: Adam Earl InSp Num: mitAGE190623145504 Permit Number: 206-145.0 Inspection Date: 6/20/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4 -214 Tppc Inj 'A TVD 5962 Tubing sotszoza�i zozz - 023 00; PTD ; 2061450 Type Test ,"] Tett psi 2900 IA 1000 3300, 2950 - 2e50 - 2530 _ BBL Pumped: 12 - BBL Returned: OA 467 543 . 528 513. 505 -- -- - — -------- — --I Interval RLQVAR P/F F Notes: MITIA tested as per AIO 28.006 to MAID. Test failed and a BBL returned was not recorded as they wanted to leave pressure on for a bit while the DHD group went to trouble shooting. Tuesday, July 2, 2019 Page 1 of I • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday, September 18, 2017 12:07 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: CD4-214 (PTD 206-145) IA pressurization Chris, CD4-214(PTD 206-145) is currently on a 30-day monitoring period of MI injection having completed a successfully completed a 30-day monitoring period on water injection. During the water injection monitoring period,tubing and inner casing packoff tests were performed and passed. A diagnostic MITIA to 3300 psi passed as well. The IA pressure has shown a building trend during the MI injection monitoring period, however. The well has been shut- in and our intent is to WAG the well back to water injection and submit an application for Administrative Approval for water-only injection service. Please let us know if you have any questions or disagree with this plan. Travis From: NSK Well Integrity Supv CPF3 and WNS Sent:Sunday,July 09, 2017 12:11 PM .•Wallace, Chris D (DOA)<chris.wallace@alaska.gov> r 1 ci Cc:Se ►- , R.Tyler<R.Tyler.Senden@conocophillips.com> "Htit® Subject:CD4-- (PTD 206-145) IA pressurization Chris, CD4-214(PTD 206-145) is an WAG i sector currently injecting MI. This morning the IA experienced rapid re- pressurization following a bleed. The p • is to WAG the well to water as soon as operationally possible. After the well reaches stabilized water injection, DHD wil -rform the typical suite of diagnostics including a MITIA and packoff tests. A series of IA bleeds will be conducted pr to performing an extended IA DDT. Providing the MITIA passes,we plan to then monitor the well on water injection for 0-day period. If the well shows integrity during the water injection monitor, CPAI plans to put the well back on MI Vection for a 30-day monitor to confirm if TxIA communication on MI is present. If TxIA on MI is confirmed, CPAI intends to ,G the well back to water and submit an AA application for water only injection. Please let us know if you have any quest'• s or disagree with this plan. Attached is a 90-day TIO plot. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, July 9, 2017 12:11 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: CD4-214 (PTD 206-145) IA pressurization Attachments: CD4-214 90-day TIO plot.docx Chris, CD4-214 (PTD 206-145) is an WAG injector currently injecting MI. This morning the IA experienced rapid re- pressurization following a bleed. The plan is to WAG the well to water as soon as operationally possible. After the well reaches stabilized water injection, DHD will perform the typical suite of diagnostics including a MITIA and packoff tests. A series of IA bleeds will be conducted prior to performing an extended IA DDT. Providing the MITIA passes, we plan to then monitor the well on water injection for a 30-day period. If the well shows integrity during the water injection monitor, CPAI plans to put the well back on MI injection for a 30-day monitor to confirm if TxIA communication on MI is present. If TxIA on MI is confirmed, CPAI intends to WAG the well back to water and submit an AA application for water only injection. Please let us know if you have any questions or disagree with this plan. Attached is a 90-day TIO plot. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED JUL 2 7 2017, • 0 w u 5 u.1 ol LT • z u, et — LL u ----, ,,1 u., 0. LL '.- 0 ,, — _8 LT I IL I O ° — A E c _ Ul LJ CC ,...-- O. 1 CA ,, 01 .1:: 6., C " J" WILI ) .—. 36ap L .."--, ED 000 Cr IT er, u.• Tr V) 01 • CJ — CI • , • • CO F_ 8 r_ 1 I 0 ,..',. - 0 c fa ; ill Z = en c , r.... , ,Eo = , E [ , 1 -t - $ o ! 0 ... iz as , 1 1 i t c = c 1 4 1 t.-- v.. ... o cs.'5.4 o R4 8 a C4 ii, — - u 4 2i,..1.- 11111 R lila. 1 , :1-.. , ' I ' ll ' 8 8 8 8 8 8 8 ° ° BHHEIBocioc,:y. coov .2eVa 9 isdil f! 2 z . >••-0 rid iii.fl EWA 7 V)0 LIJ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg cRp6117 / DATE: Tuesday,June 16,2015 P.I.Supervisor `J S SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-214 FROM: Johnnie Hill COLVILLE RIV NAN-N CD4-214 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JC2— NON-CONFIDENTIAL B2NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-N CD4-214 API Well Number 50-103-20537-00-00 Inspector Name: Johnnie Hill Permit Number: 206-145-0 Inspection Date: 6/12/2015 Insp Num: mitJWHl50613155332 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-214 - Type Inj W TVD 5967 - Tubing 2615 - 2612 - 2609 • 2608 - I PTD 2061450 - 1Type Test SPT Test psi 1500 IA 701 2114 - 2076 - 2074 Interval TST P/F P OA o 95 85 83 11 Notes: 1.7 bbls diesel used SCIwwE© 'UL 1 3 2015 Tuesday,June 16,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 05, 2011 TO: Jim Regg P.I. Supervisor ' `P / 7 � 14(1( SUBJECT: Mechanical Integrity Tests t CONOCOPHILLIPS ALASKA INC CD4 -214 FROM: Matt Herrera COLVILLE RIV NAN -N CD4 -214 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry - - NON- CONFIDENTIAL Comm Well Name: COLVILLE RIV NAN -N CD4 -214 API Well Number: 50 -103- 20537 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFH110701084532 Permit Number: 206 -145 -0 Inspection Date: 6/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well TCD4 -214 ` Type Inj. W TVD 5967 " IA 100 2140 • 2102 1 2092 - P.T.D 2061450 - TypeTest i SPT Test psi 1500 , OA 380 393 394 Interval 4YRTST P/F P - Tubing 1313 1316 1315 1313 Notes: IA tested to 2100 psi 1.6 BBL's ' ,,', , a,VN ; JUL 1 b ; Tuesday, July 05, 2011 Page 1 of 1 r~ u ~~ ~~Q~~ 0~ ada~~(Q /~..aw_,.~o~. Scott Reed ,~ Alpine Production Engineer ~ , , ~} Y~~., fl;; ~4 ~ ~` rjC!'s~, ConocoPhillips Alaska, Inc. '~'''"~'"~ ~'~ ` ~ , ,~ P.O. Box 100360 I Anchorage, AK 99510 (~~ - " ~~ Re: Colville River Field, Nanuq Oil Pool, CD4-214 Sundry Number: 310-246 Dear Mr. Reed: 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. 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 reconsideration. A request for reconsideration 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. 3~ DATED this ` day of August, 2010. Encl. Sincerely, Daniel T. Seamount, Jr. Chair ~ tt7 ~'p STATE OF ALASKA ilv ~ ;,tip ALASK~L AND GAS CONSERVATION COMMISS• APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon "` Rug for Redrill ~', Perforate New Pool Repair w ell ~ Change Approved Program ~` Suspend r Rug Perforations ~ Perforate Pull Tubing ~"" o Time Extension ~'""' l P ~ ~~ Operational Shutdow n ~ Re-enter Susp. Well ~ Stimulate Atter casing J°` s c o5 ~ Other: convert to Injector ~"~ . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~'"°" 206-145 3. Address: Stratgraphic ~ Service "" • API Number. • P. O. Box 100360, Anchorage, Alaska 99510 50-103-20537-00 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? Y2S N o ~', CD4-214 ' 9. Property Designation: ~ , ' 10. Field/Pool(s): ~ ADL 380077, 384209, 388902 Colville River Field / Nanuq Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15072 6280 15072' 6280' Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 114' 114' SURFACE 2641 9.625 2677' 2365' INTERMEDIATE 8662 7 8696' 6210' LINER 6320 4.5 14814' 6264' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner from 8688'-14773' 6210'-6260' 4.5 L-80 8507' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER -PACKER -BAKER PREMIER MD= 7523 TVD= 5967 DB nipple MD= 2189 TVD=1982 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: ~ Detailed Operations Program ~ BOP Sketch ~ Exploratory ~ Development ~` Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/16/2010 Oil Gas "' WDSPL Suspended "";` 16. verbal Approval: Date: WINJ ~` GINJ WAGL ~' Abandoned Commission Representative: GSTOR SPLUG J'~''; 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Reed @ 265-6548 Printed Name Scott Reed Title: Alpine Production Engineer Signature Phone: 265-6548 Date ~~ mmi I Sundry Number:3~~ -~~ Conditions of approval: Notify Commission so that a representative may witness f' !o-/o ~ ~ "` Plug Integrity ~°" BOP Test Mechanical Integrity Test Location Clearance j rr ~~~E~~Q Other: ~, ~.~+-: ~ ~~ 2010 Subsequent Form Required: /D_ ~/Q ~~ ` ~~~ak8 ~ ~S~y ~,, ~I$SIOtI j~)r~)r~~g0 APPROVED BY Approved by: ~/~ ~ O COMMISSIONER THE COMMISSION Date: Form 10-403 ReBi~LKN1~0 a~ ~-6 ~' ~ ~ ~ A {.. X90 ~a Submit in Duplicate ~~~/ `~/v ~~ildC(3~1~~~i~5 t „jai, i'r-xc. ,.:. V'!BH COnfg_ -CDg-'214, 1215/21 Schematic Attu HANGER. 32- e , CONDUCTOR. __ 34-114 VALVE. 2.189 NIPPLE. 2,989 -- SURFACE,_- 36-2,677 GAS LIFT, ],499- PACKER. 7,523 - NIPPLE, 7,581 - WLEG, 8 495 - SLOTS, - e.6s6-1a,n3 ACID STIM, 12.230 . WNS CD4-214 Well Attribute s ~ Max ngle & MD TD _ A Wellbore APVUWI Fieltl Name _ __ Well Status Inc! (°) _ _ MD (HKB) Act Btm (ftK8) 501 0320 5 3 700 NANUO I ( INJ 93.59 9,890.12 16 072 0 Comment 825 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date SSSV: WRDP I 0 7/1/2009 (Last WO: ' 43.34 11/14/2006_ ~ End Date Annotation (Depth (ftK8) Annotation Last Mod ... End Date Last Tag: ( ( Rev Reason: RESET INJ VLV Imosbor 11/7!2009 CasingStrin s __ Casing Description String 0... String ID ... Top (ftK8) _ Set Depth (f_. Set Depth (ND) .. string wt... string ... string Top rhrd ~ iCONDUC(OR 16 15 250 34.0 114.0 114.0 H-00 Casin Descri g ption Strin 0... Shin ID ... 9 9 To ftK8 P( 1 Set De th L.. P ( Sel De th ND P ( ) ... iStrin Wt._Strin 'String Top Thrd 9 9 .. SURFACE 9 518 8.835 36.4 2,677.0 2,365.4 i 40.00 L-80 BTC-M Casing Description String 0... .String ID ... Top (ftK8) >. Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd INTERMEDIATE 7 ~. 6.276 34.2 8,696.0 6,2104 26.00 L-80 Casin Descri lion P i ' _ String O._ ('String lD ... Top (ftK8) Set Depth (f... Set Depth(ND)... String Nlt... String... String TOp Thrd LINER 41/2 3.992 8.493.9 14,8143 6,263.7 1260 L-80 SLHT 6,197.1 5" x 4.5" i uomy ~e -~ripriun ny v .. ~u ~~y ~v .. .vv .,..,t ,.~. ..ter. , ..., r... ,...,~ ..~ .-.... ~ ._. ~ _~ ...._ TUBING 4112_. ~ _ 3.958 31 9 _ _8,506.8 6198A 1260 L 80 Completion Details -. rnp Deptn (ND) Top Inc! N mi... Top (HKBl (ftK8) ~ (') Ifem D scription Comment ID (in) ~.. _ _ -._ 31.91 31.9' -0.07 HANGER FMC TbgHanger w/pup 4.500 2,189.2 1,982.0 35.50 NIPPLE DB Nipple --~ - - 3.812 7,523.5 5,9674 6241 PACKER 'Packer-Baker Premier 3.875. 7,580.8 5,992.3 63.69 NIPPLE "X N" Nipple 3.725 8494.6, 6,1972. 86.141WLEG baker Fluted WLEG Assembly 3.958 Other In Hole Wireline retrievable lu s, valves um s fish, etc. II Top Depths i (rVD) Top Inc! ~ iTOp (ftK8) (ftK8) (") Description ~i Comment Run Date ID (in) 2,189 1 981.8 35.50 VALVE SET A-1 INJECTION VALVE (HAAS-446) GOOD 11/7/2009 1.250 CLOSURE TEST Perforations 8 Slots - - __ - snot Top (iVD) Btm (ND) Dens Top 8,688~~ Btm (ftK8 ~ (ftK8) (ftK8) Zone Date (sh... TYPe _ Commend '~. 14,773 6,209.8 6,260.3 11!10/2006 32.0 SLOTS Alternating solid/slotted pipe - 0-125"x2.5' o~74 circumferential atljacent rows, 3" centers staggered 18 deg, 3' non-slotted ends (Stimulations & Treatments ____- eeftom Min Top ~ Max Btm Top Depth Depth Depth Depth (ND) (TVD) (ftK8) (ftK8) 'i, (ftK8) (ftK8) '~ Type Date Comment . _ _ 12,230.0 14,820.0 6,221.6 8,264.2'ACID STIM 4/13!2007 Pumped 6% KCl watertaking rewrns to surface. Layed in 198 Bbls. 12 % HCI across slotted liner ~--_. Notes: General & Safety. _ '' - _ - --_ _. End Date Annotation __ _ _ -_. 11/13/2006 ' NOTE: TREE FMC 4-1/76" 5000 psi -TREE CAP CONNECTION: 7" OTIS 1117/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9 0 '. - - __. __ _ 7/24/2009 NOTE: ZONES NOT LOADED TO WELLVIEW YET - _.__ Port Top Inc! OD Valve Lath Slze TRO Run (°) Make Model (in) Serv TYPe TYP (In) ~ (P ) Run Data Cam... - t8 15 CAMCO KBG-2 1 Gas Llit DMY BEK 5 IO 000 0 0 7/23/2009 LINER, 849416.81d TD, 15 0]2 Description Summary of Proposal CD4-214 (PTD 206-145) 8/9/10 The static pressure survey taken in CD4-214 on 7/4/10 (3750 psi) showed the reservoir pressure in the Nanuq sand was too high for the Alpine well, CD4-12, to drill through. To mitigate the high Nanuq pressure, CD4-214 was converted to a producer and back flowed without artificial lift until ,f the well died at which point it was shut in. Over this period the pressure of the Nanuq sand declined 700 psi. CD4-214 was converted to a producer on 7/15/10 and back flowed for 11 days, producing a total • of 0 bbls of oil, 13750 bbls of water and 0 MSCF of gas. Scott Reed ConocoPhillips Alaska Page 1 of 2 Schwartz, Guy L (DOA) Z~(o~~{ Sd From: Schneider, Tim S. [Tim.S.Schneider@conocophillips.com] Sent: Tuesday, July 27, 2010 9:53 AM To: Schwartz, Guy L (DOA) Cc: Reed, Scott; ALP DS Lead and Simops Coord; Pysz, Nick P; Walker, Jack A; Allsup-Drake, Sharon K Subject: RE: approved sundry CD4-214 Guy, CD4-214 died early Monday afternoon. It has been freeze protected and a static survey is planned. No extended flow period is required at this time. We'll submit the 10-404 with the production data within the required submittal timeframe. Tim 907-265-6859 From: Schneider, Tim S. Sent: Monday, July 26, 2010 10:23 AM ,, ~~~ 1 To: 'Schwartz, Guy L (DOA)' ~ ..~_ i~~iw, `'~ ~' Cc: Reed, Scott; ALP DS Lead and Simops Coord ~.:~+-~~~'~ ti~"`~` Subject: FW: approved sundry CD4-214 Guy, We have been producing the CD4-214 (Sundry 310-209) since July 15, 2010. The reservoir pressure has dropped from 3750 psi on July 4th to 3450 psi on July 14th. The wells initial rate was 2000 bwpd at 480 psi FTP and the rate has dropped to 690 bwpd at 250 psi FTP. The well has been producing for 11 days, but the current producing rate is steady. CPAI would like to request a 7 day extension beyond the current July 29th flow period approval. Tim 907-265-6859 From: Allsup-Drake, Sharon K Sent: Thursday, July 22, 2010 10:36 AM To: Schneider, Tim S. Subject: FW: approved sundry CD4-214 Attached is the approved sundry for CD4-214 you requested. Thank you, Sharon 263-4612 From: Allsup-Drake, Sharon K Sent: Friday, July 09, 2010 12:55 PM To: Reed, Scott 8/13/2010 Page 2 of 2 • Cc: Schneider, Tim S. Subject: FW: approved sundry CD4-214 From: Allsup-Drake, Sharon K Sent: Friday, July 09, 2010 12:55 PM To: Allsup-Drake, Sharon K Subject: 8/13/2D10 • ~~Q~C~ O[~ Q~Q~~Q /~..a~,~.ao~A.o. Scott Reed Alpine Production Engineer ConocoPhillips Alaska, Inc. ~~ 6-- I P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Pool, CD4-214 Sundry Number: 310-209 ~~ r ~ ~ ~ ; ~ ~ ~` Dear Mr. Reed: ,.~~. ~,. ~~; °~~'~4 `` ~ ' 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. 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. Sincerely, Daniel T. Seamount, Jr. ~ ` ~,/ Chair DATED this ! day of July, 2010. Encl. ~` UI'y STATE OF ALASKA ~~~~1~ ALASl~IL AND GAS CONSERVATION COMMISS~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 !~-16A- 1. Type of Request: Abandon `"'" Plug for Redrill __ j`~ Perforate New Pool Repair well Change Approved Program ~°` Suspend ~ Rug Perforations ~"` Fbrforate `" Pull Tubing Time Extension ~°""` Operational Shutdow n Re-enter Susp. Well ~ Stimulate ~ Alter casin g Other: convert to producer 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development '"` Exploratory ~""'" 206-145 3. Address: Stratgraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20537-00 - 7. If pertorating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership cha nges: Spacing Exception Required? Yes N o ~' CD4-214 , 9. Property Designation: 10. Field/Pool(s): ADL 380077, 384209, 388902. Colville River Field / Nanuq Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 15072 ~ 6280 - 15072' - 6280' Casing Length Size MD ND Burst Collapse CONDUCTOR g0 16 114' 114' SURFACE 2620 9.625 2677' 2365' INTERMEDIATE 8639 7 8696' 6210' LINER 6320 4.5 14814' 6264' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner from 8688'-14773' 6209'-6260' 4.5 L-80 8507' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER -PACKER -BAKER PREMIER MD= 7523 ND= 5967 DB nipple MD= 2189 ND=1982 12. Attachments: Description Sunrnary of R-oposal 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch '"'° Exploratory ~`~" Development ;ivi; - Service "` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/9/2010 Oil ', - Gas WDSPL C Suspended 16. Verbal Approval: Date: WINJ ~` GINJ WAG ~ Abandoned Commission Representative: GSTOR ~~ SPLUG ;`` 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Reed @ 265-6548 Printed Name Scott Reed Title: Alpine Production Engineer Signature Phone: 265-6548 Date ~ 8 C mmi i n I Sundry Number~~ O _ 1~ Conditions of approval: Notify Commission so that a representa tive may witness 0/ "" Mechanical Integrity Test '" Location Clearance ~"'°` BOP Test Plug Integrity / 7~ Other: °' Cb .l .ti5~~.~- -~» Q e( WttLnGSS ~~~~ ~~o~.f 1 ~~~6...7V~D rr.v~ sf' /~{ ~rJUL 0 R 2010 - /~loCt.Ci'f iok.,~ ea~•~;s:o.1 ~ Subsequent Form Required: ~ ~~ ! D - y ~ Pr° " ~~'~ • Alaska Oil ~ Cas Gas. Commission Anchori~ge APPROVED BY ~ (~ Approved b ~ ~ COMMISSIONER THE COMMISSION Date: Form 10-403 Revise~T"1170`I4' ~~ ~ 9 ~ R ~ ~ ~ N A ~ ~ 7• q_tSubmit in Duplicate 't o • Description Summary of Proposal CD4-214 (PTD 206-145) 7/8/10 1. Pull Al injection valve from DB nipple for SBHP (completed). 2. Install OV in bottom station. 3. Pull check valve spool piece and install spooled choke in existing flowline. ~ ~ /~~ ~~ ~S 4. Install pilots for managing surface safety valve system. --~~ h~itncssc'~ `~ r 5. Temporarily back flow CD4-214 through production system until static pressure drops to 3000 psi or 14 days, whichever comes first. ~ 6. SI well and rig down spooled piping. 7. Seek sundry approval to convert back to injector with MIT etc. Scott Reed ConocoPhillips Alaska ~. Conc~cc~Phit{ips AI .=iNG 34-1 SURFACE, 36-2,677 GAS LIFT. ],419 PACKER. 7,523 --- --- NIPPLE, 7,561 WLEG, 6,495 WNS CD4-214 s Max Angle 8 MD TD Field Name I Wall Status Inc! (°) MD (HKB) Acl Btm (HKB) I~NANUO INJ 93.59 I 9,890.12 15,072.0 iH2S (ppm) Date An o[alion End Date IKB-Grd (ftl Rig Release Datr II 0 7/1/2009 Last WO: _l. 43 34 11/14!2006 epth (ftKB) (End Date (Annotation (Last Mod ...!End Date Rev Reason: RESET INJ VLV Imosbor 11(/12009 CONDUCTOR.V.. .._,.76..... _ 15.250 ~~ ~_e 34,0 .._, 114.0 ~.~~~ _°, V~714.0. VI ~~ ~ V~68.00 ~~~ V H-00 Casing Description String 0... String ID ... Top (ftKB) Set Depth (t_. Sat Depth (NO) .. . String Wt... String ._ (String Top Thrd SURFACE 9 S/8 8.835 36.4 2,677.0 2,365.4 40.00 L-80 BTC-M Casing Description String 0... Str ng ID ... Top (ftKB) Set Depth (t... Set Depth (NDI .. . String Wt... Str g .. String Top Thrd ( INTERMEDIATE 7 6.276 342 8,696.0 6,2104 2600 L80 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. . String Wt... String ._ _ _ String Top Thrd LINER 41/2 3.992 8,493.9 14,814.3 6,263.7 '. 72.60 L-80 SLHT Liner Details Top Depth (ND) Too Inc! Nomi... 0.7! 6,198.2 86.18 HANGER BAKER'DG' FLEX LOCK LINER HANGER 4: 0.51 6,198.91 86 20 XO 5x4.5 ( CROSSOVER S" x 45" 4: ng Strings Descnption String 0... String ID ... T I op (ftKB) Set Depth (t... Sat Depth (NDI ... String Wt... Str g .. ''~, String Top Thn G '~ 41/2 ~ 3.958 I 31.9 I 8,506.8 6,1980 12.60 ~ L80 ple tion Det _ ails _ _ _ Top Depth' (NDI Top Inc! Nol <81 (kK61 (°) ~ Item Description Comment ID 92 01 82 -0.07'HANGER FMC Tbg Hanger w/ pup 4; . 1 9 35.50 NIPPLE DB Nipple 3.1 35 5,9674 62.41 PACKER ( Packer-Baker Premier _. 3., D.8 5,992.3 63.691 NIPPLE '~ "XN"Nipple 3: Top (ftKB) In^61 (°) Description Comment Run Date ID (in) 2,189 1,981 8''~ 35.50 VALVE SET A-1 INJECTIONVALVE (HAAS-446) GOOD ( 11/7/2009 1.25f ( CLOSURE TEST Perforations 8 Slots - - __ __ _. - _ _. __ - ~ snot i Top (TVDI Btm (TVD) Dens ~ Top (ftKB) BM (ftKB) (ftKB( (HKB) Zone Date (sh-~ Type Comment 8,688 14,773 6,209.8 6,260-3 11!10/2006 32.0 SLOTS 'Alternating solid/slotted pipe - 0.125"z2.6" @ 4 circumferential adjacent rows, 3" centers staggered S i l i & T _--- -- 18 deg, 3' non-slotted ends - t mu a ons reatme t Min Top ' Max Btm ~ Top Depth nts Boaom Depth __- -- ---_------ Depth ~. Depfh ' (NDI (TVD) i (ftKB) (fl K61 (kK6) (ftKB) Type Date Comment _ _ 12,230.0 14,820.0 6,2216 6,264.2 ACID STIM !4/1 3120 0 7 Pumped 6% KCl water taking returns to surface Layed in 198 Bbls. 12 % HCI across slotted liner Notes: General- 8 Safety_ _ -- - -- _ End Date Annotation 11/13/2006 NOTE: TREE FMC 4-1/16" 5000 psi -TREE CAP CONNECTION: 7" OTIS 11/7/2008 NOTE VIEW SCHEMATIC w,'Alaska Schemanc9.0 7/24/2009 (NOTE: ZONES NOT LOADED TO WELLVIEW YET sLOrs, 8.688-14.]]3 ACID STIM, 12,236 LINER, 8,494-14,814 rD. 1s,mz 9andrel Details __ _ - - n To ftKg Top Depth Top Port (TVD) Inc! ~ OD Valve La[ch Size TRO Run 1 ~ 41 ~ CI I (ftKB) (°I Make Model ('ni Serv Type Type (inl (psi) Run D te_ C_ om 5,914.9 58.151CAMC0 KBG-2 1 Gas Llft DMY BEK 5 0.000 0 0 723/2009 ~ - Page 1 of 2 Schwartz, Guy L (DOA) From: Reed, Scott [Scott.Reed@conocophillips.com] Sent: Friday, July 09, 2010 10:30 AM To: Schwartz, Guy L (DOA) ~ - l~ ~ OC. ~ I r-~'S Subject: RE: Backflow CD4-214 Guy, Per our phone conversation: CD4-214 was shut in on 6/29/10 when it was identified as a possible drilling hazard for the upcoming well CD4- 12. A SBHPwas measured on 7/4/10 and recorded a pressure of 3747 psi at 5993 TVD (3818 psi converted to the datum). This is a ~12 ppge pressure environment at that depth and represents a large drilling risk because the mud weight required for the Nanuq is 3 ppg higher then the reservoir they will land CD4-12 in. A 2.5 ppge reduction in reservoir pressure is needed to mitigate the drilling risk for CD4-12. Drilling anticipates crossing this horizon in 3 weeks and natural pressure decline in the area will not be sufficient to lower the pressure. Back flowing CD4-214 will allow us to depressurize the over pressured Nanuq faster. CD4-214 has been on water since 2118/10 and the prior gas slug began on 12/26/09. Thanks Scott From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, July 08, 2010 11:05 AM To: Reed, Scott Cc: Maunder, Thomas E (DOA) Subject: RE: Backflow CD4-214 Scott, Could you submit your plan in writing so I have a better idea of what you want to do? You mentioned the well has an injection valve downhole (not a TRSSSV) so this is an issue as this will have to be pulled. Also what are you doing at surface as far as piping , manwatch etc. You will need to submit a 403 sundry to convert well to a Development (production) ... this sundry should include the safety and operational steps needed to do the backflow also. Hope this helps... call me back later today Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) _. __ _ ____ From: Reed, Scott [mailto:Scott.Reed@conocophillips.com] Sent: Wednesday, July 07, 2010 9:38 AM To: Schwartz, Guy L (DOA) Cc: Pysz, Nick P; Robertson, Ryan G Subject: Backflow CD4-214 Guy, The CD4-12 well plan penetrates the Nanuq-Nanuq ~ 300 ft away from the Nanuq-Nanuq injector CD4-214. Due 7/9/2010 Page 2 of 2 to the tight rock we have not had much luck getting the pressure down around that injector. Drilling estimates that they will penetrate that horizon in 3 weeks. i would like to backflow CD4-214 to reduce the pressure in that area and subsequently lower the drilling risk. What do you recommend as the best way to make this happen? Thanks Scott Reed Scott Reed Production Engineer WNS Subsurface Office: (907) 265-6548 Celt: (907) 575-3978 7/9/2010 • ~~ a X ~F ~ . L ... ~~ ~-~: ~, t MICROFILMED 6/30/2010 DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE ~~ C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • MEMORANDUM TO: Jim Regg P.I. Supervisor ~ ~ ~(~~ ~ 10 FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 12, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-214 COLVILLE RIV NAN-N CD4-214 Src: Inspector NON-CONFIDENTIAL C~ Reviewed By: P.I. Suprv ~2_ Comm Well Name: COLVILLE RIV NAN-N CD4-214 Insp Num: mitJJ100112135015 Rel Insp Num: API Well Number: 50-103-20537-00-00 Permit Number: 206-145-0 Inspector Name: Jeff Jones Inspection Date: 12/4/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We ~ CD4-214 Type Inj. w TVD 5967 / IA 660 2518 ~ 2471 2462 ~ P.T.D 2061450 TypeTest sPT Test psi 1500 ~ QA ~ 787 ~ 968 956 950 Interval 1~TA1- P/F P ~- Tubing 16s7 16ss 16x7 16s7 NOtes' 1.4 BBLS diesel pumped. 1 well house inspected; no exceptions noted. 1~~~~t~ J C`,1\ ~~ C-t! ~:M~. a„. ~~ Tuesday, January 12, 2010 Page 1 of 1 • STATE OF ALASKA • R ECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 0 8 ?.OQ9 REPORT OF SUNDRY WELL OPERATION 11 4 , , CAAR 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other nvert to injector Any: �� Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: Permit to Drill Number: ConocoPhillips Alaska Inc. Development ❑ Exploratory ❑ 206 3. Address: Stratigraphic ❑ Service ❑� API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20537 -00 7. Property Designation (Lease Number): Well Name and Number: Colville River Field / Nanuq Oil Pool CD4 -214 9. Field /Pool(s) u I ADL 380077, 384209, 388902 10. Present Well Condition Summary: Total Depth measured `15072' feet Plugs (measured) feet true vertical 6280' feet Junk (measured) feet Effective Depth measured 15072' feet Packer (measured) 7524' MD feet true vertical 6280' feet (true vertical) 5967' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 2620' 9 -5/8" 2677' 2365' PRODUCTION 8639' 7" 8696' 6210' SLOTTED LINER 6320' 4.5" 14814' 6264' Perforation depth: Measured depth: slotted liner from 8494'- 14814' true vertical depth: 6196' -6264' Tubing (size, grade, measured and true vertical depth) 4.5", L-80, 8507' MD / 6198' TVD Tar \\ \j & SSSV (type, measured and true vertical depth) Baker Premier pkr 52M) / 5967' TVD \ v , DB nipple @ 2189' MD / 1982' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation -- Subsequent to operation 2406 -- 13. Attachments . Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development ❑ Service ❑� Daily Report of Well Operations _X N V. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑✓ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309 -240 Contact John Tonello @ 265 -6371 Printed Name ohn Tonello Title Alpine Production Engineer f7r Phone: 265 -6371 Date Signature Prepared by Sharon All u Drake 263 -4612 Form 10 -404 Revised 7/2009 '� Submit Original Only WSR - Well Service Report Page 1 of 1 Well Service Report Well Job Scope CPAI Rep CD4 -214 IlWater Saturation / Flow Log Hazen, Mike Date Daily Work Unit Number 11/7/2009 7519 Initial & INITIAL T/IA/OA: Final 1550/7001600 FINAL Field: NANUQ Pressures: T/IA/OA:1550 /700/600 PERFORMED WATER FLOW LOG WITH HES SPECTRAFLOW TOOL TO 24 hr. DETERMINE FLUID MOVEMENT EXISTS BEHIND TUBING BELOW 7700'. Summary NO SUCH FLOW OBSERVED DURING LOG. LOGGED TO 8180' ELMD (INCLINATION OF 83 -DEG). STARTTIME OPERATION 05:30 AM ARRIVE CD1 , SYNC, JOB PROCEDURE 05:45 AM DRIVE TO CD4 PAD AND BEGIN RIG UP 06:15 AM WAIT FOR CRANE OPERATOR TO ARRIVE PAD TO PICK UP LUBE AND BOPS 06:45 AM CRANE OPERATOR ARRIVE LOCATION / SAFTETY MEETING AND BEGIN TO PICK LUBE AND BOPS 08:00 AM STAB LUBE ON WELL HEAD AND PREP FOR PT 09:30 AM PT LUBE OPEN SWAB AND BEGIN RUNNING IN THE HOLE WITH THE SPFL LOG 10:00 AM AT 8150' WITH SPFL AND BEGIN STOP COUNTS COMING UP HOLE 12:30 PM MAKE LOGGING PASSES UP AND DOWN 02:00 PM START OUT OF HOLE WITH THE SPFL LOGGING TOOL 02:30 PM OUT OF HOLE WITH TOOLS AND BLEED DOWN THE LUBRICATOR 04:00 PM FINNISHED RIGGING DOWN OFF THE WELL HEAD 05:00 PM RIG EQUIPMENT BACK TO THE CD2 PAD FOR THE NIGHT 06:00 PM DRIVE TO ALPINE CD I, SYNC, AND JOB PROCEDURE FOR NEXT DAY Fluid Type To From Non- Note Well I Well Irecoverablel DIESEL 1 IPT THE LUBRICATOR http: / /akapps.conocophillips. net / alaskawelleventquery / worklog.aspx ?ID= 8245BFEAA949... 12/7/2009 WSR - Well Service Report Page 1 of 1 Well Service Report Well Job Scope CPAI Rep CD4 -214 Slickline Misc. Drift, Tag, etc. Fitzpatrick, Chuck Date Daily Work 11 Unit Number 7/22/2009 770 Initial & INITIAL T/I /0= Final 500/1230/200 FINAL T/I /0= Field: NANUQ Pressures: 600/1100/225 GAUGED TBG TO 3.85" TO A -1 INJ VALVE @ 2189' RKB; PULLED SAME. 24 hr. GAUGED TBG TO 3.80" TO XN NIPPLE @ 7580' RKB. MEASURED BHP @ Summary 7736' RKB: 2530 PSI, 130 DEG. SET CAT SV IN XN NIPPLE @ 7580' RKB. PULLED OV @ 7419' RKB. IN PROGRESS. STARTTIME OPERATION 06:00 AM CONFER W/ CWG, PICKUP WELL FILE & CPU, TRAVEL TO LOCATION 06:45 AM CONTACT DSO, ARRIVE & INSPECT LOCATION, TGSM, RU HES, 2.125" STEM, TS = RS, QC,5',QC,KJ,5',QC,KJ,LSS,KJ,QC. 07:45 AM PT RIH W/ 3.85" GAUGE RING DRIFT TUBING TAG TOP OF A -1 INJ VALVE @ 2158' SLM / 2189' RKB POOH TUBING CLEAR 08:15 AM PT RIH W/ 4 1/2 PRS SIT DOWN LATCH A -1 INJ VALVE @ 2158' SLM / 2189' RKB, PULL A -1 INJ VALVE, POOH OOH W/ INJ VALVE (SER # HRS -308) 09:00 AM PT RIH W/ 5'X 2.125" STEM & 3.80" GAUGE RING DRIFT TUBING TAG XN NIPPLE @ 7557' SLM / 7580' RKB POOH PT LUB, 10 MIN LUB STOP, RIH WITH 2.65 CENT, S -SET & DUAL SAPPHIRE GAUGES TO 7713' SLM / 7736' RKB FOR 30 MIN SURVEY STOP (PSI 2530.27/ 10:30 AM TEMP 130.00), PUH TO 7590' SLM / 7613' RKB FOR 30 MIN GRADIENT STOP (PSI 2515.49/ TEMP 129.00),PUH TO 7479' SLM / 7502' RKB FOR 30 MIN GRADIENT STOP (PSI 2500.44/ TEMP 127.90), POOH, 10 MIN STOP IN LUB BLEED OFF. 01:45 PM PT RIH W/ 4 1/2 GS & CAT STANDING VALVE, SET STANDING IN XN NIPPLE @ 7557' SLM / 7580' RKB POOH 03:15 PM STAND BY FOR ASRC TO RIG UP JUMPER TO IA. 03:45 PM PT LUB, RIH W/ 4 1/2" OMK & 1.25 JD TO STA #1 @ 7400' SLM / 7419' RKB, PULL VLV, POOH, OOH W/ OV 05:00 PM LDFN, SECURE WELL, PJSM, NOTIFY DSO OF WELL STATUS, TRAVEL TO J1 LOAD WRDPS & INJ VALVES TO BE SHIPPED TO 05:45 PM SCHLUMBERGER CONTINUE CAMP, TURN IN PAPERWORK, CPU & FILES. END TICKET Fluid Type To From Non- Note Well I Well I recoverable http: / /akapps.conocophillips. net / alaskawelleventquery /worklog.aspx ?ID =62463 811277641... 12/7/2009 i 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: Conoco Phillips Alaska FIELD / UNIT / PAD: Alpine / CRU / CD4 DATE: 12/04/09 OPERATOR REP: Seth Brower AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well 214 Type In'. W TVD 5,967' Tubin 1687 1688 1687 1687 Interval I P.T.D. 2061450 Type test P Test si 1500 Casin 660 2518 2471 2462 P/F P Notes: MITT for AA OA 787 968 956 950 1.4661 AHF bbls pumped . Welli Type In'. I TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well I Type In'. TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type In'. TVD Tubin Interval P.T.D. Type test Test si Casin P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D.1 Type test I I Test psi I Casin P/F Notes: I OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring 1= Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) MIT Report Form BFL 9/1/05 MIT CRU CD4 - 21412- 04- 09.xis WNS CD4 -214 CQnoo Hips , 4 '• WWI Alt tes Max Angle 8 MD T AlaskE1 ( W Ilbore APVUWI Field Nam e (pWn) A Wall End Date Sta Inc/ MD (ftK8) Act Bim (ftK8) 501032053700 NANUO INJ 93.59 9,89012 15,072.0 Comment -� IH2S I KB- Grd(ft) !Rig Release Date Wep SSSV: WRDP Date 0 7/112009 Last WO' 43 34 11/1412006 _. -ft °nr+e-. c - t4. +v y tt �s8 - TA4 .. - - - Sr.1te_rnatk AGn+at. _- Annotation Depth (ftK8) End as Dats Annotation Lt Mod ...IEnd Data Last Tag: I _. Rev Reason: RESET INJ VLV Imos 1. 11/712009 HANGER,32- Casino 'Strin s _ Casing Description String 0... String ID... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt. .. String ... String Top Third ! I CONDUCTOR 16 15.250 34.0 114.0 114.0 68.00 H-40 - Casing Description String 0... String ID ... Top (HKB) Set Depth (i... Set Depth (ND) ... String WI... String ... String Top Third SURFACE 95/8 8.835 36.4 2,677.0 2,365.4 40.00 L -80 BTC -M Casing Description String O._ String ID ... Top (ftK8) Set Depth (f... Set Depth (ND)... String Wt... String .. String Top TAN INTERMEDIATE 7 6.276 34.2 8,696.0 6,210.4 26.00 L -80 Casi Descri - - - CONUUCWR. LIN R ption S tring z- s 3.992 70 8,493.9 $e14814.3 Set D62631.7 . S tring 0 SL.80.. Strin9SLHThN 34114 Liner Details _ Top Dep[h -� (TV Top Inc/ Nami... Top (B) C) Ilrrrt Desaiption Comment ID (in) VALVE. 2,189 8,493.9 6,197.1 86.14 SLEEVE BAKER'HR' LINER SETTING SLEEVE 4.420 NIPPLE, 2,189- 8,506.9 6,196.0 86.17 NIPPLE BAKER'RS'PACKOFF SEAL NIPPLE 4.250 8,510.7 6,198.2 86 18 W1NGR &4KER'DG' FLEX LOCK LINER HANGER 4.400 8,520.5 6,198.9 86 20 XO 5x4.5 CROSSOVER 5" x 4.5" - 4.000 SJRFACE.__. 36 -2.677 TUBING i 1/2 3 958 31 9 8,506.8 .. Str ng ID Top (HKB) Set Depth (f... Set Depth (ND) . Str ng Wt... Str g ... Stri g Top ThN T ubin g Des String O ... I I -I 6,198.0 12 60 _ l L-80 ion-Details Top Depth GAS LIFT, (TVD) Top I-1 Nomi... 7,419 To ( ) C) HernDeecription comment IDpn) 31.9 31.9 -0 .07 FIANGER FMC Tbg Hanger w/ pup 4.500 - 2,188.2 1,982.0 35.50 NIPPLE DB Nipple 3.812 -_.. 7,523.5 5,967.4 62.41 PACKER \j Packer - Baker Premier 3.875 PACKER, 7.523 __ - -_ 7,580.8 5,992.3 63.69 NIPPLE "XN" Nipple 3.725 8,494.6 6,197.2 86.14 WLEG Baker Fluted WLEG Assembly 3.958 NIPPLE, 7,581 -- :,(. Other In Hole ireline retrievable plugs, valves pumps fish etc. Top Depth - -_ - -_ (TVD) Top Inc/ !, TplpLft a fRKel l') Description Comment Run !late IDAin) WLEG. 8.495- 2,189 1,981.8 35.50 VALVE SET A -1 INJECTION VALVE (HAAS -446) GOOD 11!7/2009 1.250 CLOSURE TEST Perforations & Slots _... shot Top (ND) Btm (TVD) Dens T RKB Bhrt MCB (ftK8) (ftK8) Zone Data ( :h_. Type Comm 8,688 14,773 6,209.8 6,260.3 11/10/2006 32.0 SLOTS Alternating solidislotted pipe - j 0.125'x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg S non slotted ends TERMEDIATE, Stimulations & Treatmentsftem -- - 34-8.696 -- --- -_____ Min Top Max Btrn Top Depth Depth Depth Dspth (ND) (ND) e- y (ftK8) _ _(RKB) (ftK6) (HKB) Type Date Comment _ 12,230.0 14,820.0 6,221.6 6,264.2, ACID STIM 4/13/2007 Pumped 6% KCl water taking retums to surface. Layed in 198 Bbls. 12% HCI across slotted liner Y 11/13/2006 L.OTF, : TREE: FMC 4- 1/16" 5000 si - TREE CAP CON NgtQS_Genera &_Safety End Data Annotation y p NECTION: 7" OTIS Y 11/7 12008 : VIEW SCHEMATIC w /Alaska Schematic9.0 _. 7/24/2009 ZONES NOT LOADED TO WELLVIEW YET SLOTS, 8.688 - 14,773 j Mandrel Det i Top Depth Top Port (TVD) Inel OD Valve Latch Size Tito Run ACID122130 Stn Top (RKB) (RKB) ( Make Model (in) Sery Type Typ (inl (psi) Run Data FV- 1 7,419.0 5,914.9 58.15 CAMCO KBG -2_ 1 Gas Lift DMY BEK S .0.000 0 0 7/23/2009 t LINER,__.. _J 8,49414,814 TD, 15,072 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Water Flow Log: CD4-214 Run Date: 11/7/2009 C~ December 2, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD4-214 Digital Data in DLIS format, Digital Log Image file 1 CD Rom 50-103-20537-00 Water Flow Log 1 Color Log 50-103-20537-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 .: rafael.barretaf~hll~urtQnteo~rx " ,; __- Date: -~." ~~;- ~~~- ~pCc-tL1~' e~ilt `d ifs Signed: ;` ~J • ~ ~,~y (~ ~ ~~ ~v k ~~ ". ~ ~,`~: ~ ~ ~ ~ ~ ~ p ~ ~ ~ ~ ~ ~ ~ ~ ~ yf"' -.:p. y p "'~, 5 ~ ,~n Q R ~ @ ~ p k ~, ~ 8 ~ ~ ~ ~ ~` ~ ~ ~ ~ ~ ~t': y . ..-,: R 5~~ i?~e ~:~ ~ ~ ° ~t~ ~ ~d~s ~~~ 6 ~ ~ ~ ~~ ~~e ~ ~ ~ ,~ GOVERNOR ~ SEAN PARNELL ~~ . ^ ~ ~ ~~~ ~` ~ : F ~ ~ s ~ ~~~ ` ~ ~ k ~ ~ ~ `~ ~~ ~ , q ~ u ~~ .~~ i,. .x. c ~ ~ ~ . . . ~ _.~z¢ ~-7~ ~~ ~ ~it~-.7 ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T COMl-IISSIOI~T 9501-3539 ~ O RA ~14 pHON E ( 07) 279- 33 G' FAX (907) 276-7542 Mr. Ryan Shirtliffe WNS Production Engineer ~ ~, ~ ~ ~~~~~ i~ ~;, ?~~~~3 ConocoPhillips Alaska, Inc. ~~~`~~'~~''~~° ° P.O. Box 100360 ~ Anchorage, AK 99510 ~,~ ~ (,k ~~ Re: Colville River Field, Nanuq Oil Pool, CD4-214 Sundry Number: 309-240 Dear Mr. Shirtliffe, 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 feld 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. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED thisZ~ day of July, 2009 Encl. (~' ~.fP~ • ~ti STATE OF ALASKA ~~~~~ V ~~ ~ ~.~r~,~ ~JL. 1 6 20D9 ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~k~ ~~I ~a Gas ~o~~, Commission APPLICATION FOR SUNDRY APPROVAL ~~,~~~~~~~ 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other O Alter casing ^ Repair well ~ Plug Perforations ^ Stimulate ^ Time Extension ~ ~nvert to injector Change approved program ^ Pull Tubing ~ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^~ • Exploratory ^ 206-145 . 3. Address: Sbatigraphic ~ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20537-00 ' 7. If perForating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? Y@S ^ NO ~ • CD4-214 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380077, 384209, 388902 • RKB 57' Colville River Field / Nanuq Oil Pool . 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 15072' ° 6280' ' 15072' ' 6280' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" ~ ~4' 114' SURFACE 2620' 9-5/8" 2677' 2365' PRODUCTION 8639' 7" 8696' 6210' SLOTTED LINER 6320' 4.5" 14814' 6264' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner from 8494'-14814' 6196'-6264' 4.5~~ L-80 8506.8' Packers and SSSV Type: Packers and SSSV MD (ft) Baker premier pkr @ 7524' DB nipple @ ' 2189' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^~ - 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat August 7, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG `~~ GINJ ^ INJ WDSPL ~ Commission Representative: ~ `~/~. 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ryan Shirtliffe @ 265-6371 Printed Name an S~rtl~ e Title: WNS Production Engineer Signature Phone 265-6371 Date ~G ~ ~~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~-~ (~ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test [~ Location Clearance ^ Other:~ 2C~1f~C~F~Ev.s `~ ~~ e S ~h~0~C11 S~ ~G~r~'tt~ ~C~O'~~~`~~14ti'T~~ S~ ~~ Ct..~lt~~llCi~ y, a S Subsequent Form Required: ~Q~ ~ ~ ~ APPROVED BY ~~~~ Approved by: C MMISSIONER THE COMMISSION Date: ~ Form 10-40~Revised 06/2006 ' l ~ ~ t-~ ~ ~ ~ ~ '?~~~ ~~~ ;~;~~ ~ ~t Z~~q Submit in Dupli ate~ ~~ ~g V \./ ~ ~~6~~ ~ . ConatoPhillips .~,..> .i.l:~' CONDUCTOR. 0 114 VALVE,2.189 NIPPLE. P.'89 -- SURFACE. 3&2.6]] GAS LIfT. ~.aie PACKER, 7,513 NIPPLE.7.581 - ~ - - WLEG,B,<95 -- _Y~ ~ ~ ~' •` I I ° ~I I~ 'I I ~ .f~l I~ ~.I I ` ~I I m ~I I~ ~ I I~ SLOTS, . . . ar. I I ~ 8,688-1s,'/I3 'T:~ ( I ^°'° :~_ ~ I _ o ' I~ ACID STIM. ~- I I ~~~~'-. 12.230 d ~ ~ d ~°'I I~ V I I~' I~ LINEr2. .__. ____ ..f.I \ ~ 8.536~16.81! - . TD.15,072 ~ ~ WNS ' ~ CD4-214 Well Attributes WelltwreAPI/UWI FieldName ProA/InjWellType ~WeIlSfatus lncl(°) ~MD(fiKB~ TD(maz)(fi... I 50 7 0 32053700 NANUQ l INJ I 93.59 9,890.12 15 072 0~I Canment H2S(ppm) 'Da~e ,Annotation Entl~ata K6-Grd(ft) RigReleaseDale ISSSV~. WRDP i ~~~Last W0: I 43_34 I 11l14/2006 I Annotation ~Depth(ftK6) EnADate Annotation . iEndData I Last fag. I Rev Reason: Reset INJ VLV 17/72008 ICasing Strings _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (i... Set Deplh (ND) ... String Wt... String ... String Top ThN CONDUCTOR 16 15250 0.0 114.0 114.0 I 68.00 H-00 Casing Description String 0... String ID ... Top (ftK6) Set Depth ((... Set Depth (NDy ... '~String Wt... ~ String ... String Top Thrd SURFACE 95/8 8.835 36A 2,677A 2.365.4 I 40.00 L-80 BTC-M ~Casin9Descnption 'ISh'ing0._ ~StringlD... Top(ftK6) SatDept~(f... SetDepth(ND~...~StringWt... ~String...~5tringTOpThR1 IMEHMEDIATE I 7 ~~ 6276 342 8,696.0 6,210A ~ 26.00 i L-80 I _- _ Casing Description y5tring 0... IString ID ... Top (NKB) Sat Depth (t_. Set Dapth (ND) ... IString WI... ~String ... ~Shing Top ThN LWtH , 412 $535] 74,574.3 6,263J ~, 12.60 I L-80 SLHT ___ .. ~TubinqStrin s Tubing Description SVing 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (ND) ... String Wt... String ... Shing Top Thrd TUBING 41/2 3.958 31.9 $506.8 6.198.0 12.60 L-SO _ Completion Details _ '~i Top ~epth' I _ (NDI Top ~ Top (ftKB) (ftKe~ Incl (°' I k~ pasCription Commant ID (in) 37.9 31.9 -0.07HANGER FMCTbgHangerw/pup 4W0 i , _ 2.189.2'~ 1 9820 35_SOINIPPLE ~DB Nipple ~ . __ _ ._.._... . . . -._ . . _ . .~.-.. . 3.812I ~ 7,523.5~, 5.967A' 6241 ` ~ _ PACKER~ . _ . __ ~Packer-BakerPremier _ _. _ ___ 3.875 __.__ ,-- _ . , 7,580.8, 5,9923~ 63.69 NIPPLt "XN" Nipple ' 3J25 ___. __ _-_ - - _._- __._- F 8.494.6~r___.__ ~ 6.797.T~ 86.141`NLEG ~BakerFlutedWLEGAssembly . I . T _.._ 3958 i. .__ Other In Hole (Wireline retrievable plugs, v To 1h alves, pumps, fish, etc.) ~ ( Kg; C ~ I I`OII Oescrption I Top(ftKg~l Commen ~ RunDate ID(in) ) '- A~INJECTIONVALVE 2,189.0 1,981.8 35.50 VAWE (HRS-308 11/612008 12W s~m snoi oe~s (s~~~~ I Type Commerrt _ _ 32.OjSLOTS IAnemating solid/slotted pipe MinTOp MaxBtrn Depth Depth (ftKB) (kKB) -. etails an re __ ~~TopDepth Top (TVD) Incl OD n~~Top(f~K6~ (kKg) (`) Make ~~ Model (in) 1~I 7419.0. 5,914.958.75~,CAMCO~KBG2 1 G ~mped 6% KCI watertaking reNms to surtace iyetl In 198 Bbls. 12 % HCI across slotted liner ~ • Page 1 of ~ /~ Maunder, Thomas E (DOA) From: Walker, Jack A (Jack.A.Walker@conocophillips.com] Sent: Wednesday, July 22, 2009 12:54 PM To: Maunder, Thomas E (DOA) Cc: Galiunas, Elizabeth C; Allsup-Drake, Sharon K Subject: RE: CD4-214 (206-145) Conversion Sundry Attachments: Spectra Flow Brochure.pdf Tom, We submitted a sundry 10-403 form to convert CD4-214 (permit 206-145) to injection, dated 11-Ju1-2009. Below is some background information, a description summary of proposal, and a correction to the 10-403 form dated 11-Ju1-2009 for CD4-214 convert to injector. Background CD4-214 (permit to drill 206-145) was originally permitted and completed as an injection (service) WAG well in the Nanuq Oil Pool. It was temporarily converted to production as approved by the Commission 13-Mar-2007. The temporary production testing was completed, and longer term pressure monitoring of the CD4-214 well (shut in) was also completed. A 10-403 form was submitted to convert CD4-214 to service class, however the log to evaluate cement quality is not valid due to loqqinq conditions. The CD4-214 production (intermediate) casing cement job, including pipe movement, was executed according to plan similar to other wells in the area with good cement logs. Description Summary of Proposal The following is a proposed summary plan for CD4-214 as part of the conversion from development oil to service WAG well status after the work. 1. Prepare CD4-214 for MIT by loading inner annulus with corrosion-inhibited seawater / diesel cap and replacing gas lift valves with dummies. 2. Acquire static bottomhole pressure. 3. Put well on water injection and stabilize injection rate and pressure. 4. Run a Halliburton Spectra Flow (trademark) to demonstrate that injected fluids are isolated to the approved interval, Nanuq Oil Pool. The Halliburton Spectra Flow (TM) pulsed neutron / activated oxygen technology can be applied to identify water movement outside of casing. SPE paper 49230 describes the logging tool and method with two examples. Enclosed is a Halliburton brochure on the logging tool. 10-403 Form Correction The 10-403 form for the CD4-214 conversion signed 11-Ju1-2009 and sent to the Commission incorrectly requested WINJ well status after proposed work (box 16). We need a WAG well status after the proposed work on CD4-214 because water and gas alternating injection are planned. Thanks for the direction you've already provided to Ryan Shirtliffe and me. I would be happy to discuss this conversion or provide anything else the Commission may need. Jack Walker ConocoPhillips Alaska, Inc. Western North Slope Development 907-265-6268 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 21, 2009 7:28 AM To: Walker, Jack A 7/27/2009 ~ ~s., . .,. ~ ~ Maunder, ThQmas E (DQA~ • Frpm; Walker, Jack A [J~ck.~+.Walker~conocophili~ps.cornJ Sertt: Tuesday, ,luly 24, 20~9 8:Q6 AM To: Maunder, Thomas ~ (D~A) Subje~t: R~: G[~1-21~ (206-145) - BAT SQnie Thanks, Tom. ! had anty seen a part of this, and it helps ta have the entire sfing -1 came to similar canctusion on the BAT. S#ill haven'# heard frqm the local 'new guys', bu# their online G#era#ure indicates pulsed neu#ron #echnology in ap{~lica#ions for outside-casing wa#er up/down water f1ow. Jack Fram: MaundEr, Thomas E(QQA~ [ma~Ito:kQm.maunderC~a alaska.gov] Settt: Tuesclay, luly 21, 2Q~9 7:28 AM Ta; Walker, ,7ack A Subj+E+~t: ~V1l: Cp4-214 (~~6-145j - BAT SoniC Jat;k, ~t+eg~rding ~~t 21~, FY! h~ i~ ~ m~ ~ st~in~ th~at hy~n and 1+~~-~ng~d. 1~de~n't t~r~~w if y~u h~ve sa~n ~i~; !~ poin#e~i a~t in your m~s~g~, ~ w~tter flaw t~rg wol.tk! ~ a good chai~e b~ that t€sa ;s n~tt in tt~ "t~ol k~`: ~'~m I~ur~der: P~ A~~~C From: Maunder, Thvrnas E (CiOAj ~at: T{~tur~ay, luly k6, ~f'lE)9 8;~0 AM ro: ~snirtliffe, Ryan' 5t~b~ect: RE, CD~-2~4 (206-145) - BAT Soni~ Fty~n, ~maYs the s~rt ~f ~t~t~ment r~~d~d. 1'~u rr~~y hav~ includ+s~i th~t in t~~ ~~ch+rn~ni~ t~ the sundry. I~n~ur th~t #~e ~AT infbrr~n i~ r~c~t c~ttm~. '~'he d~ ~nform~n mi~h~ ir~d~ svrr~ d~gtt~ ~f bc-ndi~g f vw~ver yau di~ourif fh~f ~#~tSW l1~i~. 7rr~ ~pera#ions infarm~t~an ;r~ieat~$ th~t ~t r~tturn~ w~t~ r~at ~x{~risr~c~d~ I~aar~rer ttt+~y al~ st~t~ th~t ~ip~ mov++~-t~nt w~s ~a~d smtx2 th+~ dispf~aement w~s sta~i, fihe ~r v~r~as st~N ~5 bbls #rom ~~ifing the ~h~ ~r~d the i~;~~l +~rne~nt was 8n bbls b~hind th~t, i willl~k t~rw~rd ~a the ~un~ry. Tom Mauruier; P~ Ad~C ~rom. Sh~rtli~f~, Ryan [maitta:Ryan.Q.ShirtltfEea~canc~ophillips.com] Sent: Thursday, auiy 16, 2009 8:12 AM Ta: Maur~der, Thomas E {DOA) Sub~ect: RE; CR4-214 (2QE-145a - BAT Sonic Tom, Thanks for #he heads up on the proper way to send you informatior~. Since the BAT is inconclusive we would pl~n to run a watertlow log on #h~ weA to prove ihat ther~ is isola#ion. Ryan From; Maunder, Thomas ~ {D~A) [ma(Ito:tom.maund~r@alaska.gov] S+~nt: Thurs~day, Ju1y 16, 2009 7:55 AM To: Shirtliffe, Ryan 7/21/20~9 - --a- - -- - ~ • Subje~t: RE; Ct~-~~4 (206-1~5) - BAT SaniC ~tyan, ~nm~n y~ ~n~ r~ ~ m~~~~, ~~ ~r~~a~~~ ~ ~~ ~~~ t~~ ~r~;x ~ d~j~~ r~~m~r ~o~ ~,~ we~~, 7`h~t ~t~fp~ as i wvrk on tt~i~g~, llVith ~~r~ ~~~A~' S~-r~~ 1ti~g t~r t~i~ w+~1, ~r~ ycw ess~~n#i~l~y t~li~g rrae tt~t t#~~ ~g h~s nc~ u~~l~ d,~t~ ~~~+~ing th~ ~rn+en# ~n~`~ Y~u incl~t~~ ~t~t~m~nt~ ~s~ain~ th~ lc~ er+f~a~ion, hovv~wsr y~u ~ nc~f includ~ ~ c~ndug~on. Based or~ ~~ lr~g ~nd t1~ dpera~nt-1 infc,m~#it~ ~,~ #~e ?" cerr~nfing r~paration, wf iat d~ you ~n~lude a~ ta ~h~ ef~~~Iv~ l~rrl~#ic~nl~e~lirtq af the ~" ca~i~g inta t~re ~~? Tom 11A~under, pE ~~~~C Frorn: Shirtiiffe, Ryar~ [mailto:Ryan.D.Shirtliff~C~conocc~phillips.com] S~rnt: 'fhursday, ~uly i6, ~UQ9 7:45 AM Ttt: Maund~r, Thoma~ E (~QA} Sub~~ec`t: Tom, Here is #he !og #c~r th~ ~[~4-214 well that we pf~n to start ir~jection int4 as weil. 1 h~ve the 10~ 4~3`s carnple#ed far botk~ ~09 & 214 and witl get ~haron to forward t~~rn to yQUr af~ic~ today. L~g av~rview: CD4~2'!4_BAT TQ~.pdf . A~aparent T4~ approxim~teiy bet~nreen 52~0' and 53~~'. . Fcpm the Ic~g head~r the 7" wa~ set ~t 8~~8'. ~ Measur~m~nt After Drillinc~ {MA~3) pass d~~ n4t ~ver 7" sho~ or opsn hole. . Qata densilyF f~om 520a' t4 8~00' is very low, suspect this is tripping data. . Dat~ from 830Q' tp end Q# Ic~g appsars to be driiling da~. Mud Flow across re~eiv~rs causes th~ `"ch~tter" se~;r~ in th~ wav~form dis~lays. . Int€,rval betw~sn 8430' and 84'70' ha~ a higher energy ~i~nal indica#ing an apparent lack ofi bond over that intervai. Thanks, ~Y r r WNS Frocluction E3ngineer ConocoPhiliips Alasl~a f9(}7) 265-6371 Offt~e (907) 575-7839 Mobile 7/2 2 /200R Spectra Flow Logging Servic~ata Sheet) WIRELINE ANO PERFORATING SERVICES Spectra FIowT"' Logging Service Accurate, Simultaneous Up And Down Waterfiow Analysis The new standard in water flow technology, Halliburton's Spectra FIowT"' Service accurately detects and quantifies downhole water flow to enhance the planning and improvement of conformance and water management. . Accurately identify the water source Spectra Flow data precisely identifies water entry points and channels for timely planning of effective remedial action. . Evaluate downhole flow patterns Quality injection profiles lead to improved conformance measures. . Reduce water disposal COStS Spectra Flow identifies flowing water with spectral measurements of the gamma rays emitted by neutron- activated oxygen nuclei. The detectors are located far enough from the source that oxygen decay in stationary water, mud, formation or cement is not observed. Oxygen activation measurements clearly identify water entry points. ......__.._ .............._...... _.--~--- ~ -- ~ Page l of 3 ~"r ~'rint Version The above Spectra Flow impulse velocity test calculates accurate velocity by measuring the time of activated water compared to non-activated water passing by Spectra Flow detectors. Velocities are calculated for the two spectral measurements, the total activation measurement, and the natural gamma ray detector. Both simultaneous up and down flow can be measured. Track 3 displays the spectral measurements of activated oxygen. Track 2 contains the gamma ray, near and far oxygen activation (OAIN and OAIF), generator voltage, and near and far total activation measurement (TNA and TFA) curves. Track 1 shows the water flow velocity curves from each of the measurements in Track 2(VSN for OAIN, VSF for OAIF, VTN for TNA, VTF for TFA, and VGR for GR). http://www.halliburton.com/public/lp/contents/Data_Sheets/web/H/H00634.asp 2/28/2009 Spectra Flow Logging Servic~ata Sheet) ~ Page 2 of 3 Comprehensive water flow analysis identifies not only the source and speed of the water but also determines whether the water is flowing up or down the wellbore, inside or outside the casing. Precise water velocity measurements using spectral data are provided with continuous logs and stationary impulse step-down tests. Water flow greater than 3 ft/min can be detected and, depending on the flow volume and location, accurate quantitative velocities as low as 5 ft/min can be measured. For velocities over 50 ft/min, improved accuracy is obtained by using the more distant natural gamma ray detector. Modular tool design allows Spectra Flow to be run in combination with production logging tools. Multiple configuration options allow Spectra Flow to be tailored to the types of flows encountered downhole. http://www.halliburton.com/public/lp/contents/Data_Sheets/web/H/H00634.asp 2/28/2009 Spectra Flow Logging Servic~ata Sheet) • Page 3 of 3 ~c-a~r Dlm~nsions ~ncf Ratin~s ~~x Max tem~: 32a"~ Max +~rr~s: 15,D~NJ psi SesEioat Min Ha3r~: 2~Q in Max 00: 1eC'~ in. ~ _ . _ ~ Max H~te: 1~6.4 in. L~ngth: 215.8 i~ Weight at~ Ib ~orehole Cr~ncfitic~ns Borefroale Fluids: 5alt ^ FrGSh ^ Oil^ Air ^ _. _ .. . __.___ __ ._.. _.._... . _____W _ . , , ..w , ._ ___..,._ _ ._.._._...~.,..~ _. ~_ __ Re~ammended ~Qgging SpGed. 5tati~ary; ~oc f~~aw rat~ tie~aendent 1c~Ul !'asiti~xrri~; !C~rrlYalet~d ! EC~cetttP7liZed ^ Hardwace Charasteristics D~tectwl +Generattx Secdon 5~ce Tjr~. 14 N~V ncutron g~r~crau~€ Sens~x Type: Na~ ~'tl) SGintillvmeter~ ~~} Sens4zr S{~a~inc~: N~±~e ~~i i~., F~r 4~3 in Fuise P~riod: 45-ms a~tivati~~a; 5-ms delay; 5t}-ms croxy~en counis; repcatea continu~usly 5ampiing Race: 3 ~n. ~tan~ard Full Speclr~~rn; _.. _ _..~ .,._ ___._ Tcicmetry Syste~: _ . _. Cc~mpatibil~~y ~~~~tr~ for eac~~ 4i~teCk~' __.._.__ , ,___.._.._ _..___~_. , w . _~ .__._.__._ _.._.._. .. . _..._.. Iv1UXB 2 tclerr~euy syst~m , .,. .. ._.. .. . M41XB 2 c€s~-~p~~iblc Me~~ult'~CtlcttE e~~ p~ ,~aac tr~ F tow c~ua tre rur7ligincd ~o naeasurc u,~fi7c~wtr. dc~~~flt~w ~r bdfh srmuJr~~rs~y wva~ri ~~~a~nary. ~i tudi 3 t~~t t~r~tsvcr!n ff~ sx~urce and tfcaft~c~dr:~ e~d~rtir~td~s ~d~ivr~y uxyx~t.~r~ ~irxi SatrYj?Pilrt'S C~fibY~EtOrt. Principle~ Watcr v~la~ci4y frc~m neutrt~t sctiWatet~ ~yget~ Ftange: 3- 50 ft+min st~rkio~ary; 5~ • 2il€3 ~4tt~in with GR to~xf at f 2 (i 1Jeriic~l Ftes~+lt~4ican; ~~ in ~rp[h af Irn1~ki~at~n+n,: A- 12 i~~. l~ccura+cy: *_ 2 #Umin Pr~cision: ~epends c~n vnlumc ~ and slistaryce ta f~osnr ~rim~y ICuCveS ~~t, f~All~, t~A1F. GENV, 4U~~'7, ~Sf'T, ~l$iV,1f~F. VGR, CRA~'tU. GR11TF Secartdary Gurves~ TNA. TFA. VT~1, VTf, CGL. ~S, Rt~AS, FV5 Send questions or comments about this site to Halliburton Service Center or www.Ha/liburton,CO/11 call U.S. (877) 263-6071 or outside U.S. (281) 983-4900. ~~~`t8~~.r~~ Copyright ~O 2009 Halliburton. All Rights 2/28/2009 Reserved. Terms_and Condition_s Privacy http://www.haliiburton.com/public/lp/contents/Data_Sheets/web/H/H00634.asp 2/28/2009 # ~ Maund~r Thomas ~ C-QA From: Walker, Jack A [Jack.A.Walker@conocophiilips.com] Sent: Monday, July 20, 2009 3:55 PM To: Maunder, Thomas E (DOA) Subject: CD4-214 (206-145) Conversion to Injection Sundry Tom, I confirmed that our cement quality log is not valid due to logging conditions in CD4-214. In the past, we would have proposed a"Water Flow Log", pulsed neutron type device by Schlumberger. But as our logging company contract was changed, I'm trying to track down our new service company, Halliburton, capabilities. Jack -----Original Message----- From: Maunder, Thomas E (DOA) Sent: Thursday, ~uly 16, 2009 To: Walker, Jack A Subject: FW: CD4-209 (206-065) [mailto:tom.maunder@alaska.gov] 3:00 PM and CD4-214 (206-145) «CD4-26 Convert to Injector 9 7 2009 (2).doc» Hi Jack, Here is the message I got back when I sent a message to Ryan. Can you help me here? Al1 that was sent was the sundries and weilbore drawings. Can you provide some sort of "statement" document that assesses the cement isolation and concludes it is effective or in question. Thanks, Tom Maunder, PE AOGCC ____e________~~~ffi~~egaaQa~~aa~_~~m_sa~~~ « ~ffia~a~~Qa~~a_______________~_a I will be on holidays from July 17-July 26th, then relocating to Calgary. Please call me on cell at 907-575-7839 for anything urgent. Scale associated items call Tim Schneider, CD4 items please call Jack Walker. Thanks, Ryan -----Original Message----- From: Maunder, Thomas E (DOA) Sent: Thursday, July 16, 2009 2:53 PM To: 'Shirtliffe, Ryan' Subject: CD4-209 (206-065) and CD4-214 (206-145) Ryan, I have received the sundries including a wellbore drawing, but that is all. I need a document for each similar to what you sent for CD4-26. We had earlier exchanged emails regarding CD4-214 where you indicated that a water flow log would be run due to the pessimistic BAT sonic. 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BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: S ~~ ~ - I ~- 1 i-I, 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`x', 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 ~~~~~ ... _~. ~t "~ I~A~ ,., ~Y, 2~ 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 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # .cement um ed cement date 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 i 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 C 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 r 3 !~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2067450 Well Name/No. COLVILLE RIV NAN-N CD4-214 Operator CONOCOPHILLIPS ALASKA INC MD 15072 TVD 6280 Completion Date 11/13/2006 Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION Mud Log No Samples No Directional DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neutron Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D D Asc Directional Survey (~ C Lis 14572 Induction/Resistivity Rpt. 14572 LIS Verification / f..~b C 15855 Induction/Resistivity 0 15072 Open 1/28/2007 2645 15072 Open 4/4/2007 LIS Veri, GR, ROP, FET 2645 15072 Open 4/4/2007 LIS Veri, GR, ROP, FET 114 6279 Open 1/31/2008 MD and TVD for EWR, DGR in, PDF, EMF and CGM graphics Well Cores/Samples Information: Name API No. 50-103-20537-00-00 Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? Y N Chips Received? '1~[..AL Formation Tops / N Analysis ~'T~ Received? Comments: (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments Compliance Reviewed By: _ __.____ --- -------- Date: r • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-214 January 15, 2008 AK-MW-4720106 CD4-214: Digital Log Images: 50-103-20537-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 a -~ -- ~` ._ ' , x Date: ~~~-£ ~ ~ ~ ~i~??~; Signed: ~ ~ ~~~ s, v~.C~ a bto _ ~ c-( 5 Sundry 307-083, CD4-214 Page 1 of 1 ~ - • • Maunder, Thomas E (DOA) From: Walker, Jack A [Jack.A.Walker@conocophillips.com] Sent: Monday, July 23, 2007 9:14 AM To: Maunder, Thomas E (DOA) Subject: Sundry 307-083, CD4-214 CD4-214 24 hr summary April 13, 2007 -Sundry No. 307-083 Permit to drill 206-145 Tractor from 12,230' to end of liner at 14,820' CTMD, pumping 6% KCI water taking returns to surface. Laid in 198 Bbls. 12% HCI across slotted liner. FP well with 30 Bbls. diesel. 7/23/2007 ~ ~ • ~ ~ECEiv~® STATE OF ALASKA 1~~ ~ ~ 2~~7 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION°8ska Oil & Gas Cans. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ~ Exploratory ^ 206-145 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20537-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 5T CD4-214 ~ 8. Property Designation: 10. Field/Pool(s): ADL 380077, 384209, 388902 Colviie River Field/Nanuq Oil Pool 11. Present Well Condition Summary: Total Depth measured 15072' F feet true vertical 6280' 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 2620' 9-5/8" 2677 PRODUCTION 8639' 7" 8696' SLOTTED LINER 6320' 4-1/2" 14814' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 8507' MD. Packers &SSSV (type & measured depth) Baker Premier Packer set at 7523' SSSV=NIP SSSV= 2189' 12. Stimulation or Cement Squeeze Summary: Layed 198 bbl. 12% HCI throughout slotted liner via tractor-assisted coil tubing with final pressure of 400 psi Intervals treated (measured) S BFL JUL 2 4 2b0~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 648 - 2159 None Subsequent to operation 829 ~ 1840 None 14. Attachments 15. Well Class after work : Copies of Logs and Surveys run _ Exploratory ^ Development ^ f Service ^ Daily Report of Well Operations _ 16. Wefl Status after proposed work: Oil^~ ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 307-083 Contact Jack Walker Printed Name Jac er Title Production Engineer Signature ~ Phone 265-6268 Date ~ 2~/l~ 7 Pre ared b Jeanne Haas 263-4470 v Form 10-404 Revised 04/2006 ORIGINAL ~~~~~ 7~~~i~mit Original Only Aw...~.~ Ll4~Gwi ~~~ .... • Subject: I~.c; Cll4-214 (206-145) Frnna: Tlion~as Maunder <tom maunder a admin.sl~ate.ak.us> D:a!e: Wed, 11 Apr 2007 10:30:03 -0800 Tea: Vern Johnson <Vern.Johnson@eonocophillips.cotn> CC: Liz Galiuias <galiuec@conocophillps.com> ~-Q ~ ~-- ~ ~ S Vern and Liz, I was checking the log file as well as my emails and I still don't have a copy of this log. I'd appreciate if one of you would get a copy for me. Electronic is OK. Thanks, Tom Maunder, FE AOGCC Thomas Maunder wrote, On 2/1/2007 12:45 PM: Vern and Liz, Not sure which of you to send this to. I am reviewing the completion report for the well. Since this is an injection well, a bond log was required. I see that it was planned to use the sonic tool for evaluation. indicates the job went well. If that log is available, I'd appreciate getting a copy of it. Call or message with any questions. Tom Maunder, PE AOGCC Finally CD4-214 cement bond log Subject: Finally CD4-214 cement bond log From: "Galiunas, Elizabeth C" <Elizabeth.C.Galiunas@conocophillips.com> Date: Mon, 23 Apr 2007 16:07:49 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: "Johnson, Vern" <Vern.Johnson@conocophillips.com> Tom, Operations report Here is the long awaited cement bond log. I can bring you a hard copy also, for easier reading. Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-941-4871 Content-Description: CD4-214 BBL.pdf CD4-214 BBL.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 ~r~~ ~ ~~a 6/20/2007 7:36 AM `'FELL LOG TRati'SVIITTaL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 9901-3539 RE: MWD Formation Evaluation Logs: CD4-214, March 30, 2007 AK-MW-4720106 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a sib ed 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#: 50-103-20537-00. _ __R~ ~,~ :_, ;. _ - ~~~ ~~~"~ :~~ _ . ,~, • ®a.tl ti~7 C®1®TS~R~A~IO1~T C®1~'II~SI®-1dT , Jack Walker Production Engineer ConocoPhillips Alaska, Inc. PO Box 1003 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Pool, CD4-214 Sundry Number: 307-083 Dear Mr. Walker: • SARAH PAL1N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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 March, 2007 Encl. ~~~.. ~ ~~t~S Sincerely, } s* • • ConocoPhillips Jack Walker ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Phone: 907.276.1215 ~~~r~ March 2, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage AK 99501 MAR p ~ ~~'~7 Alaska Oit ~ Gas Cans, Cammissian Anchorage Re: Colville River Field, Nanuq Oil Pool, Well CD4-214 Dear Chairman Norman: Subject well CD4-214 was permitted and completed as a WAG service well in the Nanuq Oil Pool of the Colville River Field under Permit to Dri11206-145. ConocoPhillips Alaska, Inc. (CPAI) as operator of the Colville River Unit is submitting a 10-403 form for approval to treat CD4-214 with acid to improve productivity, and then produce CD4-214 via the permanent drill site facilities. We are also seeking an administrative approval to produce CD4-214 up to 60 days without an SSSV to monitor its gas:oil ratio (GOR) trend. The CD4-214 GOR was significantly higher than expected during the flowback. Understanding the GOR performance is needed. for improving the reservoir description and positioning future wells. CD4-214 was planned as an injector, and completed with a wireline-retrievable injection valve type SSSV which will not allow production. Installing apressure-operated SSSV (K-valve) would complicate the test program because well performance information is needed to properly set the K-valve, and the range of conditions during the transient flow period is very difficult to cover with a single K-valve setting. Operating the test without an SSSV will improve the quality of the test data. An SSV will be mounted immediately downstream of the wellhead. ` Please call me at 265-6268 with any questions. Very truly yours, ack Walker North Slope Operations and Development ConocoPhillips Alaska, Inc. Attachments ~ ~ 1%r3r~ STATE OF ALASKA RECEIVED MAR 0 2 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION AIBSka OtI & GaS Cuf'IS. COfiT1RlIS$1011 APPLICATION FOR SUNDRY APPROVAL Anl;halrage 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ tM~,,,,/( Waiver ^ Other ^ ' ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ~/'~ ~ Time Extension ^ Change approved program ^/ ~ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-145 ' 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20537-00 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 ^~ CD4-214 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380077, 384209, 388902 RKB 56' Colville River Field / Nanuq Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): -Junk (measured): 15072' 6280' - Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2620' 9-5/8" 2677 PRODUCTION 8639' _ 7" 8696' = _ SLOTTED LINER 6320' 4-1/2" 14814' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 8507 Packers and SSSV Type: Packers and SSSV MD (ft) Premier Packer ~ Packer = 7523' SSSV= PJfi4 ~ '~~ V~~N~ SSSV= 2189' 13. Attachments: Description Summary of Proposal ~ 14. Well Class .after proposed.work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: March 2007 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: Jack Walker @ 265-6268 Printed Name JBCk W 81k r e Title: Production Engineer ~ ~ Q ~ Signature ~'`Z`~{/C~ Phone 265-6268 Date 3 Z~O Commission Use Only Sundry Numbe~r:/ Conditions of approval: Notify Commission so that a representat ive may witness ~ / ' Qg~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~M\v;1S~i'~4~~~' ~~j~ 6E~Ci\ '~-d lie UCH ~~~Cs~ d~~~C_~ , Subsequent Form Required: ~„~~~ ~ ~ ~~~~` ~© ,~ =. ~ !~~ f$ 2~D~ ` APPROVED BY ~ ~~ 3 Approved by: STONER THE COMMISSION Date: ( Form 10-403 Revised 06/2006 V i ~~~~ ~ r" p/4/~ Submit in Duplicate ,`D3•$~~ • • Colville River Field, Nanuq Oil Pool Well CD4-214 Proposed Acid Treatment & Production Test March 2, 2007 1. Pull injection valve SSSV from profile at 2189'RKB. 2. Rig up temporary flowline to permanent CD4 drill site facilities with SSV with electronic controls with automatic, remote and local shut in capabilities. 3. Establish baseline performance by producing well and metering well rates via CD4 test separator. _ 4. Shut in well and treat horizontal, slotted liner completion with nitrified 12% HCl with corrosion inhibitor via coiled tubing. 5. Flowback CD4-214 to portable flowback separator with separator gas stream connected into facilities and separator liquid leg to atmospheric tanks. Neutralize flowback liquids as necessary and inject in approved Class II disposal well. 6. Divert well stream to permanent facilities, and produce up to 60 days. Test well every 10 days. -' Nanuq Sand Top Structure L~ - CD4-214 Openhole Log CD '~, I~'. 00052 / _ N'~`\ ~~~~ 1 I" of 006iL OOe4i OOL4S 009iT OOS4T 00 ii1 ' Ti ~ _ - II I I ' OOCST OOL 42 OOT ii OOOiT 006ti OOBES OOLCS / ~. J ~ I I I 009ET 005£1 OO iET OOE[i . , 5 I I I I II I I I OOZET OOiEi 000£S 006£2 OOBLS OOLLS : _ a }~~ I I I 009iT 005LT 00 iLT 00[Li OOLZS S / S / _ - - ~ I I I OOTL 00 OLS 006T2 f ~ _~ • OO BST 00 Lii 00925 00511 c l -` ` OO iii 00 ETS ` ~ - II I I I I OOETS aaiii oooii 00601 OOBOS OO LOS ~ i i. _ ~ I I 00901 005oT BB rot OOCOS ~!- -~ `t 00 LOS OOtOT 00002 ^f { ~ ~ 0066 OOB6 OO L6 ~' _` M N ~ oo9fi A~ ~ i A A W ^W^ ~ ~l~f OOS6 _ O i 0 O 0066 J i J i J OOE6 K d 9) O OO L6 OOT6 = a, C7 r i 0006 OOfi0 Dose Bo ce 0098 Dose ' = Z ° ° oar saao ~~ a~ ~n ,y ~B don Dos ao co m oo~ sans ~ oo~ waaa ~ t0 01 a Ol - C U f` ~ ~ Re: Nanuq Pool, CD4-214 Sundry • Subject: Re: Nanuq Pool, CD4-214 Sundry From: Thomas Maunder <tom_maundernadminstate.ak.us> Date: Fri, 02 Mar 2007 11:30:10 -0900 To: "R'alJ:er, Jack ~~" ~~~-.lack.A.Walker~~r-c~~nocophillip~.c~>>~~=~~ C'C:.lim LZr~,~~ `~~in1_rc~~~~(ri.adminstati~.ak.us=> L~ acs ~ ~ ~~~ Sack, I checked the file and the 407 has the well completed as WAG, so yes a 403 will be needed and yes you can cover all the activities in it. One thing I noticed on the 407 is that it is noted that there is no SSSV. While this is technically correct there is an injection valve which does provide subsurface control as required by the conservation order. It may be appropriate to note "injection valve" in that box with the depth. Call or message with any questions. Tom Maunder, PE AOGCC Walker, Jack A wrote, On 3/2/2007 11:10 AM: Thanks, Tom. Do we also need a 10-403 to produce it because it's permitted as a service well? If so, a single 10-403 can cover both the conversion and the acid work? Jack From: Thomas Maunder [mailta:tam maunder@admin.state.ak.us] Sent: Friday, March 02, 2007 9:57 AM To: Walker, Jack A Cc: Jim Regg Subject: Re: Nanuq Pool, CD4-214 Sundry Jack, Since an SSSV is required by the Conservation Order (562), the process to accommodate your request is an Administrative Approval (AA). Normally a letter request is submitted outlining the need (The document you included likely could cover this), describing the departure (no SSSV) needed and provides justifications in support of the action. Hope this helps. Message back to Jim and I with any questions. Tom Maunder, PE AOGCC Walker, Jack A wrote, On 2/28/2007 11:03 AM: Tom, Enclosed is the background information regarding the sundry request I mentioned. The CD4-214 was permitted & completed as an injector. It had lower than expected productivity and higher than expected GOR on a 24hr flowback. We would like to propose testing it, acidizing it, and then producing it for several weeks while monitoring GOR. i Jack «CD4-214 10-403 request.doc» 1 of 1 4! 11 /2007 10:40 AM C~ ConocoPhillips February 28, 2007 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Colville River Field, Nanuq Oil Pool, Well CD4-2I4 Dear Chairman Norman: • Jack Walker ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Phone: 907.276.1215 Subject well CD4-214 was permitted as a service well in the Nanuq Oil Pool of the Colville River Field under Permit to Dri11206-145. ConocoPhillips Alaska, Inc. (CPAI) as operator of the Colville River Unit is submitting a 10-403 form for approval to treat CD4-214 productivity with acid, and then produce CD4-214 via the permanent drill site facilities up to 60 days after the acid treatment to monitor its gas:oil ratio (GOR) trend. The CD4-214 productivity observed during its 24 hour flow back was much lower than expected and acid-soluble mud cake is suspected as the cause. The CD4-214 GOR was approximately significantly higher than expected during the flowback. Understanding longer term trend GOR performance is needed for improving the reservoir description and positioning future wells. CD4-214 was planned as an injector, and completed with accommodation for an injection valve and without ahydraulically-actuated SSSV. To help provide good quality well performance information, we are requesting approval to flow CD4-214 during the test period without an SSSV. An SSV will be mounted immediately downstream of the wellhead. Please call me at 265-6268 with any questions. Very truly yours, Jack Walker North Slope Operations and Development ConocoPhillips Alaska, Inc. Attachments • • Colville River Field, Nanuq Oil Pool Well CD4-214 Proposed Acid Treatment & Production Test February 28, 2007 1. Pull injection valve SSSV from profile at 2189'RKB. 2. Rig up temporary flowline to permanent CD4 drill site facilities with pilot-operated SSV. 3. Establish baseline performance by producing well and metering well rates via CD4 test separator. 4. Shut in well and treat horizontal, slotted liner completion with nitrified 12% HCl with corrosion inhibitor via coiled tubing. 5. Foowback CD4-214 to portable flowback separator with separator gas stream connected into facilities and separator liquid leg to atmospheric tanks. Neutralize flowback liquids as necessary and inject in approved Class II disposal well. 6. Divert well stream to permanent facilities, and produce up to 60 days. Test well every 10 days. r ~ ~ ~ ; ~~ a~ ~ ~~ ,~ c. ~~ ~, I I ~ ~- ., ~ ` ~ ~` ~~ >~ j ~ ~, ~ .. ~. l -.-., __ - j ~ ... ..... .... . 1 ,_ --~. _. :~, ~. - f: __ ..... _ ..... Nanuq Sand Top Structure N~~llfi r^ ~, ', I` L _. CD ~y~~ "~~ C ~'hii~ s Al k I ~ x[34-2'I4 c~nacc~ i as a, nc. Y:. TI' ... - - - APl: 5010.'i2453740 _...... Wet[ T . ----- -- - le TS- d cU ~ ~ 4.5e~, SSSV Type: NIPPLE prig Gomptetion: 71?14l20t>F Angts ~ TD: deg foam} ~- Arxruiar Fluid: Lasi Viflfl: Rev Reason:: Set tNJECTION is vaLVE Reference 32' RKB Rst L Date: Last U ts: 1137?2447 ~ Last T TD: 74819 ttK6 =rzeoucrft~ t4-85J8 . - , i. acr Tan (y:+r- A4aY Hrda r°...~. (1 r!r° rf~i , ~zarw, ~'. / Casi^~ St^in~- A~' S~RI~?S i ~{`5"~} suaFncl= -- Le-.r.xi uvu ~~cn Ta bu3Awi~ :rl Grede Thread rn-zsrr. CONDUCTOR 16.Ot~} 4 179 68.40 H-94 tNELD ac:ssz~ ;' ~~ SURFACE 9.$25 4 2677 90.44 L-80 BTC wf:ao_ma} ~ PRflDt1CT€ON 7.444 4 8696 26.40 L-84 BTCM ~ SLOTTED LINER 9.540 8999 79F?~ 1264 L-80 SLNT ut~~ lr Ih_ __ ___ t ~ ~ I F I . J ~ 3 - - Fe~oratians St;mmari _ I ~ r: Gas _,ft Mandral w l~~ s s, a ~s Gas Lilt __ _ : -: ~j. m Mrr~ F1ti. i ype w n;u r V TgPe 'r ,;,„~ -' ~~~~ ~ Date Rur. Jl, L A h~~ MardreWatvz , ~ ~ Gmnt t t?aa~-7azQ, ' -- -- ' 1 ~ i IQ CAMCO KBG-2 OV 3.4 BEK 5 0.: D 111612047 . : ' ~. ~ ~~ >!~\ , O,h ~ er tpl_. uga, egulp., etc j - C'?MPI E'S'!ON _ ,,,,. l~enxn I I ~ voe 1 E+exrEOxron _ ---T li.r _....-i 04~:J ~ YYI.LV -~IXiRBC t(rLV ILV JrIC3iti YYIrSCLilYG 4tUiLlC Y.JJCi*'IOt_1 YYfLVWnIVR ' 3.YJC3 'General Dotes _ _ _' t7ate INo:e... I 3t7d1? Mt7TF TRFF FMr`. d-1 f'#fi' Sf{rrtl nci -TREE d^AP C:E7NAtF(TICIPt 7" f'}TE.S PrkCKEr? 17523-7524, OD:5.970) ?i N€P (751-7582.. Oi5:5.LYf0} Pelf l8S38-14773} EEOTff=LI L@dER (84J&14814, f3t7:4.5C1p, YVt:t2.tit;} STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI SION WELL COMPLETION OR RECOMPLETION REPORT pin 1a. Well Status: Oil ^ Gas Plugged Abandoned ^ Suspended ^ WAG a 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. ell ass: Develop~e~th; ® 20~~ploratory ^ Service '' VV ~ Strat//igraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ,Q, orAband.: November 14, 2006 's'~c~~t~ ~a~S t,OnS. Cammiss~on 206-145 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 27, 2006 13. API Num er: 50-103-20537-00 4a. Location of Well (Governmental Section): Surface: 2947' FNL, 321' FEL, Sec. 24, T11 N, R4E, UM 7. Date TD Reached: November 9, 2006 14. Well Name and Number: CD4-214 At Top Productive Horizon: 1233' FNL, 2418' FWL, Sec. 25, T11 N, R4E, UM 8. KB Elevation (ft): 56' RKB MSL 15. Field/Pool(s): Colville River Field Total Depth: 1713' FNL, 26' FEL, Sec. 36, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 15072' MD / 6280' ND Nanuq Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377922 y- 5957465 Zone- 4 10. Total Depth (MD + ND): 15072' MD / 6280' TVD 16. Property Designation: ADL 380077, 384209, 388902 TPI: x- 375325 y- 5953942 Zone- 4 Total Depth: x- 378067 - 5948137 Zone- 4 11. Depth where SSSV set: no SSSV 17. Land Use Permit: ALK 380077 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1526' MD 21. Logs Run: GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 68# H-40 37' 114' 37' 114' 24" Portland Type III 9.625" 40# L-80 37' 2677' 37' 2365' 12.25" 595 sx Class G 7" 26# L-80 37' 8696' 37' 6210' 8.75" 207 sx LiteCRETE, 198 sx Class G 4.5" 12.6# L-80 8494' 14814' 6196' 6264' 6.125" slotted liner (refer to attachment) 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 8507' 7523' slotted liner from 8494'-14814' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector -waiting for facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corn) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE Form 10-407 Revised 12/2003 CONTINUED ON REVERSE 28-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-214 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 37.10' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 15,072.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. AnchoraQge`, AK 99518 Date ~o J ~.-o1~p7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) • ConocoPhilli 5 Casing Detail 9 5/8"Surface Casin_a • Well: CD4-214 _ Date: 10/29/2006 ~~ - 0'~~~ DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.38 FMC Gen V Hanger 2.24 36,38 Jts 3 to 69 67 Jts 9-5/8" 40# L-80 BTC Csg 2560.77 38.62 Halliburton Float Collar 1.14 2599.39 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 74.26 2600.53 Ray Oil Tools "Silver Bullet" Float Shoe 2.23 . 2674.79 2677.02 TD 12 1/4" Surface Hole 2687.00 12 1/4" hole 2687' MD - 2373' TVD 9 5/8" csg shoe 2677.02' MD - 2365' TVD TOTAL BOWSPRING CENTRALIZERS - 40 1 per jt on Jt #1 - #13 (stop ring on Jt #1 8~ 2 ) and over collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39, 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 65, 67. Joints in the pipe shed 75: jts to run 69 -Last 6 jts out c~~~ v C. ~'•~' ~ Use Best-o-Life 2000 pipe dope All joints drifted - 8.815" MU torque - 8600 ftllbs Remarks: tJp Wt = 173 k • D~ ~iVt - 137 tc f3lot~tc ~Nt - 75k Supervisor.• Burley /Hill Cement Detail Report CD4-214 .. Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10147730 10/26/2006 Cement Details __ - -- - Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 10/29/2006 10:30 10/29/2006 12:05 CD4-214 Comment Cem S ges - - - - - - - -- 'Stage # 1 _ _ _ Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Surface Casing Cement 36.0 2,677.0 No 130.0 Yes Yes Q (start) (bbl/min) Q (end) (bbllmin) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 4 8 620.0 1,020.0 Yes 25.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment ~Cement Fluids & Additives -- - -- - - - - - -- -- -- _ _ __ ~Fluld - - _ -~ Fluid Type Fluid Description T Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class - Volume Pumped (bbl) Lead Cement 36.0 2,177.0 360 G 285.0 Yield (ft'Isack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.77 10.70 Additives Additive Type Concentration Conc Unit label - Fluid - - - - Fluid Type Fluid Description - - -- - --- Estimated Top (ftKB) Est Btm (ftKf3) Amount (sacks) Gass 'Volume Pumped (bbl) 2,177.0 2,677.0 235 G 235.0 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 15.70 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 11/15/2006 Daily Drilling Report C D4-214 ~, Report Date: 10/29/2006 Report Number Days From Spud (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) Wellbore 4 2.73 2,687.0 2,687.0 0.00 CD4-214 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftK6) 10/27/2006 DOYON 19 NANUQ Development 14,735.0 AFE I RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10147730 6,427,648.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,677.OftKB Ops and Depth ~ Morning Report Daily Cost Total Cummulative Cost Rigging up Geospan. 265,362.80 813,741.85 24hr Forecast Daily Mud Cost Cummulative Mud Cost Test BOPS. PU BHA ,RIH drill rathole, FIT. Drill ahead. 7,710.70 41,235.75 Last 24hr Summary RIH and cement surface casing. NU Riser and BOP. Start BOP test General Remarks Weather Head Count 23/8 SE@ 16-21 mph 45.0 S:~pervisor _ _- I'it1~ Dave burley Rig Supervisor Larry Hill Rig Supervisor Time Log _. _ . . . -. _ - -... r a Start F-~d '. Dur ~ ~ ,~ N Tinu: D EBi Sty L~ P~`' Eii:~ P T~ii Time {hrs) PI ~,~~ ~n cede O Sub-Co. T . Trbl Code itl C,~ass f~KH: i`, Y.H; r rn ,'G~ ' 00:00 01:00 1.00 SURFAC DRILL PULD ar tools from rig floor P 163.0 0.0 Lay down BHA components - cle 0000 - 0200 hrs Time change to 0100 hrs -Day light savings time 01:00 02:30 1.50 SURFAC CASING RURD P 0.0 0.0 Rig up to run 9 5/8" casing 02:30 02:45 0.25 SURFAC CASING SFTY P 0.0 0.0 Prejob safety and Opts meeting for running casing 02:45 05:45 3.00 SURFAC CASING RNCS P 0.0 1,715.0 Run 9 5/8" 40# L-80 MBTC csg as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Howco) 2 jts. csg (first 4 connections made up w/ BakerLoc -filled pipe & checked floats) 41 jts csg to 1715' 05:45 06:15 0.50 SURFAC CASING CIRC P 1,715.0 1,715.0 Stage pumps up to 5.5 bpm -circulate and condition mud - FCp 320 psi 06:15 07:45 1.50 SURFAC CASING RNCS P 1,715.0 2,677.0 Continue running 9 5/8" - 40# L-80 MBTC csg f/ 1715' to 2638' - 24 jts (69 jts total ran) - PU FMC csg hanger & landing jt. -Land csg w/fluted mandle hanger on landing ring w/ float shoe @ 2677' & float collar @ 2599' 07:45 08:30 0.75 SURFAC CEMENT PULD P 2,677.0 2,677.0 Lay down fill-up tool -blow down top drive - RU cement head 08:30 10:00 1.50 SURFAC CEMENT CIRC P 2,677.0 2,677.0 Establish circulation @ 3.0 bpm / 210 psi -staged pumps up to 8 bpm -reciprocate pipe PUW 173k SOW 137K -circulate and condition mud for cementing -full returns throughout - FCP 8.0 bpm / 410 psi - PJSM Latest BOP Test Data Date CommenF Page 1/3 Report Printed: 11/14/2006 Daily Drilling Report CD4-214 Report Date: 10/2912006 'Time Lo __ _ -- _ Start End Dur - Tune _ __ _ ---- ~, °t.+rt ~ C1e PtPi ~~„ i - - De r ~ Time Time lhrs) Pr~asc ~ ~t° C~ it ioSi~u .,.,.. F N-T Conia.'Op_a:~n Trbl ! uTC .:~ L.a.~. .Y•E'. ;`tt';E, 10:00 12:00 2.00 SURFAC CEMENT DISP P 2,677.0 0.0 Cement 9 5/8" csg as follows :Pumped 4U bbls Biozan water w/ nut plug as marker -Pumped 5 bbls water w/ Dowell -Tested lines to 2600 psi -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 285 bbls lead slurry (ASL) @ 10.7 ppg (` Observed nut plug marker @ shakers w/ 271 bbls lead pumped -pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 177.8 bbls 9.8 ppg water base mud -Displaced @ 8.0 bbls/min for first 170 bbls - slowed to 4.2 bbls/min for last 7.8 bbls -Bumped plug w/ 1020 psi (prep bump pressure 620 psi) Check float (held OK) CIP @ 12:05 hrs. -Full circulation throughout job w/ 130 bbls 10.7 ppg cmt returns to surface - reciprocated pipe while circulating 8~ through cement job until last 82 bbls of displacement 12:00 12:45 0.75 SURFAC CASING DHEQ P 0.0 0.0 Line up and test 9 5/8" casing to 2500 psi for 30 minutes 12:45 14:30 1.75 SURFAC DRILL RURD P 0.0 0.0 RD cement head, LD landing joint. LD riser. Change bales and elevators. XO Saver sub to XT-39. MU Wellhead. 14:30 16:00 1.50 SURFAC DRILL RURD P 0.0 0.0 Clear floor, rig up welding equipment to work on stabbing board. 16:00 17:30 1.50 SURFAC DRILL PULD P 0.0 0.0 NU BOP, install flowline and turnbuckles. 17:30 19:00 1.50 SURFAC WELCTL OTHR P 0.0 0.0 Install test plug, fill stack and manifold with water. Pressure up and test for leaks. OK 19:00 19:30 0.50 SURFAC WELCTL BOPE P 0.0 0.0 Test annular 250/3500. OK 19:30 00:00 4.50 SURFAC WELCTL BOPE T Well BOP's 0.0 0.0 Attempt to test top set varible bore rams, did not test. Control XO seal on choke shock hose. Did not test. XO rubber System elements on top set varible rams. Mud Check Data _ I ~ - _ _ Type I Ci~t,•h~tthCii ~DemjlUigal) vistsiyG F'`vi;aiC{cpj Spud 2 60 9.80 78 30.0 _ n i H i FiP Filt Denslt TPn /P r~lr. Gef (10s) Gei !r")m;' ( ~' iviBT b/UGi~ pt{ { ~) -' i' S he rorr - fl~„ ~Of.°) {Ibf7100ft~} Qbfl1 ..tN) ~ iv,~~J...~ ~ t ) ~ mL~30min F 25.000 5.000 11.000 17 000 25.0 9.8 ~__ ~__ --1 _ _ _ 1_ -- -- -- !- In'ection Fluid - _ _ - Fluid S~u.ce Diesel Other __ _ - _ _ T ~ _Fr mL?a ihbll r D ainstior --.. .Note 15.0 CD4-208 614.0 CD4-208 Water 155.0 CD4-208 Water Based Mud 1469.0 CD4-208 Drill Strin s: 8HA No. 2 - 8.75 Geo-Pilot.! Bit Run No. 2 - 8 3/4in, Halliburton Securi DBS , FS2463 , 10807513 Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (ins) Nozzles (l32") IADC Bit Dull String V11t (10001bf) YYOB (max) (700... WOB (min) (1000... 2,596.0 8,706.0 0.98 16/16/16/16/16 2-3-BT-A-X-O-ER-TD 69 25 15 Drill Strin g Components - _ - - - J'= I Item Description fl6r nnl - l6 (inl Tcn, r. Sz i,in? T~~ Thraad Cum Ler. i,fti _ 1 -- - 7600 Geo Pilot 6 3/4 1.500 4 1/2 NC 50 21.60 1 Non-Mag GP DM Flex 6 3/4 1.500 4 1/2 NC 50 30.80 1 Stabilizer (Non Mag) ILS 6 3!4 1.920 4 1/2 NC 50 33.01 1 MWD (Logging) 6.71 1.920 4 1/2 NC 50 54.07 1 Stabilizer (Non Mag) 6 3/4 1.920 4 1/2 NC 50 56.27 1 MWD (Logging) H-Cim 6.78 1.920 4 1/2 NC 50 63.02 1 MWD (Dir & Logging) T-M 6.77 1.920 4 1/2 NC 50 72.95 1 Float Sub NM 6.6 2.813 4 1/2 NC 50 75.33 3 NMDC 6.64. 2.813 4 1/2 NC 50 167.31 3 HWDP 5 3.000 4 1/2 NC 50 257.16 1 Drilling Jars -Mechanical 6 1/4 2.250 4 1/2 NC 50 289.48 Page 2/3 Report Printed: 11/14/2006 Daily Drilling Report CD4-214 Report Date: 10/29/2006 Drill Strin Components _ .its Berm Description -- OD (in) iD (in) Top ConnSz (ir~ Tn~ Thread _ _- Cun~ Lf~ (ft) - 14 HWDP 5 3.000 4 1/2 NC 50 712.98 1 Drill Pipe 5 4.276 4 1/2 NC 50 744.73 1 Ghost Reamers 6.54 2.875 4 1/2 NC 50 750.79 33 Drill Pipe 5 4.276 4 1/2 NC 50 1,796.89 1 Ghost Reamer 6.54 2.875 4 1/2 NC 50 1,803.84 2 Drill Pipe 5 4.276 4 1/2 NC 50 1,867.50 1 Cross Over 5 4.276 3 1/2 XT-39 1,868.86 tlrillina P aramPtPrc !~i ~ nq Time Sliding Hrs (~.;rr D " Q ~~~.+-; b Sri tthH': Fred (ftKB) - ~ ,`gal (miNft) Cum Depth rft, 11 1.00 Time hrsi L.t Depth (ft~ _ - 9F~"~; 1.C.., w:f;. RPht ~:;:,, , I„ APP (p~ij ' Dill Ta '~ --- - - 650 25,000.0 50 2,420.0 5,000.01 - - - Wetlbores -- - 1 Wellbore Name _ Wellbore APi !UWI CD4-214 501032053700 Soy-lion - COND1 ----_ gi linl __ ___ i AdT ~: [ 16 RD Act Btm(ffKB~ ~ t~-Date I End Date 36.0 114.0 10/26/2006 10/26/2006 SURFAC 12 1 /4 114.0 2,687.0 10/27/2006 10/28/2006 INTRM1 8 3/4 2,687.0 8,706.0 10/30/2006 11/2/2006 PROD 1 6 1/8 8, 706.0 15,072.0 11 /4/2006 11 /9/2006 Cement - -- Surface Casin Cement -Started 10/29/2006 Type Wellbore String Cement Evaluation Results casing CD4-214 Surface, 2,677.OftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 36.0 2,677.0 4 620.0 _ 61.;Id --_ Class Amount (sacks) I V i onl] Danstiy {~btgal) Yield {R'Isack) Fst Top (ftKB) ', (_,~~ Btrr (ftKB) Lead Cement G 360 285.0 -- - 10.70 4.45 36.0 2,177.0 G 235 235.0 15.70 1.17 2,177.0 2,677.0 Page 3/3 Report Printed: 11/14/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-214 Rig: Doyon 19 Date: 10/30/2006 Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: Burley/Hill/Winfree Pump used: ' #2 Mud Pump ~ ~, T f T ~ P i d ~ Strokes ~ 0.1000 Bbls/Strk ~ 8.OOi Strk/min ~ I OpenholeTest LoT/Frr ype o est: ump ng own drillpipe. Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 36.4 Ft 2677.0 Ft-MD 2365.0 Ft-TVD 2707._0 Ft-MD 2410.0 Ft-TVD Strks si Min si Strks si Min si Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 20 0 2590 0 10 0.00 1020 Casin Test Pressure Int e rit Test 2 180 1 2580 1 30 0.25 960 Mud Weight: 9.8 ppg Mud Weight: 9.7 ppg 4 450 2 2580 2 80 0.50 910 Mud 10 min Gel: 21.0 Lb/100 Ft2 Mud 10 min Gel: 35.0 Lb/100 Ft2 6 740 3 2580 3 ~ 190 1.00 850 Test Pressure: 2500.0 psi Rotating Weight: 130.0 Lbs 8 920 4 2580 4 310 1.50 820 Rotating Weight: 0.0 Lbs Blocks/Top Drive Weight: 74.0 Lbs 10 1090 5 2580 5 410 2.00 Blocks/Top Drive Weight 74.0 Lbs Desired PIT EMW: 18.0 ppg 12 1280 6 2570 6 510 2.50 i Estimates for Test: 1.9 bbls Estimates for Test: 1021 psi 0.8 bbls 14 1460 7 2570 7 620 3.00 765 ~ ~I 16 1660 8 2570 8 720 3.50 750 EMW =Leak-off Pressure + Mud Weight = 1040 + 9 ~ PIT 15 Second 18 1880 9 2570 9 . 800 4.00 745 0.052 x TVD 0.052 x 2365 Shut-in Pressure, si 20 2140 10 2570 10 870 4.50 745 EMW at 2677 Ft-MD (2365 Ft-ND) = 18.2 9so 22 2340 15 2570 11 940 5.00 740 sooo Lost 20 ps i durin g test, held 24 2590 20 2570 12 990 5.50 740 99.2 % of t est pre ssure . 25 2570 13 1040 6 00 735 . 30 2570 6 50 735 2soo - . 7.00 735 __ _ _ 7.50 730 8 00 72 Zooo . 5 - - 8 50 725 w . ~ _ - - 9 00 725 -- - . isoo 9.50 725 N _ - _ w _ 10.00 725 fY _ - a _ _ l1~ \ - o 0 1 2 3 0 5 1 0 1 5 2 0 2 5 3 0 ~~CASING TEST Barrels tL EAK-OFF TEST S hut-I O P n tim IT Poin e, M t inute s Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back S S S S Comments: Tested 9 5/8" csg after bumping plug on cmt. Job LV 1 trU4-L 14 SUfTdGe Summary • • 7" Csg Detail ConocoPhillips Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM Company Well: CD4-214 Date: 11/3/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.40 FMC Gen V Hanger 2.64 34.40 Jts 3 to 203 201 Jts 7" 26# L-80 BTCM Csg 8570.71 37.04 Halliburton Float Collar 1.04 8607.75 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 85.35 8608.79 Ray Oil Tools "Sliver Bullet" Float Shoe 2.08 8694.14 7" Shoe @ 8696.22 8 314" hole TD @ 8706.00 8 3/4" hole TD @ 8706.' MD / 6210.26 TVD 7" Shoe @ 8696.22' MD / 6209.58 ' TVD Total Centralizers: 60 Straight blade centralizers one per jt. on jts. # 1-15 Straight blade cent. one per jt. on jts. # 106 - 118 Straight blade cent. One per jt # 141 - 143 Straight blade cent. One every other jt. 145 to 201 215 jts in shed - 203 total jts. to run Last 12 jts. Out Used Jet Lube Run-N-Seal i e do e Remarks: Up wt - 285 k Dnwt-160k Blocks - 70k Make up torque - -8000 ft/Ibs Supervisor.D. Lubick/D. Mickey ~ \ Cement Detail Report CD4-214 Intermediate Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10147730 10/26/2006 ---_ Cement Details _ __ _ _ _ _ _ Description _ Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 11/3/2006 12:30 11/3/2006 15:30 CD4-214 Comment Cement Stages Sta a#1 -- Description Objective - -- - Top (ftK6) Bottom (ftK6) Full Return? Gmnt Rtm (... Top Plug? Btm Plug? Intermediate Casing 4,400.0 8,696.0 Yes Yes Yes Cement Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 3 8 650.0 1,150.0 Yes 25.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) ~.omment __.~ _ __. Cement Fluids 8~ Additives 'Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) CW-100 1,632.0 3,016.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) 8.30 Isacksl Class __ _ -- Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est 8tm (ftK6) Amount (sacks) Class MudPush 3,016.0 4,400.0 Yield (ft (sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickeninc 10.50 Additives Additive Type - Fluid - --- _ ~ -- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Lead Cement 4,400.0 7,696.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) 3.35 11.20 11.00 Additives Additive Type -__ Fluid _ _ - - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Tail Cement 7,696.0 8,696.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) 1.16 5.09 15.80 Additives Additive Type .(sacks) Class 207 LiteCrete (sacks) Class 198 G Fluid _ _ - - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Water Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) 8.30 Additives Additive Type Fluid ___ _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Mud Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) 9.80 Page 1/2 ___ \mount(sacks) ~Giass 'umpi 40.0 Conc Unit label Volume Pumped (bbl) 40.0 lume Pumped (bbq 132.0 IVoiume Pumped (bbl) 41.0 Volume Pumped (bbl) 20.0 me Pumped i 308.3 ~rStr 1 (psi) 11 /14/2006 Daily Drilling Report CD4-214 ,. Report Date: 11/3/2006 Report Number Days From Spud (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) Wellbore 9 7.73 8,706.0 8,706.0 0.00 CD4-214 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftK6) 10/27/2006 DOYON 19 NANUO Development 14,735.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ff/hr) 10147730 6,427,648.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Intermediate, 8,696.OftKB Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost RIH w/ BHA 449,119.81 2,156,418.82 24hr Forecast Daily Mud Cost Cummulative Mud Cost C&S drill line - CO shoe track -FIT -- CO to OBM -Drill 6 1/8" hole 2,872.81 155,564.72 Last 24hr Summary Run 7" & cmt 7" csg -Test csg to 3500 psi -Set & test pack off - RD f/ cmt job - MU BHA #3 General Remarks Weather Head Count 6/-6 we / NE @ 7 mph 48.0 -- - Donnie Lutrick Rig Supervisor Don Mickey Rig Supervisor Time Lo ---- - - Start End Dui ~ Tune D~oth Stert Depih Fnd Time Time %hrsi Fhasa Op Cude OpS~,tr-Cc r'N-T~~. T~b, Code T r... lass ~ (ttKBl (ftK6 ' CorimlOperation 00:00 03:45 3.75 INTRMI CASING RNCS P 0.0 3,431.0 Run 7" 26# L-80 BTCM csg as follows: FS (Ray Oil tools silver bullet) 2 jts. csg - FC (Hallibutton) 2 jts. csg (first 4 jts. made up w/BakerLoc -filled pipe & checked floats) 76 jts to 3431' (80 jts total) 03:45 04:30 0.75 INTRMI CASING CIRC P 3,431.0 3,431.0 Break circ -stage pump to 5.5 bbls/min. -Circ btms up + @ 350 psi - PU 145 SO 130 04:30 08:30 4.00 INTRM1 CASING RNCS P 3,431.0 7,040.0 Continue running 7" 26# L-80 BTCM csg - f/ 3431' to 7040' (165 jts total) 08:30 09:30 1.00 INTRM1 CASING CIRC P 7,040.0 7,040.0 Break circ & stage pump to 4.5 bbls/min -Circ btms up + - ICP - 510 psi FCP - 420 psi - PU 245 SO 155 09:30 11:30 2.00 INTRM1 CASING RNCS P 7,040.0 8,696.0 Continue running 7" 26# L-80 BTCM csg f/ 7040' to 8659' (201 jts total) - PU FMC fluted hanger & landing jt. -Land 7" csg w/ FS @ 8696' FC @ 8607' - RD fill up tool & RU cmt head 8 lines 11:30 13:00 1.50 INTRMI CEMENT CIRC P 8,696.0 8,696.0 Establish circulation -stage pump up to 6 bbls/min - circulate & condition for cement job Final mud properties - Wt. 9.8 ppg Vis 41 PV 9 YP 16 13:00 16:00 3.00 INTRMI CEMENT DISP P 8,696.0 8,696.0 Cement 7" csg as follows: Pumped 5 bbls 8.3 ppg CW-100 -Test lines to 3500 psi -Pumped 35 bbls 8.3 ppg CW-100 - 3.5 bbls/min @ 280 psi -Drop btm plug - Pumped 40 bbls 10.5 ppg MudPush 5 bbls/min @ 400 psi -Mixed & pumped 132 bbls 11.0 ppg Lead slurry LiteCrete) 5.7 bbls/min @ 400 psi -Mixed & pumped 41 bbls 15.8 ppg Tail slurry (Class G w/ additives) 5 bbls/min @ 180 psi -Drop top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 308.3 bbls 9.8 ppg LSND mud - 6 bbls/min @ 960 psi for first 290 bbls -slowed pumps to 3 bbls/min @ 650 psi for last 18.3 bbls -Bumped plug w/ 1150 psi -Checked floats OK - CIP @ 15:29 hrs. -Full returns throughout job - reciprcated pipe until beginning of displacement w/ rig pumps 16:00 16:30 0.50 INTRMI CEMENT OTHR P 8,696.0 8,696.0 Tested 7" casing to 3500 psi for 30 mins. 16:30 17:30 1.00 INTRM1 CEMENT RURD P 8,696.0 8,696.0 RD cmt lines LD cmt head & landing jt.- LD csg elevators & spider Latest BOP Test Data Da Comment 10/30/2006 250/5000 si Page 1/2 Report Printed: 11/14/2006 Daily Drilling Report CD4-214 Report Date: 11/3/2006) - - - - Time Log Sta' En j~ ar - I urn ~ ---- fl ~ h SIhrt~D~-uL, Gnj ~; Tcn~- Iri ~, hisi Ft ;use f7p Coin ~rIF ~~'Jv (,u P-N T 7rbl Coi, Irnl Wass iflH B) ftt:Ri ~onm/Oynration 17:30 21:00 3.50 INTRMI CASING OTHR P Pull thin wall wear bushing -Install & test 7" x 9 5/8" pack-off & test to 5000 psi -Change top pipe rams back to 3 1/2" x 6" VBR -Test to 250 & 5000 psi -Set wear bushing L I:UV UU:UU 3.UU IN I KIVI1 UKILL F'VLU Y I I U.U ~ B/.V I rvw onri ~ o - o lio un, vc~nwi -mvvv - vNwau mvvv Mud Check Data f ~ f -- _ 1 vr~ ~,3i~_ ~~~~i ii: ~i r;u i ,r~;l r, i °~c~„~, i, ~ HiHN Fdt 1 oer,~~t~ T~~~.,o I .~_i i. r_~~r I yF= Depth {ftKH) Dens (Iblgyll V s : ~~ LSND ~ 8.706 0 9 ~0' 4~ ~ r ~r i;;r~ it~t~~~~xm°; 5 0 16 000 (i~I~~oor~) {Ibrraixm=} {ibrJ~Wn~} rmBrpbro.~;; mu3omin) uN r, ____ '`ti; _ 85 8.8 9 1 10.000 1 f> 0 8.000 8.00 ~~ ~ -- ~ -- -- Injection Fluid ~ FLnn _- -_ - --- _ Source 1 - FfOf1L=3 r : ~ ht;'~; L ~ a~~c.~, - - - - - a-pie _ Water Based Mud 1 - - - - .- - . 1400.0 CD1-1 ~ - - f%CD4-214 - - - - Wellbores I - - - Wellbore Name - - iWel lbore APl/UW I CD 4-~ 14 90103205300 SecSion ___ Si COND1 SURFAC - --- _Nini Ae~Top(ftKB) 16 ~ ~ 36.0 12 1/4 114.0 ArtBtm(ftKBI SlartDate T EndDafe 114.010/26/2006 10!26/2006 2,687.0 10/27/2006 10/28/2006 INTRM1 8 3/4 2,687.0 8,706.0 10/30/2006 11/2/2006 PROD1 6 1/8 - 8,706.0 - 15,072.0 11/4/2006 - - -- 11/9!2006 - - - - Cement - -- Intermediate Casin Cement -Started 11/3/2006 Type Wellbore String Cement Evaluation Results casing CD4-214 Intermediate, 8,696.OftKB Stg No. Description Top (ftK6) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Intermediate Casing Cement 4,400.0 8,696.0 3 650.0 Fluid -I . ~:as Amount {sans) I V jt,bp Density pblgat} Yfeid {R'Jsack) Esi 1 -ap (RKB} Es_ 8tm {RKB} CW-100 40.0 8.30 1,632.0 3,016.0 MudPush 40.0 10.50 3,016.0 4,400.0 Lead Cement LiteCrete 207 132.0 11.00 3.35 4,400.0 7,696.0 Tail Cement G 198 41.0 15.80 1.16 7,696.0 8,696.0 Water 20.0 8.30 Mud 308.3 9.80 Page 2/2 Report Printed: 11/14/2006 ' h ~ CD (fl I~ L(7 Lf) ~ In O ~ In ~> Ln O In ~ O In N O ~ CO ~ (O O Lf) O lf> ' OO In f~ lf) I~ lf) (O lf~ ~ l(1 M In ~t In ~ lf) ' Y C ._ Q In In lf) In lf ) l1~ In In Ln In In l.l) LC ) d V 7 N +~+ H 7 m ~ ~ c ~ ~ ~ C O ~ O tn O ~ ~ ~ N tf') N M tl~ M ~ ~ d' to O ~ (O ~ CO I~ ~ f~ OO In 00 O tn O O ~ p'0 ~ ~ m ~ m d d ap C - O ~ N C O ' a' M N O N O C O ~ N f~ p y .a ao ~ ~ M O ~ c0 tD ~ 00 M 0 C0 O 00 O ~ (D ~ CO ~ C~ lC) CO ~ CO H N N •~ ~ ~ ~ ~ , ~ d ~ Q_ N ~ O ln O ~ tf') ~ N ~ N M N M ~ M ~ ~ ~ to tn In N O ~ 7 mo d , -- m m c .: N °' d V ~ R m ~ N ~,,, ~ L ~ ,~ O ~ N M ~' ~ Cfl l~ a~ 0 0 ~ Lf) ~ O N H N O M ~ ; d ~ ~ m ++ c ' ~ ~ d H C U C ~ °' E ' E c ~ a m ja . >' ~ f' ~ ~ o ~ y M o > ~~ a ~ W c O I ..:! M ~ d ~ i V1 ~ ~C y r ~ 6) O G> N VI (O ~ ~ o C ~ Q _ ~ ! ~ ~ ~, ~ ~ ~~- a~ aH L ~a ~ ~' ; ~ ~., y~ c m 0 +, N a- as ai ~ c . m m F M O ; O N. ~ ~ ~ ° W ~ a ~ ci v o ~ ~ i r co w a 3 t ~ :. ~ o c ~- Z J J ~ - c = ~, = 'L i ~ ~ ~ i d 3 D ~ ti ~ ~ i , W a ~ ~ °' c s° ~ y "N ~ ~ °'o~ ~~ ~ I I ~ V a s ~ ~ 0 _ o ~ O E E ~' y "~ ~ o ~ 0 Q1 N W Z ~ 7 a 7 a a (6 d I ~ o H ~ ~ r + ~ ~ _ ~ ~ N N r ~ ~' ~ N t a ~ `~ m W p p K 11 ~ ~ ~ w ~ rn ~ U ~ O N O I v~ 0 ~ ~ r ~ ~ ~ ~ a W 07 ~ ~ Q ~ Q, ~ R , ~+ I,L I I J ~ Y ~ c .y ~ ~ ~ ~n N ~ C ~ ~O i ~ U n l0 V a, ~ .`-~ M J ~ ` ~ ~ ~ +T rn C C II `-~ ~ N M ~ ~ ~ CO CV ~ O , i C fC f0 U U rr CQ CI C • i n .- II ~ H 1k ~ 0 !d 3 ._ ~ ~ ~ ~ LL i ~ l4 m ~_ d N ~ ~~ J "" ~L v d Q ~ 'd 14 ~ ~ ~ ( i I ~". (~ o to U ~ ~ ~ ~ ~ L lC w ~. L t °' N + ~, ~ D ' I i ~ ~ C .~ ~ ~ a ~ ~ ~ ~ c ~~ 3 a • ~ o o a~ ~ L ~ ~ N~ ~ y ~ ~ z ¢ ca U Q ~ 3 o I a ix~ ~ co ~' y ^? N O 4? C N O O d N W i V tf~ ~ ~~ 2 m ~ O ~ i ~ I ~' ~ O H • H fn y ~ - ~ ~ ~ LL 01 p L ~ O Y p ~ 2 C ~ ~~ U ~ C L ~ t0 0 ° i ~ N ~ ~ H Gd N m Y ~ () V • ~~~ c N .~- w '0 •L ~ J II i°n o h ii N Z ~ ~ N .N ~ ~ m 3 3anss3ad ~ d ~ •c O o = o ~ Ew ~p •N ;=, ~ W o U ConocoPhillips January 19, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-214 (APD 206-145) Dear Commissioner: ~p ~ ~ ~ ?OCR.. ~s ~~rr~s. ~~.;~,,;, ., ~~~~r~rr~~~, -...~ ConocoPhillips Alaska, Inc. submits the Well Completion Report for the recent drilling operations on the Alpine well CD4-214. 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 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 GCA/skad • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ~~ S.~ N ~ ~' ~~ r, 1a. Well Status: Oil ^ Gas Plugged Abandoned ^ Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: ,. Development ^ Exploratory ~^-II Service ^~ Stratigraphic TesILJ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., y~.o9 f 3 ~' or Aband.: November , 2006 12. Permit to Drill Number: 206-145 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 27, 2006 13. API Number: 50-103-20537-00 4a. Location of Well (Governmental Section): Surface: 2947' FNL, 321' FEL, Sec. 24, T11 N, R4E, UM ~ 7. Date TD Reached: November 9, 2006 14. Well Name and Number: CD4-214 At Top Productive Horizon: 1233' FNL, 2418' FWL, Sec. 25, T11 N, R4E, UM 8. KB Elevation (ft): 32' RKB 15. Field/Pool(s): Colville River Field Total Depth: 1713' FNL, 26' FEL, Sec. 36, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 15072' MD / 6280' ND Nanuq K yNi~ Oil POOI ' ~' Z~' G ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377922 * y- 5957465 ' Zone- 4 10. Total Depth (MD + ND): ~ 15072' MD / 6280' TVD ~ 16. Property Designation: ADL 380077, 384209, 388902 TPI: x- 375325 y- 5953942 Zone- 4 Total Depth: x- 378067 - 5948137 ~ Zone- 4 11. Depth where SSSV set: no SSSV 17. Land Use Permit: ALK 380077 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 759' MD 21. Logs Run: GR/Res/Dens/Neutron 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE G AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTIN RECORD PULLED 16" 68# H-40 32' 114' 32' 114' 24" Portland Type III 9.625" 40# L-80 32' 2677' 32' 2365' 12.25" 595 sx Class G 7" 26# L-80 32' 8696' 32' 6210' 8.75" 207 sx LiteCRETE, 198 sx Class G 4.5" 12.6# L-80 8494' 14814' 6196' 6264' 6.125" slotted liner (refer to attachment) 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 8507' 7523' SIOtt2d Ilner - 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector -waiting for facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ' NONE ~~ yrt~~i~ ---~ , Form 10-407 Revised 12/2003 CONTINUED O ` ~~ rCAC ~ t~ ~~~,07 NAL 28. 29. 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". CD4-214 Nanuq sand 8633' ~ 6206' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT, slotted liner detail sheets 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. Alvord Title: Alpine Drillino Team Leader Signature Phone u ~ ~ (~ (2o Date (~(ti ~~~ INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same. as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interva- 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 • r~ CanacciP~hillps Time Log Summary tNelNiew Web f2eAOrt+ng Well Name: CD4-214 Job Type: DRILLING ORIGINAL ____ ~ fiime Logs _ ~ __ __ Date__ __ From To Dur S_De_pth_ E_De~th__Phase Code Subcode T COM _ __ 10/26/200615:00 23:30 8.50 0 114 MIRU MOVE PSIT P MIRU 23:30 00:00 0.50 114 114 MIRU DRILL RURD P NU riser. Rig accept 23:30 hrs. 10/27/2006 00:00 02:00 2.00 114 114 MIRU DRILL RURD P Continue to NU riser and lines. Spud mud to its. 02:00 03:00 1.00 114 114 MIRU DRILL PULD P Pick up BHA -Bit Motor Float Sub. 03:00 03:30 0.50 114 114 MIRU DRILL SFTY P Pre Spud meeting. 03:30 05:30 2.00 114 114 MIRU DRILL PULD P Continue MU BHA- MWD- Orient- set UBHO and load tools. 05:30 06:15 0.75 114 114 MIRU DRILL DHEQ P Fill hole check for leaks. Test lines to 3500 si 06:15 06:30 0.25 114 117 MIRU DRILL PULD P MU stand of NMFC and Jars. Tag up at 117'. 06:30 12:00 5.50 117 530 SURFA DRILL DDRL P Drilled 12 1/4" hole from 114' to 530'. MD/TVD ADT 2.88 hrs ART 0.66 hrs AST 2.22 hrs. WOB 9 K, RPM 0/50, GPM 450PP 900 psi. PU Wt 100. SO 105. ROT 100 K Torq ON 5000 Off 4500 Ft Lbs. 7 G ro surve s. 12:00 00:00 12.00 530 1,549 SURFA DRILL DDRL P Drilled 12 1/4" hole from 530' to 1549' MD/1466' TVD. ADT 9.15 hrs ART 4.69 hrs AST 4.46 hrs. WOB 20/30 K, RPM 50, GPM 600 PP 1940 psi. PU Wt 120. SO 125. ROT 120 K Tor ON 5000 Off 4500 Ft Lbs. 10/28/2006 00:00 12:00 12.00 1,549 2,464 SURFA DRILL DDRL P Drilled 12 1/4" hole from 1,549' to 2,464' MD/2200' TVD. ADT 8.18 hrs ART 5.31 hrs AST 2.87 hrs. WOB 20/30 K, RPM 50, GPM 650 PP 2480 psi. PU Wt 141. S0 127. ROT 137 K Tor ON 7500 Off 6000 Ft Lbs. ~~~~ F~age 1 of 12 ~J Time Low _ _ _ -_ _ _ Date From To Dur S_D th E. De th Pha~e Code Subcode T COM___ __ __; 10/28/2006 12:00 15:15 3.25 2,464 2,687 SURFA DRILL DDRL P Drilled 12 1/4" hole f/ 2,464' to 2687' MD TD Surface Hole ADT 2.92 hrs ART 2.22 hrs AST 0.7 hrs. WOB 20/30 K, RPM 50, GPM 650 PP 2490 psi. PU Wt 145. SO 130. ROT 140 K Tor ON 7500 Off 6000 Ft Lbs. 15:15 15:45 0.50 2,687 2,596 SURFA DRILL CIRC P Circulate and flow check. Pump out 1 std from 2,687' to 2,596' with 60 RPM 600GPM and 1980 si. 15:45 19:00 3.25 2,596 887 SURFA DRILL TRIP P Flow check OK. Continue POOH to base of permafrost at 1,648' with 60 RPM, 450 GPM, 1,270 psi. Continue out of hole to 887' Flow check OK. 19:00 20:15 1.25 887 2,596 SURFA DRILL TRIP P RIH to 2,596'. 20:15 21:00 0.75 2,596 2,687 SURFA DRILL CIRC P Break circulation, wash to 2,687'. Circulate and condition for 9-5/8" casin . 21:00 00:00 3.00 2,687 163 SURFA DRILL TRIP P Blow down TD. POOH on TT from 2,687' to 163' 10/29/2006 00:00 01:00 1.00 163 0 SURFA DRILL PULD P Lay down BHA components -clear tools from rig floor 0000 - 0200 hrs Time change to 0100 hrs -Day light savin s time 01:00 02:30 1.50 0 0 SURFA CASIN( RURD P Rig up to run 9 5/8" casing 02:30 02:45 0.25 0 0 SURFA CASIN( SFTY P Prejob safety and Opts meeting for runnin casin 02:45 05:45 3.00 0 1,715 SURFA CASIN( RNCS P Run 9 5/8" 40# L-80 MBTC csg as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg -Float collar (Howco) 2 jts. csg (first 4 connections made up w/ BakerLoc -filled pipe & checked floats 41 'ts cs to 1715' 05:45 06:15 0.50 1,715 1,715 SURFA CASIN( CIRC P Stage pumps up to 5.5 bpm -circulate and condition mud - FC 320 si 06:15 07:45 1.50 1,715 2,677 SURFA CASIN( RNCS P Continue running 9 5/8" - 40# L-80 MBTC csg f/ 1715' to 2638' - 24 jts (69 jts total ran) - PU FMC csg hanger & landing jt. -Land csg w/fluted mandle hanger on landing ring w/float shoe @ 2677' & float collar 2599' 07:45 08:30 0.75 2,677 2,677 SURFA CEME~ PULD P Lay down fill-up tool -blow down top drive - RU cement head 08:30 10:00 1.50 2,677 2,677 SURFA CEME~ CIRC P Establish circulation @ 3.0 bpm / 210 psi -staged pumps up to 8 bpm - reciprocate pipe PUW 173k SOW 137K -circulate and condition mud for cementing -full returns throughout - FCP 8.0 b m / 410 si - PJSM s P~~2af1~ ~~ ~~ Time Logs Date From__To Dur S. De th E. Depth Phase Code Subcode T COM 10/30/2006 13:15 13:45 0.50 2,440 2,597 SURFA DRILL TRIP P Wash and ream from 2440' to 2597'. FC at 2600' 13:45 16:15 2.50 2,597 2,687 SURFA DRILL REAM P Drill FC, shoetrack, FS and rathole from 2597 to 2687. 16:15 16:30 0.25 2,687 2,707 SURFA DRILL DDRL P Drill 20' new hole from 2687' to 2707'. 16:30 16:45 0.25 2,707 2,707 SURFA DRILL CIRC P Circulate and condition for LOT 16:45 17:45 1.00 2,707 2,707 SURFA DRILL FIT P Perform formation integrity test. 18 EMW 17:45 00:00 6.25 2,707 3,415 SURFA DRILL DDRL P Drilled 8-3/4 hole f/ 2707' to 3415' MD/2939' TVD ADT 3.06 hrs WOB 10/15 K, RPM 125, GPM 550 PP 1570 psi. PU Wt 165. SO 120. ROT 135 K Torq ON 9000 Off 8000 Ft Lbs. Change over to 9.6 ppg LSND on the fl . 10/31/2006 00:00 12:00 12.00 3,415 4,817 INTRM1 DRILL DDRL P Drilled 8-3/4" hole w/GeoPilot F/3415' T/481 T M D/401 T ND ADT = 7.5 hrs ECD = 11.16 WOB = 10/20 RPM = 150 GPM = 650 @ 2910 psi String Wt -- PU Wt = 189 SO Wt = 126 ROT = 147 Torque On/Off Btm -11,000/9,000 ft/Ibs 12:00 00:00 12.00 4,817 6,149 INTRM1 DRILL DDRL P Drilled 8-3/4" hole w/GeoPilot F/4817' T/6149' MD/5001' TVD ADT = 7.45 hrs ECD = 10.54 WOB = 10/20 RPM = 140 GPM = 650 @ 2950 psi String Wt -- PU Wt = 180 SO Wt = 156 ROT = 165 Torque On/Off Btm - 10,500/7,500 ft/Ibs 11/01/2006 00:00 12:00 12.00 6,149 7,421 INTRM1 DRILL DDRL P Drilled 8-3/4" hole w/GeoPilot F/6149' T/7421 MD/5916' TVD ADT = 7.85 hrs ECD = 10.61 WOB = 10/20 RPM = 140 GPM = 650 @ 2970 psi String Wt -- PU Wt = 192 SO Wt = 160 ROT = 175 Torque On/Off Btm - 10,500/8,000 ft/Ibs 12:00 00:00 12.00 7,421 8,545 INTRM1 DRILL DDRL P Drilled 8-3/4" hole w/GeoPilot F/7421' T/8545' MD/6199' TVD ADT = 8.69 hrs ECD = 10.59 WOB = 10/22 RPM = 120 GPM = 600 @ 3250 psi String Wt -- PU Wt = 190 SO Wt = 150 ROT = 170 Tor ue On/Off Btm - 11,00/8,000 ft/Ibs v ~ Party cf 12 Time Logs Date From To Dur S- De th E. D th Phase ___ Code _ Subcode T COM 11/02/2006 00;00 01:30 1.50 T 8,545 8,706 INTRM1 DRILL _ DDRL __ P Driiled 8-3/4" hole w/GeoPilot f/8545' to 8706' MD - 6208' ND ADT = 1.56 hrs ECD = 10.5 ppg WOB 15/20 RPM 120 GPM 620 @ 3270 psi String Wt -- PU 192 SO 151 ROT 170 Torque On/Off Btm -12,00/10,000 ft/Ibs 01:30 03:30 2.00 8,706 8,706 INTRM1 DRILL CIRC P Circ 3 BU's Flow Check; Well Static 600 GPM 2980 psi 120 RPM Stand back stand eve 30 min 03:30 06:30 3.00 8,706 8,706 INTRM1 DRILL WPRT P Wiper Trip f/8706 to 7293' MD w/pump 600 GPM 120 RPM Flow Check; Static Blow Down TD RIH to 8628' -Wash down to 8706' 06:30 09:00 2.50 8,706 8,706 INTRM1 DRILL CIRC P Circ 3 BU's 600 GPM 120 RPM S/B STD Every 30 min Run Back to BTM. 09:00 12:00 3.00 8,706 7,094 INTRM1 DRILL TRIP P POH spotting Wellbore strengthing pill and Lube Pill f/8706 to 7293'. Flow Check Static, Blow Dwn TD. POH on TT f/ 7293 to 7094' 12:00 16:30 4.50 7,094 1,868 INTRM1 DRILL TRIP P Cont. POOH on TT f/ 7094' to 1868' - flow ck 9 5/8" shoe -Static 16:30 20:30 4.00 1,868 0 INTRM1 DRILL TRIP P Change over to 5" handling tools - Cont. POOH on TT w/ 5" DP f/ 1868' - Std back HWDP, Jars, & NM flex DC's -Down load MWD -break off bit & service GP - LD GP &MWD 20:30 22:30 2.00 0 0 INTRM1 CASIN( OTHR P Clean up floor -Pull wear bushing - Change top pipe rams to 7" -Set test plug & test 7" rams & door to 300 & 5000 psi -Pull test plug -set thin wall wear bushin 22:30 23:45 1.25 0 0 INTRM1 CASIN( RURD P RU to run 7" casing - change to long bails - MU fill up tool - RU elevators,s ider & ton s - 23:45 00:00 0.25 0 0 INTRM1 CASIN( SFTY P Held PJSM w/ crew on running 7" csg 11/03/2006 00:00 03:45 3.75 0 3,431 INTRM1 CASIN( RNCS P Run 7" 26# L-80 BTCM csg as follows: FS (Ray Oil tools silver bullet) 2 jts. csg - FC (Hallibutton) 2 jts. csg (first 4 jts. made up w/BakerLoc -filled pipe & checked floats) 76 jts to 3431' (80 'ts total 03:45 04:30 0.75 3,431 3,431 INTRM1 CASIN( CIRC P Break circ -stage pump to 5.5 bbls/min. -Circ btms up + @ 350 psi - PU 145 SO 130 04:30 08:30 4.00 3,431 7,040 INTRM1 CASIN( RNCS P Continue running 7" 26# L-80 BTCM cs - f/ 3431' to 7040' 165 ~ts total 08:30 09:30 1.00 7,040 7,040 INTRM1 CASIN( CIRC P Break circ & stage pump to 4.5 bbls/min -Circ btms up + - ICP - 510 si FCP - 420 si - PU 245 SO 155 ~ Page C7 l J Time Logs - Date Frorn To Dur --- S,_Depth -- E. De th Phase Code ------ Subcode - T - COM _ 11/03/2006 09:30 11:30 2.00 7,040 8,696 INTRM1 CASIN( RNCS P Continue running 7" 26# L-80 BTCM csg f/ 7040' to 8659' (201 jts total) - PU FMC fluted hanger & landing jt. - Land 7" csg w/ FS @ 8696' FC @ 8607' - RD fill up tool & RU cmt head & lines 11:30 13:00 1.50 8,696 8,696 INTRM1 CEME~ CIRC P Establish circulation -stage pump up to 6 bbls/min -circulate & condition for cement job Final mud properties - Wt. 9.8 Vis 41 PV 9 YP 16 13:00 16:00 3.00 8,696 8,696 INTRM1 CEME~ DISP P Cement 7" csg as follows: Pumped 5 bbls 8.3 ppg CW-100 -Test lines to 3500 psi -Pumped 35 bbls 8.3 ppg CW-100 - 3.5 bbls/min @ 280 psi - Drop btm plug -Pumped 40 bbls 10.5 ppg MudPush 5 bbls/min @ 400 .psi - Mixed & pumped 132 bbls 11.0 ppg Lead slurry (LiteCrete) 5.7 bbls/min @ 400 psi -Mixed & pumped 41 bbls 15.8 ppg Tail slurry (Class G w/ .additives) 5 bbls/min @ 180 psi -Drop top plug w/ 20 bbls water f/ Dowell - Switched to rig pumps & displaced w/ 308.3 bbls 9.8 ppg LSND mud - 6 bbls/min @ 960 psi for first 290 bbls - slowed pumps to 3 bbls/min @ 650 psi for last 18.3 bbls -Bumped plug w/ 1150 psi -Checked floats OK - CIP @ 15:29 hrs. -Full returns throughoutjob - reciprcated pipe until beginning of dis lacement w/ ri um s 16:00 16:30 0.50 8,696 8,696 INTRM1 CEME~ OTHR P Tested 7" casing to 3500 psi for 30 mins. 16:30 17:30 1.00 8,696 8,696 INTRM1 CEME~ RURD P RD cmt lines LD cmt head & landing ~t.- LD cs elevators & s ider 17:30 21:00 3.50 INTRM1 CASIN( OTHR P Pull thin wall wear bushing -Install & test 7" x 9 5/8" pack-off & test to 5000 psi -Change top pipe rams back to 3 1/2" x 6" VBR -Test to 250 & 5000 si -Set wear bushin 21:00 00:00 3.00 0 87 INTRM1 DRILL PULD P MU BHA # 3 - 6 1/8" bit, GeoPilot - MWD - U load MWD 11/04/2006 00:00 00:30 0.50 87 215 INTRM1 DRILL PULD P Finish PU BHA #3. Bat sonic tool and NMFC's. 00:30 01:00 0.50 215 215 INTRM1 DRILL OTHR P Shallow test MWD, Geopilot and Geos an. 01:00 05:30 4.50 215 4,307 INTRM1 DRILL PULD P PU and RIH with 4" DP to 4307'. Fill i e eve 60 'ts. 05:30 11:00 5.50 4,307 5,307 INTRMI EVALFI DLOG P MAD pass with Bat sonic tool from 4307' to 5307' at 300 fpm w/ no pump or rota 11:00 13:00 2.00 5,307 8,440 INTRM1 DRILL TRIP P RIH f/ 5307' to 6117' -picking up reminder of 4" DP f/ shed - RIH f/ 6117' to 8403' w/pipe from derrick -Mad ass to 8440' took wt. ~ _ ~ s Pace~ofl2~ Time Logs _ _ _ ___ _ _ _ Date From To Dur S De th E. De th Phase Code Subcode T_ CO_M ~ 11/04/2006 13:00 14:00 1.00 8,440 8,498 INTRM1 DRILL TRIP P MU TD -wash down f! 8403' to 8998' 210 gpm @ 1370 psi w/ 50 rpm - Circ btms u 14:00 15:30 1.50 8,498 8,498 INTRM1 RIGMN SVRG P PJSM -cut & slip drill line -service TD 15:30 16:00 0.50 8,498 8,607 INTRM1 CEME~ COCF P Wash down f/ 8498' to 8570' (tag up) Clean out cmt to 8607' - 210 gpm @ 1390 si w/ 70 r m 16:00 19:00 3.00 8,607 8,726 INTRM1 CEME~ DRLG P Drill wiper plugs - FC @ 8607' - cement to sheo -drill out shoe @ 8694' to 8696' -clean out rat hole to 8706' -Drill 20' new hole to 8726' - 210 m 1410 siw/80r m 19:00 20:00 1.00 8,726 8,726 INTRM1 DRILL CIRC P Circulate hole clean for FIT - 210 gpm 1400 siw/ 80 m 20:00 20:30 0.50 8,726 8,726 INTRM1 DRILL FIT P RU & perform FIT to 12.5 ppg EMW - 840 psi w/ 9.9 ppg mud @ 6210' TVD - RD 20:30 22:00 1.50 8,726 8,726 PROD1 DRILL CIRC P Change well over to 9.2 ppg OBM - 210gpm @ 2030 PSI W/ 70 RPM - shutdown & flow check(static) while cleanin u shakers 22:00 00:00 2.00 8,726 8,790 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 8726' to 8790' MD 6217' TVD ATD - 1.06 hrs. ECD - 10.2 ppg WOB 7/10 k RPM 100 GPM 210 @ 1950 psi String wt. PU 210 So 130 Rot 163 Torque on/off btm. - 12,500/11,000 ft/Ibs 11/05/2006 00:00 12:00 12.00 8,790 9,393 PROD1 DRILL DDRL P Drilled 6-1/8" horiz. section f/ 8790' to 9393 MD/6255' TVD ADT = 9.29 hrs ECD = 10.71 WOB = 7/12k RPM = 140 GPM = 224 @ 2210 psi String Wt -- PU = 220 SO = 130 ROT = 165 Torque On/Off Btm -12,500/11,000 ft/Ibs 12:00 00:00 12.00 9,393 10,160 PROD1 DRILL DDRL P Drilled 6-1/8" horiz. section f/ 9393' to 10,160 MD/6217' TVD ADT = 9.95 hrs ECD = 10.97 WOB = 7/10k RPM = 140 GPM = 224 @ 2300 psi String Wt -- PU = 210 SO = 130 ROT = 160 Torque On/Off Btm -11,500/10,500 fUlbs 11/06/2006 00:00 12:00 12.00 10,160 10,921 PROD1 DRILL DDRL P Drilled 6-1/8" horiz. section f/ 10,160' to 10,921 MD/6252' TVD ADT = 9.45 hrs ECD = 10.96 WOB = 8/12k RPM = 140 GPM = 225 @ 2370 psi String Wt -- PU Wt = 222 SO Wt = 119 ROT Wt = 162 Torque On/Off Btm - 13,000/12,000 ft/Ibs ~~~ ~~~ 7 of 12 ~ Time Logs __ Date From To Dur S De th E. De th Phase Code Subcode T COM 11/06/2006 12:00 00:00 12.00 10,921 11,570 PROD1 _ DRILL DDRL P Drilled 6-1/8" horiz. section f/ 10,921' to MD/ 1.1,570' ND ADT = 9.7 hrs ECD = 11.21 WOB = 8/10k RPM = 140 GPM = 225 @ 2490 psi String Wt -- PU Wt = 238 SO Wt = 105 ROT Wt = 160 Torque On/Off Btm - 13,000/12,000 fUlbs 11/07/2006 00:00 12:00 12.00 11,570 12,291 PROD1 DRILL DDRL P Drilled 6-1/8" horiz. section f/ 11,570' to 12,291' MD/6227' ND ADT = 9.4 hrs ECD = 11.12 WOB = 8/10k RPM = 140 GPM = 225 @ 2540 psi String Wt -- PU Wt = 239 SO Wt = 105 ROT Wt = 160 Torque On/Off Btm - 14,000!13,000 ftllbs 12:00 00:00 12.00 12,291 12,927 PROD1 DRILL DDRL P Drilled 6-1/8" horiz. section f/ 12,291' to 12,927 MD/6257 ND ADT = 9.43 hrs ECD = 11.12 WOB = 8/10k RPM = 140 GPM = 224 @ 2600 psi String Wt -- PU Wt = 230 SO Wt = 117 ROT Wt = 160 Torque On/Off Btm - 13,000/12,000 ft/Ibs 11/08/2006 00:00 12:00 12.00 12,927 13,510 PROD1 DRILL DDRL P Drilled 6-1/8" horiz. section f/ 12,927' to 13,510' MD/6240' ND ADT = 8.73 hrs ECD = 11.09 WOB = 8/10k RPM = 140 GPM = 224 @ 2530 psi String Wt -- PU Wt = 235 SO Wt = 117 ROT Wt = 158 Torque On/Off Btm - 14,000/12,500 ft/Ibs 12:00 00:00 12.00 13,510 14,214 PROD1 DRILL DDRL P Drilled 6-1/8" horiz. section f/ 13,510' to 14,214' MD/6214' ND ADT=9.19 hrs ECD=11.2 WOB = 8/10k RPM = 140 GPM = 224 @ 2680 psi String Wt -- PU Wt = 235 SO Wt = 105 ROT Wt = 157 Torque On/Off Btm - 13,500/12,500 ft/Ibs Unable to slack-off for connections f/ 13,928' double back reamed; still unable to slack off to make connection - rotate down to set sli s ~e~ F~~e ct 12 Time Logs _ Date From To Dur S_._De~th E. De th Phase Code Subcode __ T _ COM _ 11/09/2006 00:00 12:00 12.00 14,214 14,786 PROD1 DRILL DDRL __ P Drill 6-1/8" horiz. sect. w/ GP f/ 14,214' to 14,786' MD 6263' ND ADT - 8.13 hrs. ECD - 11.35 ppg WOB 10/12 k RPM 120 GPM 224 @ 2790 psi String wt. PU 267 SO Must rotate Rot. 157 Torque on/off btm.- 15,500/14,500 ft/Ibs 12:00 16:30 4.50 14,786 15,072 PROD1 DRILL DDRL P Drill 6-1/8" horiz. Sect. w/GP f/ 14,786' to 15,072' MD 6378' ND ADT - 3.88 hrs. ECD - 11.6 WOB 9/11 k RPM 120 GPM 199 @ 2500 psi String wt. PU 280 SO must rotate Rot 160 Torque on/off btm.- 16,000/15,000 ft/Ibs 16:30 20:00 3.50 15,072 15,072 PROD1 DRILL CIRC P Circulate 3 x btms up @ 220 gpm @ 2750 psi w/ 120 rpm -Flow check well static 20:00 00:00 4.00 15,072 12,499 PROD1 DRILL TRIP P POOH w/pump @ 170 gpm @ 1630 PSI W/ no rotation f/ 15072' to 12,499' - no ti ht hole - takin ro er fill 11/10/2006 00:00 01:00 1.00 12,499 11,642 PROD1 DRILL TRIP P Continue POOH w/ pump f/ 12,499' to 11,642' Improper hole fill - on last 5 stds - Monitor well static 01:00 02:00 1.00 11,642 11,642 PROD1 DRILL CIRC NP Circ btms up - 197 gpm @ 2120 psi w/ 80 rpm - monitor btms up OK -Flow check -Static 02:00 06:30 4.50 11,642 8,688 PROD1 DRILL TRIP P Cont. POOH w/ pump f/ 11,642' to 8974' -Drop 2 1/8" hollow drift -Cont. POOH int 7" csg @ 8688' -Flow check -Static 06:30 07:30 1.00 8,688 8,688 PROD1 DRILL CIRC P Circ btms up 218 gpm @ 2220 psi - recip. pipe 220 PU 130 SO -Flow check -static 07:30 11:00 3.50 8,688 6,340 PROD1 DRILL TRIP P Cont. POOH w/ pump f/ 8688' to 6340' - Blow down TD & Geo S an 11:00 17:00 6.00 6,340 405 PROD1 DRILL TRIP P Cont. POOH on TT f/ 6340' to 405' BHA 17:00 20:30 3.50 405 0 PROD1 DRILL PULD P Flow check -Static -Handle BHA - Std back HWDP 7 NM Flex DC's - Pull up & check GP & break bit - LD MWD & GP 20:30 21:00 0.50 0 0 COMPZ RPCOh OTHR P Clean up & clear floor of tools f/ OBM 21:00 21:30 0.50 0 0 COMPZ RPCOh RURD P Ru to run 4 1/2" liner -Held PJSM w/ crew 21:30 00:00 2.50 0 2,485 COMPZ RPCOh RCST P Run 4 1/2" 12.6# L-80 SLHT Blank & slotted liner to 2485' 62 of 157 to run 11/11/2006 00:00 04:00 4.00 2,485 6,327 COMPZ RPCO6 RCST P Cont. running 4 1/2" 12.6# L-80 SLHT slotted/blank liner f/ 2485' to 6327' - 157 jts. total - MU Baker Flex Lock hanger assembly -Mix & spot Pal Mix in top of running tool - PU 148 SO 115 Rot 128 w/ 11,500 ft/Ibs for ue F'~ge g ~sf 12 • Time Low---- -- --- - - -~ Date __ From To Dur____ S. Depth E. De th Phase Code Subcode T COM _ -_ 11/11/2006 04:00 06:00 2.00 6,327 8,615 COMPZ RPCOh RCST P RIH w/ 4 1/2" liner on 4" DP f/ 6327' to 8615' 81' f/ 7" shoe 06:00 06:30 0.50 8,615 8,615 COMPZ RPCOh CIRC P Pump DP volume 3.5 BPM @ 240 psi - PU 180 SO 125 Rot 145 w/ 8,000 ft/Ibs for ue -Blow down TD 06:30 10:30 4.00 8,615 14,814 COMPZ RPCOR RCST P Cont. RIH w/ 4 1/2" liner on 4" DP f/ 8615' to 14,814' - PU 270 SO 85 10:30 11:00 0.50 14,814 14,814 COMPZ RPCOh RCST P Drop setting ball -Est. circ @ 3 BPM - pump ball to seat -Pressure up to 2000 psi -Set liner hanger w/ Top @ 8493.82' @ liner shoe @ 14,814' - Pressure up to 3500 psi & release riunnin tool f/liner han er 11:00 12:00 1.00 8,478 8,478 COMPZ RPCOi\ CIRC P Pull up & std back 1 std DP - to 8478' - Circ btms u 224 m 1200 si 12:00 14:00 2.00 8,478 7,450 COMPZ RPCOh TRIP P Flow check well -static -POOH w/ pump f/ 8478' to 7450' -flow ck. Static - Blow down TD 14:00 21:30 7.50 7,450 30 COMPZ RPCOA TRIP P POOH on TT f/ 7450' to 30' -Flow ck 1258 Static - 21:30 22:00 0.50 30 0 COMPZ RPCOh PULD P LD liner hanger running tool assembly 22:00 22:30 0.50 0 0 COMPZ RPCOM1 OTHR P Pull wear bushing 22:30 23:30 1.00 0 0 COMPZ RIGMN RGRP T Change out swivel packing 23:30 00:00 0.50 0 0 COMPZ RPCOh RURD P Rig up to run 4 1/2" completion string 11/12/2006 00:00 00:15 0.25 0 0 COMPZ DRILL SFTY P Held pre job safety meeting 00:15 13:00 12.75 0 8,507 COMPZ RPCOh RCST P Run 4 1/2" completion as follows: Baker fluted shear indicating locator w/ WLEG assembly - 23 jts. 4 1/2" 12.6# L-80 IBTM tbg - XN nipple - 1 jt 4 1/2" tbg -Baker Premier packer assembly - 2 jts. 4 1 /2" tbg -Camco 4 1/2" GLM w/ DCK2 shear valve - 131 jts 4 1/2" tbg -Camco 4 1/2" DB nipple - 52 jts 4 1/2" tbg - (2) 4 1/2" pups jts for space out - 2 jts 4 1/2" tbg - FMC tbg hanger Spaced out locator 2' above 4 1/2" liner top -Landed tbg in wellhead on tbg hanger w/ tbg tail @ 8506.81' - XN nipple @ 7580' -Packer @ 7523' - GLM @ 7419' - DB nipple @ 2189' - RILDS 13:00 14:00 1.00 8,507 8,507 COMPZ RPCOh DHEQ P FMC installed 2-Way check; Test tbg han er seals to 5000 si. 14:00 16:00 2.00 COMPZ RPCOA PULD P LD Tbg Equip. Clean and clear the rig floor. Flush BOPE of MOBM and blow thru choke. 16:00 20:00 4.00 COMPZ RPCOh RURD P ND BOPE and CO Junk sub. NU tree and test to 5000 si. ~~ ~ Pay ~S? of 12 r~ Time Logs _ Date From To Dur SD epth E. Depth Phase Code Subcode T __ COM 11/12/2006 20:00 00:00 4.00 _ _ ,_ COMPZ __ DRILL CIRC P _ _ _` Pull TWC Displace well w/diesel . Pumped 20 bbls mineral oil. Test lines to 2000 psi. Pumped 263 bbls diesel @ 2.5 bbls/min Pressure schedule maintained on choke. Final pressure 830 si. 11/13/2006 00:00 02:00 2.00 COMPZ RPCOh PACK P RU lubricator & drop packer setting rod/ball assmebly - RD lubricator Pressure test lines to 5000 psi - Pressure up on tbg to 4200 psi to set packer -Test tbg for 30 mins. Initial pressure 4063 psi -Finial pressure 3853 psi -Bleed tbg down to 2500 psi - Pressure up on 4 1/2" X 7" annulus to 3500 psi -test for 30 mins. finial pressure 3367 psi -Bleed down annulus to 0 psi -bleed down tbg to 600 psi -Shut in well . NOTE: Didn't shear out shear valve in GLM 02:00 03:00 1.00 COMPZ RPCOA RURD P Blow down hard lines & manifold - RD 03:00 04:30 1.50 COMPZ RPCOh OTHR P RU FMC lubricator & set BVP - RD - Secure well 04:30 12:00 7.50 COMPZ RPCOh PULD P Set mouse hole - LD excess 4" DP - 4 3/4" flex DC's - 4" HWDP f/ derrick via mouse hole for rig move -move 6" Flex Dc's to drillers side of derrick 12:00 17:00 5.00 COMPZ RPCOA OTHR P Clean rig of OMB (pipe racks -drip pans -service rotary table & rou hneck 17:00 00:00 7.00 MIRU MOVE OTHR P Prep rig for move -blow down steam & water -Move motors & pits past CD4-320 to allow access for slick line to work on CD4-318 -Jack floor -Move ri off of CD4-214 11/14/2006 00:00 12:00 12.00 MIRU MOVE MOB P Move sub over CD4-211 -Skid floor & set pipe shed -Hook up lines at mezzanie -Set surface riser - Pit ~ motor complexes still at end of pad - Perform rig maintenance while slick line working on CD4-318 - Chnage out seats in #2 pump - PU mouse hole -Change dies in "the Driver" to 5" - Chnage mud bucket rubbers -service drag chain -Check brakes -Hook up flare line -Install clamp on choke line -service draw works F~~~~ 11 of 12 ~ i Time Loys ____ __ _ __ Date From To Dur S De th E. De th Pha e Code Subcode T COM _ _ 11/14/2006 12:00 00:00 12.00 MIRU MOVE DMOB P _ Install pipe spinners on "the Driver" - Continue service drag chain -service pit equipment -service motor eugipment -Install raditor coolant hood on motor complex -Measure & drift 9 5/8" csg -while slicke line finsihed work on CD4-318 -Released rig @ 2359 hrs. Prep to continue move to CD4-211 ~~~~ ~ P~ye 12 c~# 12 f Casing Detail Report CD4-214 Casing (Casing Description (Liner 11 Depth (ftKB) 14,81`4.3 Date (Set Tension (kips) Casing Components h11~-uF~ 1 r~ '. llem Des -.peen OD (=n) VJt ~Ibs/hi Grade Top Th..ead Jis 1. ~r. ;,'~i ToF iFlKB~ &m ("KPH (~tibs? C.c-ss is Mai. OD (,ni ID i,i~~ I Liner Hanger I I I I I 1 I 32.291 8.535.71 8.568.01 I I I I Blank Liner 4 1/2 12.60 L-80 SLHT 4 162.12 - 8,568.0 8,730.1 Slotted Liner 4 1/2 12.60 L-80 SLHT 4 157.62 8,730.1 8,887.7 Blank Liner 4 1/2 12.60 L-80 SLHT 2 79.34 8,887.7 8,967.0 Slotted Liner 4 1/2 12.60 L-80 SLHT 4 158.18 8,967.0 9,125.2 Blank Liner 4 1/2 12.60 L-80 SLHT 1 41.60 9,125.2 9,166.8 Slotted Liner 4 1/2 12.60 L-80 SLHT 1 39.20 9,166.8 9,206.0 Blank Liner 4 1/2 12.60 L-80 SLHT 6 247.58 9,206.0 9,453.6 Slotted Liner 4 1/2 12.60 L-80 SLHT 3 118.28 9,453.6 9,571.9 Blank Liner 4 1/2 12.60 L-80 SLHT 6 240.90 9,571.9 9,812.8 Slotted Liner 4 1/2 12.60 L-80 SLHT. 2 78.42 9,812.8 9,891.2 Blank Liner 4 1/2 12.60 L-80 SLHT 6 244.34 9,891.2 10,135.5 Slotted Liner 4 1/2 12.60 L-80 SLHT 8 315.70 10,135.5 10,451.2 Blank Liner 4 1/2 12.60 L-80 SLHT 4 119.61 10,451.2 10,570.9 Slotted Liner 4 1/2 12.60 L-80 SLHT 3 120.66 10,570.9 10,691.5 Blank Liner 4 1/2 12.60 L-80 SLHT 3 118:57 10,691.5 40,810.1 Slotted Liner 4 1/2 12.60 L-80 SLHT 2 79.05 10,810.1 10,889.1 Blank Liner 4 1/2 12.60 L-80 SLHT 2 80.21 10,889.1 10,969.3 Slotted Liner 4 1/2 12.60 L-80 SLHT 3 118.32 10,969.3 11,087.7 Blank Liner 4 1/2 12.60 L-80 SLHT 4 162.12 11,087.7 11,249.8 Slotted Liner 4 1/2 12.60 L-80 SLHT 2 79.58 11,249.8 11,329.4 Blank Liner 4 1/2 12.60 L-80 SLHT 10 403.90 11,329.4 11,733.3 Slotted Liner 4 1/2 12.60 L-80 SLHT 12 472.58 11,733.3 12,205.8 Blank Liner 4 1/2 12.60 L-80 SLHT 3 123.16 12,205.8 12,329.0 Slotted Liner 4 1/2 12.60 L-80 SLHT 1 41.01 12,329.0 12,370.0 Blank Liner 4 1/2 12.60 L-80 SLHT 3 125.22 12,370.0 12,495.2 Slotted Liner 4 1!2 12.60 L-80 SLHT 1 39.38 12,495.2 12,534.6 'Blank Liner 4 1/2 12.60 L-80 SLHT 2 81.95 12,534.6 12,616.6 - _ Slotted Liner 4 1/2 12.60 L-80 SLHT 18 714.68 12,616.6 13,331.2 _ Blank Liner 4 1/2 12.60 L-80 SLHT 6 242.31 13,331.2 13,573.6 Slotted Liner 4 1/2 .12.60 L-80 SLHT 3 119.43 .13,573.6 13,693.0 Blank Liner 4 1/2 12.60 L-80 SLHT 3 121.64 13,693.0 13,814.6 _ Slotted Liner 4 1/2 12.60 L-80 SLHT 7 277.60 13,814.6 14,092.2 Blank Liner 4 1/2 12.60 L-80 SLHT 7 281.15 14,092.2 14,373.4 Slotted Liner 4 1/2 12.60 L-80 SLHT 1 39.72 14,373.4 14,413.1 Blank Liner 4 1/2 12.60 L-80 SLHT 5 199.90 14,413.1 14,613.0 Slotted Liner 4 1/2 12.60 L-80 SLHT 4 160.42 14,613.0 14,773.4 Blank Liner 4 1/2 12.60 L-80 SLHT 1 39.05 14,773.4 14,812.5 Float Shoe 4 1/2 12.60 L-80 SLHT 1 1.80 14,812.5 14,814.3 Page 1/1 Report Printed: 11/28/2006 .r COY'IOCO~I'1tINl~S • . Liner Detail 4 7/2" Slotted and Blank Liner Well: CD4-214 Date: 11/10/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Top of Liner Hanger @ 8493.82 Baker "HR" Liner Setting Sleeve 5.79 OD x 4.42 ID 13.05 8493.82 Baker "RS" Packoff Seal Nipple 5.60 OD x 4.25 ID 3.76 8506.87 Baker "DG" 5" x 7" Flex Lock Hanger 5.92 OD x 4.40 ID 9.78 8510.63 XO - 5" L-80 Butt x 4 1/2" L-80 SLHT 5.57 OD x 4.00 ID 1.76 8520.41 Pup - 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 3.72 8522.17 Jts 154 to 157 4 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 162.12 8525.89 Jts 150 to 153 4 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 157.62 8688.01 Jts 148 to 149 2 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 79.34 8845.63 Jts 144 to 147 4 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 158.18 8924.97 Jts 143 to 143 1 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 41.60 9083.15 Jts 142 to 142 1 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 39.20 9124.75 Jts 136 to 141 6 Jts 4-1/2", 12.6#, t-80, SLHT BLANK PIPE 247.58 9163.95 Jts 133 to 135 3 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 118.28 9411.53 Jts 127 to 132 6 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 240.90 9529:81 Jts 125 to 126 2 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 78.42 9770.71 Jts 119 to 124 6 Jts 4-1/2", 12.61/, L-80, SLHT BLANK PIPE 244.34 9849.13 Jts 111 to 118. 8 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 315.70 10093.47 Jts 107 to 110 4 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 161.68 10409.17 Jts 104 to 106 3 Jts 4-1/2", 12.6#, L-8Q, SLHT SLOTTED LINER 120.66 10570.85 Jts 101 to 103 3 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 118.57 10691.51 Jts 99 to 100 2 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 79.05 10810.08 Jts97 to 98 2 Jts 4-1/2", 12.6#, L-8o, SLHT BLANK PIPE 80.21 10889.13 Jts 94 to 96 3 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 118.32 10969.34 Jts 90 to 93 4 Jts 4-1/2", 12.6#, L-8o, SLHT BLANK PIPE 162.12 11087.66 Jts 88 to 89 2 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 79.58 11249.78 Jts 78 to 87 10 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 403.90 11329.36 Jts 66 to 77 12 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER .472.58 11733.26 Jts 63 to 65 3 Jts 4-1/2", 12.6#, L-8o, SLHT BLANK PIPE 123.16 12205.8 - Jts 62 to 62 1 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER - 41.01 12329.00 Jts 59 to 61 3 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 125.22 12370.01 Jts 58 to 58 1 Jts 4-1/2", 12.6#, L-80,_SLHT SLOTTED LINER 39.38 12495.23 Jts 56 to 57 2 Jts 4-1/2", 12.6#, L-8o, SLHT BLANK PIPE 81.95 12534.61 Jts 38 to 55 18 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 714.68 12616.56 Jts 32 to 37 6 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 242.31 13331.24 Jts 29 to 31 3 Jts 4-1l2", 12.6#, L-80, SLHT SLOTTED LINER 119.43 13573.55 Jts 26 to 28 3 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 121.64 .13692.98 Jts 19 to 25 7 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 277.60 13814.62 Jts 12 to 18 7 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 281.15 14092.22 Jts 11 to 11 1 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 39.72 14373.37 Jts 6 to 10 5 Jts 4-1/2", 12.6#, L-80, SLHT BLANK PIPE 199.90 14413.09 Jts 2 to 5 4 Jts 4-1/2", 12.6#, L-80, SLHT SLOTTED LINER 160.42 14612.99 Jts 1 to 1 1 Jts 4-1/2" 12.6# L-80 SLHT Blank Pie 39.05 14773.41 Baker V set float shoe 5.05" OD 1.80 14812.46 4 1/2" liner shoe @ 14814.26 TD of 6 1/8" hole = 15072.00 Remarks: Run-NSeal pipe dope p. ::......:::::::::.: , ....................:::.:..:..:::..:.::::::::.:.,.:..:.,:::::::.:::.::::...;; ..; ..........:.:::.. ':::fk ><><>>'- <>St~ ervisvr »~~ ( rfckI>D.a1/l..ke . . Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc . ___ Date: 1 212 0/2 0 06 Time: 13:17:48 Page: 1 Field: Colville River Unit Co -ordinate(NE) Reference: Well: CD4-214, True North ' Site: Alpine CD4 Vertical (TVD) Re ference: CD4-214:56.9 Well: CD4-214 Section (VS) Reference: 1NeIl (O.OON,O.OOE,178.18Aii) Wellpath: CD4-214 Survey Calculation Method: Minimum Curvature ~ Db: Oracle ---_ Field: Colville River Unit -- North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: CD4-214 Slot Name: Alpine CD4 Well Position: +N/-S -64.88 ft Northing: 5957465.31 ft ~ Latitude: 70 17 32.328 N +E/-W -251.70 ft Easting : 377922.00 ft ~ Longitude: 150 59 18.098 W Position Uncertainty: 0.00 ft Wellpath: CD4-214 Drilled From: Well Ref. Point 501032053700 Tie-on Depth: 37.10 ft Current Datum: CD4-214: Height 56.90 ft Above System Datum: Mean Sea Level Magnetic Data: 10/23/2006 Declination: 23.01 deg Field Strength: 57551 nT Mag Dip Angle: 80.66 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.10 0.00 0.00 178.18 Survey Program for Definitive Wellpath Date: 9/18/2006 Validated: No Version: 3 Actual From To Survey Toolcode Toal Name ft ft 75.80 621.80 CD4-214 gyro (75.80-621.80) CB-GYRO-SS Camera based gyro single shot 752.37 15034.27 CD4-214 (752.37-15034.27) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey _~ ~ MD Incl Azim TVD Sys TVD N/S E/1~' MapN b4apE Tool ft deg deg ft ft ft ft ft ft ~I 37.10 0.00 0.00 37.10 -19.80 0.00 0.00 5957465.31 377922.00 TIE LINE 75.80 0.50 320.00 75.80 18.90 0.13 -0.11 5957465.44 377921.89 CB-GYRO-SS 167.80 0.80 330.00 167.79 110.89 0.99 -0.69 5957466.31 377921.33 CB-GYRO-SS 256.80 1.10 320.00 256.78 199.88 2.19 -1.55 5957467.52 377920.49 CB-GYRO-SS ~ i 349.80 1.40 262.00 349.76 292.86 2.71 -3.25 5957468.07 377918.80 CB-GYRO-SS i 439.80 2.75 239.00 439.70 382.80 1.45 -6.19 5957466.86 377915.84 CB-GYRO-SS i 531.80 4.00 232.00 531.54 474.64 -1.67 -10.61 5957463.82 377911.37 CB-GYRO-SS 621.80 5.00 228.00 621.26 564.36 -6.22 -15.99 5957459.35 377905.91 CB-GYRO-SS ~I 752.37 6.54 220.94 751.17 694.27 -15.65 -25.10 5957450.07 377896.65 MWD+IFR-AK-CAZ-SC 842.42 8.15 223.34 840.48 783.58 -24.16 -32.84 5957441.68 377888.78 MWD+IFR-AK-CAZ-SC 938.47 12.85 233.62 I 934.90 878.00 -35.46 -46.12 5957430.61 377875.32 MWD+IFR-AK-CAZ-SC 'i 1032.96 19.38 239.84 1025.64 968.74 -49.58 -68.16 5957416.84 377853.05 MWD+IFR-AK-CAZ-SC 1128.50 21.72 240.60 1115.09 1058.19 -66.23 -97.27 5957400.67 377823.68 MWD+IFR-AK-CAZ-SC I 1223.32 24.62 237.99 1202.26 1145.36 -85.32 -129.31 5957382.11 377791.33 MWD+IFR-AK-CAZ-SC I j 1317.25 27.81 235.75 1286.51 1229.61 -108.02 -164.02 5957359.97 377756.26 MWD+IFR-AK-CAZ-SC i 1412.48 29.95 233.86 1369.90 1313.00 -134.55 -201.59 5957334.06 377718.27 MWD+IFR-AK-CAZ-SC 1507.63 29.99 234.82 1452.33 1395.43 -162.26 -240.21 5957306.99 377679.21 MWD+IFR-AK-CAZ-SC 1602.49 29.12 237.20 1534.85 1477.95 -188.42 -278.99 5957281.46 377640.01 MWD+IFR-AK-CAZ-SC 1697.69 33.69 241.33 1616.09 1559.19 -213.66 -321.65 5957256.92 377596.95 MWD+IFR-AK-CAZ-SC 1793.18 42.98 245.39 1690.92 1634.02 -239.98 -374.61 5957231.47 377543.58 MWD+IFR-AK-CAZ-SC 1888.05 44.40 242.45 1759.52 1702.62 -268.80 -433.44 5957203.61 377484.29 MWD+IFR-AK-CAZ-SC 1983.29 43.89 240.17 1827.87 1770.97 -300.63 -491.63 5957172.72 377425.60 MWD+IFR-AK-CAZ-SC 2078.63 41.82 237.79 1897.76 1840.86 -334.02 -547.20 5957140.24 377369.49 MWD+IFR-AK-CAZ-SC 2173.63 37.63 237.54 1970.81 1913.91 -366.48 -598.49 5957108.62 377317.69 MWD+IFR-AK-CAZ-SC ~I 2269.13 36.50 237.44 2047.02 1990.12 -397.42 -647.03 5957078.48 377268.66 MWD+IFR-AK-CAZ-SC 2364.10 37.69 242.49 2122.78 2065.88 -426.04 -696.60 5957050.68 377218.63 MWD+IFR-AK-CAZ-SC i 2458.92 39.54 244.67 2196.87 2139.97 -452.34 -749.59 5957025.24 377165.22 MWD+tFR-AK-CAZ-SC i 2554.39 39.41 242.09 2270.57 2213.67 -479.53 -803.85 5956998.93 377110.54 MWD+IFR-AK-CAZ-SC 2644.10 39.45 241.68 2339.86 2282.96 -506.38 -854.10 5956972.91 377059.86 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12/20/2006 Time: 13:17:48 Page: Z, Field: Colville River Unit Co-ordiuate(NE) Reference: Well: CD4-214, True North Site: Alpine CD4 Vertical (TVD) Reference: CD4-214:56.9 ~VeII: CD4-214 Section (VS) Reference: Well (O.OON,O.OOE,178.18Azi) ~Vellpath: CD4-214 Survey CakEda6on titethod: Minimum Curvature Db: Oracle ~uney --_ _ __ bID Incl Azim TVD ft deg deg ft ____ __ 2698.33 38.64 240.38 2381.98 2792.48 39.53 238.92 2455.06 2886.56 39.25 237.89 2527.77 2981.92 39.36 238.14 2601.56 3076.77 38.89 238.79 2675.14 3172.25 38.60 238.65 2749.61 3267.60 38.00 239.58 2824.44 3362.94 39.55 239.15 2898.77 3457.86 40.71 238.91 2971.34 3553.31 39.35 239.02 3044.42 3648.19 39.91 240.92 3117.50 3743.49 40.88 241.09 3190.08 3838.71 41.77 240.81 3261.59 3933.66 40.53 241.12 3333.08 4028.52 39.58 240.67 3405.69 4124.19 40.10 241.14 3479.15 4219.32 40.34 239.82 3551.79 4315.16 39.89 239.21 3625.08 4410.04 39.56 237.62 3698.06 4505.16 38.07 237.53 3772.17 4600.60 38.34 238.16 3847.17 4695.86 38.20 238.11 3921.96 4791.42 38.09 238.59 3997.11 4886.40 38.86 239.44 4071.47 4982.06 38.32 239.73 4146.24 5077.36 38.61 238.85 4220.86 5172.03 37.17 239.83 4295.57 5267.28 36.31 241.14 4371.90 5362.48 37.22 241.01 4448.16 5457.51 38.57 240.38 4523.15 5552.80 40.19 239.46 4596.81 5648.35 40.73 239.30 4669.51 5743.78 40.59 237.74 4741.90 5839.14 40.32 235.38 4814.47 5934.25 41.01 231.66 4886.62 6029.34 40.80 227.24 4958.50 6123.93 40.19 223.81 5030.45 6219.27 40.36 222.33 5103.19 6314.96 40.95 220.00 5175.79 6410.02 41.44 215.62 5247.33 6504.67 42.61 210.47 5317.66 6599.85 44.21 205.77 5386.82 6695.04 45.98 201.54 5454.03 6790.10 47.35 196.70 5519.29 6885.43 47.92 191.83 5583.55 6980.86 47.98 186.90 5647.48 -____ __ Sys TVD ,~/S ft ft ___ 2325.08 -522.92 2398.16 -552.92 2470.87 -584.20 2544.66 -616.19 2618.24 -647.50 2692.71 -678.53 2767.54 -708.86 2841.87 -739.29 2914.44 -770.77 2987.52 -802.42 3060.60 -832.70 3133.18 -862.64 3204.69 -893.17 3276.18 -923.49 3348.79 -953.18 3422.25 -982.99 3494.89 -1013.25 3568.18 -1044.58 3641.16 -1076.33 3715.27 -1108.30 3790.27 -1139.72 3865.06 -1170.86 3940.21 -1201.83 4014.57 -1232.25 4089.34 -1262.46 4163.96 -1292.74 4238.67 -1322.39 4315.00 -1350.46 4391.26 -1378.02 4466.25 -1406.60 4539.91 -1436.90 4612.61 -1468.48 4685.00 -1500.95 4757.57 -1535.04 4829.72 -1571.88 4901.60 -1612.34 4973.55 -1655.35 5046.29 -1700.37 5118.89 -1747.30 5190.43 -1796.75 5260.76 -1849.84 5329.92 -1907.51 5397.13 -1969.26 5462.39 -2034.55 5526.65 -2102.78 5590.58 -2172.66 E/~V b1apN ft ft -883.99 5956956.85 -935.20 5956927.69 -986.06 5956897.25 -1037.29 5956866.09 -1088.30 5956835.62 -1139.37 5956805.43 -1190.09 5956775.92 -1241.46 5956746.34 -1293.91 5956715.71 -1346.51 5956684.92 -1398.91 5956655.50 -1452.92 5956626.45 -1507.89 5956596.82 -1562.51 5956567.39 -1615.85 5956538.57 -1669.41 5956509.64 -1722.86 5956480.25 -1776.07 5956449.80 -1827.73 5956418.89 -1878.05 5956387.74 -1928.03 5956357.15 -1978.14 5956326.82 -2028.38 5956296.67 -2079.04 5956267.08 -2130.50 5956237.72 -2181.46 5956208.28 -2231.47 5956179.44 -2281.04 5956152.18 -2330.92 5956125.43 -2381.81 5956097.69 -2434.12 5956068.24 -2487.48 5956037.53 -2540.50 5956005.93 -2592.13 5955972.69 -2641.93 5955936.66 -2689.22 5955896.99 -2733.05 5955854.69 -2775.13 5955810.36 -2816.16 5955764.11 -2854.51 5955715.30 -2889.01 5955662.78 -2919.79 5955605.62 -2946.79 5955544.33 -2969.39 5955479.41 -2986.72 5955411.48 -2998.25 5955341.80 -3005.30 5955270.39 -3009.20 5955197.16 -3010.25 5955121.36 -3007.78 5955043.25 -3000.83 5954962.59 -2989.02 5954879.64 ___ ,11apE Tool ft 377029.71 MWD+IFR-AK-CAZ-SC 376978.02 MWD+IFR-AK-CAZ-SC 376926.67 MWD+IFR-AK-CAZ-SC 376874.93 MWD+IFR-AK-CAZ-SC 376823.42 MWD+IFR-AK-CAZ-SC 376771.85 MWD+IFR-AK-CAZ-SC 376720.66 MWD+IFR-AK-CAZ-SC 376668.80 MWD+IFR-AK-CAZ-SC 376615.85 MWD+IFR-AK-CAZ-SC 376562.74 MWD+IFR-AK-CAZ-SC 376509.87 MWD+IFR-AK-CAZ-SC 376455.38 MWD+IFR-AK-CAZ-SC 376399.93 MWD+IFR-AK-CAZ-SC 376344.83 MWD+IFR-AK-CAZ-SC 376291.02 MWD+IFR-AK-CAZ-SC 376236.99 MWD+IFR-AK-CAZ-SC 376183.06 MWD+IFR-AK-CAZ-SC 376129.35 MWD+IFR-AK-CAZ-SC 376077.19 MWD+IFR-AK-CAZ-SC 376026.35 MWD+IFR-AK-CAZ-SC 375975.88 MWD+IFR-AK-CAZ-SC 375925.28 MWD+IFR-AK-CAZ-SC 375874.54 MWD+IFR-AK-CAZ-SC 375823.40 MWD+IFR-AK-CAZ-SC 375771.46 MWD+IFR-AK-CAZ-SC 375720.02 MWD+IFR-AK-CAZ-SC 375669.54 MWD+IFR-AK-CAZ-SC 375619.52 MWD+IFR-AK-CAZ-SC 375569.21 MWD+IFR-AK-CAZ-SC 375517.86 MWD+IFR-AK-CAZ-SC 375465.07 MWD+IFR-AK-CAZ-SC 375411.21 MWD+IFR-AK-CAZ-SC 375357.67 MWD+IFR-AK-CAZ-SC 375305.50 MWD+IFR-AK-CAZ-SC 375255.11 MWD+IFR-AK-CAZ-SC 375207.17 MWD+IFR-AK-CAZ-SC 375162.66 MWD+IFR-AK-CAZ-SC 375119.85 MWD+IFR-AK-CAZ-SC 375078.07 MWD+IFR-AK-CAZ-SC 375038.93 MWD+IFR-AK-CAZ-SC 375003.57 MWD+IFR-AK-CAZ-SC 374971.87 MWD+IFR-AK-CAZ-SC 374943.87 MWD+IFR-AK-CAZ-SC 374920.21 MWD+IFR-AK-CAZ-SC 374901.77 MWD+IFR-AK-CAZ-SC 374889.12 MWD+IFR-AK-CAZ-SC 374880.90 MWD+IFR-AK-CAZ-SC 374875.81 MWD+IFR-AK-CAZ-SC 374873.53 MWD+IFR-AK-CAZ-SC 374874.74 MWD+IFR-AK-CAZ-SC 374880.37 MWD+IFR-AK-CAZ-SC 374890.84 MWD+IFR-AK-CAZ-SC 7076. 70 49. 24 184 .39 5710.86 5653 .96 -2244. 20 7172. 14 51. 35 181 .74 5771.83 5714 .93 -2317. 51 7267. 81 53. 56 179 .87 5830.13 5773 .23 -2393. 35 7363. 40 56. 12 176 .56 5885.18 5828 .28 -2471. 43 7458. 93 59. 61 173 .64 5936.00 5879 .10 -2552. 00 7554. 19 63. 20 170 .17 5981.59 5924 .69 -2634. 77 • i Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12/20!2006 Time: 13:17:48 Page: 3 Field: Colville River Unit Co-ordinate(NF) Refere~ice: Well: CD4-214, True North Site: Alpine CD4 Verticat (TVD) Refereuce: CD4-214:56.9 Well: CD4-214 Section (YS) Reference: Well (O.OON,O.OOE,178.18Azi) Wellpath: CD4-214 Survey CaleulaHon Method: Minimum Curvature Db: Oracle Survey MD Inc! Azim T'VD Sys TVD NlS E1W D1apN A1apE Tool ft deg deg ft ft ft ft ft ft __ _-- 7649.23 65.65 167.39 6022.62 5965.72 -2718.84 -2972.32 5954795.32 374906.17 MWD+IFR-AK-CAZ-SC ~ 7742.44 68.32 164.86 6059.07 6002.17 -2802.10 -2951.73 5954711.74 374925.40 MWD+IFR-AK-CAZ-SC 7839.67 71.57 162.33 6092.41 6035.51 -2889.69 -2925.92 5954623.75 374949.78 MWD+IFR-AK-CAZ-SC 7934.41 74.76 159.98 6119.85 6062.95 -2975.49 -2896.62 5954537.50 374977.68 MWD+IFR-AK-CAZ-SC I 8029.97 77.95 155.85 6142.40 6085.50 -3061.50 -2861.70 5954450.94 375011.20 MWD+IFR-AK-CAZ-SC j 8125.54 80.47 152.23 6160.29 6103.39 -3145.88 -2820.60 5954365.91 375050.92 MWD+IFR-AK-CAZ-SC 8220.74 83.51 148.35 6173.56 6116.66 -3227.73 -2773.89 5954283.32 375096.30 MWD+IFR-AK-CAZ-SC Ili 8316.09 84.49 146.34 6183.53 6126.63 -3307.56 -2722.72 5954202.67 375146.15 MWD+IFR-AK-CAZ-SC i 8411.92 85.98 144.57 6191.49 6134.59 -3386.21 -2668.57 5954123.16 375199.02 MWD+IFR-AK-CAZ-SC I, 8506.82 86.17 144.18 6197.99 6141.09 -3463.17 -2613.42 5954045.32 375252.90 MWD+IFR-AK-CAZ-SC 8602.10 86.41 143.75 6204.15 6147.25 -3540.06 -2557.49 5953967.54 375307.58 MWD+IFR-AK-CAZ-SC j 8678.56 86.10 144.93 6209.15 6152.25 -3602.05 -2513.01 5953904.84 375351.04 MWD+IFR-AK-CAZ-SC 8747.48 85.56 144.92 6214.16 6157.26 -3658.30 -2473.51 5953847.96 375389.62 MWD+IFR-AK-CAZ-SC j, 8842.51 85.07 145.44 6221.92 6165.02 -3736.06 -2419.43 5953769.34 375442.42 MWD+IFR-AK-CAZ-SC 8936.87 84.51 146.81 6230.49 6173.59 -3814.07 -2367.06 5953690.49 375493.52 MWD+IFR-AK-CAZ-SC 9032.07 83.70 149.23 6240.27 6183.37 -3894.39 -2316.91 5953609.38 375542.36 MWD+IFR-AK-CAZ-SC '~ 9123.96 84.70 151.47 6249.56 6192.66 -3973.83 -2271.68 5953529.22 375586.28 MWD+IFR-AK-CAZ-SC i 9222.62 87.05 154.28 6256.65 6199.75 -4061.40 -2226.83 5953440.94 375629.70 MWD+IFR-AK-CAZ-SC 9318.28 90.44 156.40 6258.75 6201.85 -4148.30 -2186.94 5953353.41 375668.17 MWD+IFR-AK-CAZ-SC 9413.98 93.53 157.14 6255.43 6198.53 -4236.18 -2149.22 5953264.94 375704.46 MWD+IFR-AK-CAZ-SC j 9509.16 93.41 155.57 6249.67 6192.77 -4323.20 -2111.11 5953177.32 375741.14 MWD+IFR-AK-CAZ-SC ~ 9604.53 93.53 153.56 6243.90 6187.00 -4409.17 -2070.23 5953090.71 375780.62 MWD+IFR-AK-CAZ-SC 9699.52 92.23 151.36 6239.13 6182.23 -4493.28 -2026.37 5953005.90 375823.10 MWD+IFR-AK-CAZ-SC 9794.91 91.86 152.17 6235.72 6178.82 -4577.27 -1981.27 5952921.20 375866.83 MWD+IFR-AK-CAZ-SC I i 9890.13 93.59 152.82 6231.20 6174.30 -4661.62 -1937.35 5952836.15 375909.37 MWD+IFR-AK-CAZ-SC 9985.51 92.79 153.73 6225.89 6168.99 -4746.68 -1894.52 5952750.41 375950.81 MWD+IFR-AK-CAZ-SC 10080.88 92.66 155.18 6221.35 6164.45 -4832.63 -1853.44 5952663.82 375990.48 MWD+IFR-AK-CAZ-SC 10175.58 92.91 153.28 6216.75 6159.85 -4917.81 -1812.32 5952577.99 376030.21 MWD+IFR-AK-CAZ-SC 10270.90 89.52 151.91 6214.73 6157.83 -5002.40 -1768.47 5952492.71 376072.69 MWD+IFR-AK-CAZ-SC i 10366.23 86.00 151.50 6218.46 6161.56 -5086.26 -1723.32 5952408.13 376116.46 MWD+IFR-AK-CAZ-SC it 10461.16 82.89 154.58 6227.65 6170.75 -5170.45 -1680.49 5952323.26 376157.91 MWD+IFR-AK-CAZ-SC 10556.76 85.07 157.73 6237.67 6180.77 -5257.39 -1642.07 5952235.71 376194.92 MWD+IFR-AK-CAZ-SC 10652.10 84.14 157.15 6246.64 6189.74 -5345.05 -1605.65 5952147.49 376229.90 MWD+IFR-AK-CAZ-SC 10746.91 87.05 156.59 6253.92 6197.02 -5431.97 -1568.52 5952059.98 376265.61 MWD+IFR-AK-CAZ-SC 10842.23 90.50 156.36 6255.96 6199.06 -5519.33 -1530.49 5951972.02 376302.22 MWD+IFR-AK-CAZ-SC 10936.22 92.54 155.06 6253.46 6196.56 -5604.97 -1491.84 5951885.77 376339.46 MWD+tFR-AK-CAZ-SC 11033.26 91.61 152.50 6249.95 6193.05 -5691.95 -1449.00 5951798.11 376380.88 MWD+IFR-AK-CAZ-SC 11128.85 91.74 153.05 6247.16 6190.26 -5776.92 -1405.29 5951712.45 376423.21 MWD+IFR-AK-CAZ-SC 11224.14 91.86 153.48 6244.16 6187.26 -5861.98 -1362.44 5951626.71 376464.66 MWD+IFR-AK-CAZ-SC 11319.53 93.16 153.13 6239.99 6183.09 -5947.12 -1319.63 5951540.90 376506.08 MWD+IFR-AK-CAZ-SC 11414.90 91.85 152.46 6235.82 6178.92 -6031.85 -1276.07 5951455.47 376548.26 MWD+tFR-AK-CAZ-SC 11510.51 91.92 153.33 6232.67 6175.77 -6116.92 -1232.53 5951369.72 376590.40 MWD+IFR-AK-CAZ-SC 11605.91 91.92 153.56 6229.48 6172.58 -6202.20 -1189.91 5951283.76 376631.63 MWD+IFR-AK-CAZ-SC 11701.49 92.48 154.82 6225.81 6168.91 -6288.18 -1148.33 5951197.12 376671.81 MWD+IFR-AK-CAZ-SC 11795.46 91.92 151.92 6222.20 6165.30 -6372.11 -1106.24 5951112.53 376712.53 MWD+IFR-AK-CAZ-SC 11891.93 91.00 152.12 6219.74 6162.84 -6457.28 -1061.00 5951026.65 376756.38 MWD+IFR-AK-CAZ-SC 11987.07 92.17 152.84 6217.11 6160.21 -6541.62 -1017.05 5950941.61 376798.94 MWD+IFR-AK-CAZ-SC 12082.06 89.52 151.46 6215.71 6158.81 -6625.59 -972.69 5950856.94 376841.93 MWD+IFR-AK-CAZ-SC 12177.16 86.86 151.18 6218.71 6161.81 -6708.97 -927.08 5950772.83 376886.18 MWD+IFR-AK-CAZ-SC 12272.97 86.80 152.29 6224.01 6167.11 -6793.23 -881.77 5950687.86 376930.11 MWD+IFR-AK-CAZ-SC 12368.56 86.86 153.84 6229.30 6172.40 -6878.32 -838.54 5950602.09 376971.95 MWD+IFR-AK-CAZ-SC 12463.87 87.05 154.31 6234.36 6177.46 -6963.91 -796.93 5950515.83 377012.16 MWD+IFR-AK-CAZ-SC 12558.52 86.49 155.54 6239.69 6182.79 -7049.50 -756.88 5950429.61 377050.81 MWD+IFR-AK-CAZ-SC • . Halliburton Company Survey Report _ ___ Company: ConocoPhillips Alaska Inc. Date: 12/20/2006 Time: 13:17:48 Page: 4 Field: Colville River Unit Co-ordinate(VF,) Reference: Well: CD4-214, True North Site: Alpine CD4 Vertical (TV fl) Reference: CD4-214:56.9 Yell: CD4-214 Section (VS) Reference: Well (O.OON,O.OOE,178.18AZi) Wellpath: CD4-214 Survey Calculation iviethod: Minimum Curvature Db: Oracle Survey ___ MD Incl Acim TVD Sys TVD NlS E/yV i<1apN i41apF: Tool ft deg deg ft ft ft ft ft ft ___ _ __ _ _ __ _ __ ___ 12654.50 86.55 155.40 6245.52 6188.62 -7136.66 -717.11 5950341.83 377089.16 MWD+IFR-AK-CAZ-SC 12749.88 86.67 155.99 6251.16 6194.26 -7223.43 -677.92 5950254.44 377126.93 MWD+IFR-AK-CAZ-SC 12799.80 86.43 155.62 6254.16 6197.26 -7268.89 -657.50 5950208.66 377146.61 MWD+IFR-AK-CAZ-SC 12845.18 88.22 156.28 6256.28 6199.38 -7310.28 -639.02 5950166.98 377164.41 MWD+IFR-AK-CAZ-SC 12940.23 89.33 156.52 6258.31 6201.41 -7397.36 -600.98 5950079.30 377201.03 MWD+IFR-AK-CAZ-SC 13035.53 91.49 156.92 6257.63 6200.73 -7484.89 -563.32 5949991.17 377237.26 MWD+tFR-AK-CAZ-SC 13130.74 92.29 155.04 6254.49 6197.59 -7571.81 -524.59 5949903.65 377274.57 MWD+IFR-AK-CAZ-SC 13226.11 91.74 152.63 6251.14 6194.24 -7657.34 -482.56 5949817.45 377315.20 MWD+IFR-AK-CAZ-SC 13321.38 91.55 153.31 6248.40 6191.50 -7742.17 -439.28 5949731.94 377357.09 MWD+IFR-AK-CAZ-SC 13415.46 92.05 153.33 6245.45 6188.55 -7826.19 -397.06 5949647.25 377397.94 MWD+IFR-AK-CAZ-SC 13511.16 92.35 153.47 6241.77 6184.87 -7911.70 -354.24 5949561.06 377439.36 MWD+IFR-AK-CAZ-SC 13606.65 92.42 153.73 6237.80 6180.90 -7997.16 -311.82 5949474.93 377480.39 MWD+IFR-AK-CAZ-SC 13700.23 91.74 153.74 6234.40 6177.50 -8081.02 -270.44 5949390.42 377520.40 MWD+IFR-AK-CAZ-SC ~ 13795.32 91.80 154.10 6231.47 6174.57 -8166.39 -228.65 5949304.39 377560.79 MWD+IFR-AK-CAZ-SC 13892.31 92.23 153.56 6228.06 6171.16 -8253.38 -185.90 5949216.72 377602.12 MWD+IFR-AK-CAZ-SC 13988.24 92.11 154.36 6224.42 6167.52 -8339.51 -143.82 5949129.93 377642.79 MWD+IFR-AK-CAZ-SC 14083.60 92.29 153.46 6220.76 6163.86 -8425.09 -101.92 5949043.69 377683.30 MWD+IFR-AK-CAZ-SC 14178.41 92.42 153.56 6216.87 6159.97 -8509.87 -59.66 5948958.23 377724.17 MWD+IFR-AK-CAZ-SC 14273.91 88.59 153.14 6216.02 6159.12 -8595.21 -16.84 5948872.22 377765.60 MWD+IFR-AK-CAZ-SC 14368.93 85.94 152.38 6220.56 6163.66 -8679.59 26.60 5948787.16 377807.66 MWD+IFR-AK-CAZ-SC 14464.49 83.57 153.97 6229.29 6172.39 -8764.50 69.54 5948701.57 377849.21 MWD+IFR-AK-CAZ-SC 14559.40 83.21 156.51 6240.22 6183.32 -8850.10 109.03 5948615.34 377887.29 MWD+IFR-AK-CAZ-SC 14654.86 84.07 157.46 6250.80 6193.90 -8937.42 146.12 5948527.44 377922.96 MWD+IFR-AK-CAZ-SC 14750.62 85.81 158.80 6259.24 6202.34 -9025.94 181.64 5948438.36 377957.04 MWD+IFR-AK-CAZ-SC 14845.95 85.93 158.55 6266.11 6209.21 -9114.51 216.22 5948349.25 377990.17 MWD+IFR-AK-CAZ-SC 14940.08 86.61 158.94 6272.23 6215.33 -9202.05 250.27 5948261.17 378022.80 MWD+IFR-AK-CAZ-SC 15034.27 86.86 159.86 6277.60 6220.70 -9290.07 283.36 5948172.63 378054.44 MWD+IFR-AK-CAZ-SC • 15072.00 86.86 159.86 6279.66 6222.76 -9325.44 296.33 5948137.06 378066.84 PROJECTED to TD ~ • 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: ConocoPhillips Alaska, Inc FIELD !UNIT /PAD: Colville River Field /Alpine /CD4 DATE: 11 /13/06 OPERATOR REP: D. Lutrick / D. Mickey AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION hAechanical Integrity Test • Packer Depth Pretest Initial 15 Min. 30 Min. Well CD4-214 T e in'. N TVD 5,967' Tubing 2,500 2,800 2,800 2,800 Interval I P.T:D. 206-145 Type test P Test psi 3500 Casing 3,507 3,391 3,367 P/F P Notes: OA Well Type Inj. TVD Tubing interval P.T.D. T e test Test psi Casin P/F Notes: OA WeII T e In'. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well T e Inj. TVD Tubing Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casin 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 = Intemal 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 Fonn CD4-214 ~ STATE OF ALASKA s '~vosi°a OlL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ~~m #~G~~ ~a~cr:iP.state.alc.us• ~I, ao~. pr~.4d~~oe bat o,ad:nn.stae.ak.us b+~l ?ecken;a~S~n~`Y)c:~~#~'Ei'3.5tc~t~.~?i.~i Contractor: Doyon Rig No.: 19 DATE: 10/30/2006 Rig Rep.: Krupa / 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 CD4-214 PTD # 206-145 Operation: Drfg: x Test: Initial: x 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 Annular Preventer 1 13-5/8 Pipe Rams 1 3-1/2x 6 Lower Pipe Rams 1 3-1/2x 6 Blind Rams 1 blinds 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: Explor.: Weekly: Bi-Weekly Annular: 250/3500 Valves: 250/5000 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test R P Upper Kelly 1 P P Lower Kelly 1 P P Ball Type 1 P Inside BOP 1 P Test Result CHOKE MANIFOLD: P Quantity Test R~ FP No. Valves 16 P P Manual Chokes 1 P P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Resu System Pressure 3000 P Pressure After Closure 1500 P 200 psi Attained 19 P Full Pressure Attained 2 min 35 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 1950 psi Test Results Number of Failures: 3 Test Time: 12.50 Hours Components tested 30 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: ~i~ ~-e~~:~~ad~:in.stat~.alc,i~~• Remarks: Top set VBR's Failed. Replaced elements retested OK. Top flange on mud cross leaked, torque up. Retested OK. Flange on choke line leaked. Replaced OTECO Ring. Retested OK. 24 HOUR NOTICE GIVEN YES X NO Date 10/28/06 Time 7:OOam est start Finish Waived By Not waived Witness Chuck Scheve BOP Test (for rigs) BFL 11/09/04 Doyon19 10-30-06 CD4-214.x1s RE: CD4-214 • • Subject: RE: CD4-214 From: "Galiunas, Elizabeth C" <Elizabeth.GGaliunas a)conoeophillips.com> Date: Mon, 16 Oct2006 13:44:12 -0800 '['o: "]~homas ~~1~~undrr ~~tom maunder(r?adn~in.statc.ak.us== Tom, to reconcile here is the revised Annular Pumping Operations paragraph stating there are two hydrocarbon bearing zones, the Qannik and the Nanuq. The CD4-214 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Nanuq reservoir and the Qannik reservoir. There will be 500' of cement fill above the top of the Nanuq reservoir along with 500' above and below the Qannik reservoir as per regulations. Thanks, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 -----Original Message----- From: Thomas Maunder [mailto:to=r: maunder~yadmin.state,ak.us] Sent: Monday, October 16, 2006 1:37 PM To: Galiunas, Elizabeth C Cc: Dave Roby Subject: CD4-214 Liz, Just starting to review the permit package. In the cover letter, it is stated that the Qannik interval could be considered a significant hydrocarbon bearing zone. In the annulus pumping section it is stated that the only significant hydrocarbon zone in the intermediate hole is the Nanuq. Would you please reconcile these statements? Tom Maunder, PE AOGCC 1 of 1 10/16/2006 1:47 PM C. Alvord WNS Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Re: Colville River Field, Nanuq Oil Pool, CD4-214 Company ConocoPhillips Alaska, Inc. Permit No: 206-145 Surface Location: 2947' FNL, 321' FEL, SEC. 24, Tl 1N, R4E Bottomhole Location: 1400' FNL, 138' FEL, SEC. 36, 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) 659-3607 (pager). Sincerely, Cathy . Foerster Commissioner ~f DATED this day of October, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. a ConocoPhilli s Alaska, Inc. p Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 9, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drilt CD4-214 Dear Sir or Madam: ~Q["1C1C0 "ill 5 p ~~,T 1 ~ 2006 Alaska dil & Gax C©rwso Cpmtnission Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore njector well from the Nanuq (CD4) drilling pad. The intended spud date for this well is 11/4/2006. It is intended that Doyon Rig 19 be used to drill the well. After setting 7" intermediate casing, the undulating horizontal section will be drilled and the well completed as a slotted liner injector. At the end of the rig work program, the well will be flowed back for / 2-3 days to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities connection that will allow the well to begin injection. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. ' Hydraulic modeling indicates that it is not technically feasible to place cement from the 7" casing shoe up to 500' above the K2, due to the distance between the two points, so a variance under 20 AAC 25.030 (g) is necessary. It is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap _ between the two stages. It is also requested that the packer placement requirement be relaxed to place the completion packer +/- +/- 250 ft TVD above the Nanuq 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. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. There have been 8 surface holes drilled at CD4 and there has not been a significant show of shallow gas or gas hydrates. `' 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. • • If you have any questions or require further information, please contact Liz Galiunas at 265- 6247, or Chip Alvord at 265-6120. Sincerely, Liz Galiunas Drilling Engineer Attachments cc: CD4-214 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Liz Galiunas ATO 1704 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation RECEIVED ~~ O C T 1 0 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION A~aSka OII & GaS CUnS. CommISS~~rt I PERMIT TO DRILL 20 AAC 25.005 Anchorage '~ ~~ 1 a. Type of Work: Drill ^/ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^~ Development Gas ^ Multiple Zone^ Single Zone Q ~ 1 c. 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: CD4-214 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14375' TVD: 6196' 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 2947' FNL, 321' FEL,. Sec 24 T11 N R4E 7. Property Designation: ADL 380077, 384209, 388902 Nanuq Nanuq Oil Pool Top of Productive Horizon: 1068' FNL 2979' FEL, Sec. 25 T11 N R4E 8. Land Use Permit: ALK 380077 13. Approximate Spud Date: 11/41200& Total Depth: 1400' FNL 138' FEL, Sec. 36 T11 N R4E 9. Acres in Property: 2560 14. Distance to Nearest Property:3860' nanuq PA 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377922 y- 5957465 Zone- 4 10. KB Elevation (Height above GL): 37' RKB feet 15. Distance to Neare;tom u.,~ Z gc~, Well within Pool~;.~laa~~ T ~ 16. Deviated wells: Kickoff depth: 400. ft. Maximum Hole Angle: 91° - deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2804 psig Surface: 2184 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 114' pre-installed 12.25" 9-5(8" 40# L-80 BTC 2678 37 37 2715 2400 516 sx AS Lite3, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 8358 37 37 8395 6196 234sx 15.8G, 2nd stage 49 sx ASL3 4.5" 12.6# L-80 SLHT 6444 8280 6196 14724 6196 Slotted Liner 4.5" 12.6 L-80 IBT-M 8248 32 32 8280 6181 tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling ProgramQ Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Ga(iunas Printed Name C. Alvord Title WNS Drilling Team Lead Signature ~ Phone Z~ S 6 /2..~ Date 1~0~~ (OL l Commission Use Only Permit to Drill // c Number: ~~f0 ~ ~~•••~ API Number: 50- a/~3' ~ S3 ~• D~ Permit Appro Date: val ~ ~ ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be u d to explore for, test, or produce Coalbed m than ,gas hydrates, or gas contained in shales: ~~~ h+t ~~+ ^ +~ ~ ~~~ ` ~~~~C~c~~~~Samples req'd: Yes ^ No ~ Mud log req'd: Ye~] No[]' Other: t'> H2S measures: Yes ^ No [v]' Directional svy req'd: Yes [~ No ^ M ~~ ~ «~~~cwc-.~~~ ~o S?c,.~~cr~~~lt~ ~c€~a~tE a O ~C.~-~~, WSC~C.c~~ OV COM SION DATE: ISSIONER f •/~• Cnhmif in rluniicat ~~ Orm lU-4U1 KeVISeQ 7Z/LVUb CD4-214 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" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro sin le shots, travelin c tinder 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 HZS 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 HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers • • Nanug : CD4-214 Procedure 1) Move on Doyon 19, dewater cellar as needed. 2) Rig up riser. • 3) Drill 12-%4" hole to the surface casing point as per the directional plan. (Directional/MWD).' 4) Run and cement 9-5/8" surface casing. 5) Install and test BOPE to 5000 psi. 6) Pressure test casing to 2500 psi. 7) Drill out 20' of new hole. Perform leak off test. 8) Pick up and run in hole with 8-3/4" drilling BHA. 9) Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 10) 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. 11) BOPE test to 5000 psi. 12) 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. 13) Displace well to Mineral oil based mud. . 14) Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD/Sonic tool for cement evaluation). 15) Circulate the hole clean and pull out of hole. 16) Run lower completion with slotted liner and liner hanger, set hanger and pull out of hole. 17) Run 4-'/2, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrels, packer and stinger assembly. Sting in, space out and land hanger. 18) Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19) Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20) Circulate tubing to diesel and install freeze protection in the annulus. 21) Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 22) Set BPV and secure well. Move rig off. ^,RI6INAL • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. Nanuq 5 is the closest well. Well separation is 42 @ 253' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nanuq 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. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD4-214 will be injected into a permitted annulus , on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-214 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Nanuq reservoir and there will be 500' of cement fill above the top of the Nanuq as per regulations. SSE ~w"o:~` ~'~~ ~t"'C'`~ Upon completion of CD4-214 form 10-403, Application for Sundry Operations, will be filed. Annular \'~~1co pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) " (0.052)'` (2400') + 1,500 psi = 2998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 -1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2.992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL • ~ DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint -12 %<" Intermediate hole to 7" casing point - 8 3/4" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 8.1-8.8 PP9 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) NA HPHT Fluid Loss at 160 12-14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0-9.5 KCL 6% Oil /water ratio Approx. 60/40 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 60/40 oil/water ratio M-I Versa-Pro mineral oil based ~' drill-in fluid. The base fluid will consist of high flashpoint (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. ORIGINAL • • CD4 - 214 Nanuq Nanuq Injector Completion Sperry Sun 16" Insulated Conductor to Directional Plan WP04 114' 9/18/06 4-'/" 12.6 ppf L-80 IBT Mod Tubing 813" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2715' MD / 2400' TVD Upper Completion: Top MD TVD Item 1) Tubing Hanger 32' 32' 2) 4-%" 12.6 #/ft IBT-Mod Tubing 3) Camco DB nipple (3.813") 2199' 2000' 4) 4-%i' 12.6 #/ft IBT-Mod Tubing 5) Camco KBG- GLM (3.833" ID) w/DCK-2 7423' 5907' 6) 4-'/2' 12.6 #/ft IBT-Mod Tubing (2) 7) Baker Premier Packer 7523' 5954' TOC 8) 4-'/" 12.6 #/ft IBT-Mod Tubing (1) +/-4407' MD / 3709' TVD 9) HES "XN" (3.750")- 64.0° inc 7573' 5977' Stage 10) 4 '/" 12.6 #/ft IBT-Mod Tubing +/- 12 jts cementing tool 11) BOT Stinger with Fluted WLEG/ stinger 8177' 6181' +/- 5431' MD / ~s Stung into tieback extension 10', bottom at 8270' 4501' TVD K2/Qannik sand +/-4907 MD / 4096' TVD Lower Completion: Top MD ND lem 12) Baker 5" x 7" Flexlock Liner Hanger 8280' 6182' 13) 4-'/2', 12.6#/ft, SLHT Tubing +/- 4 jts 14) 4 Y" 12.6#/ft L-80 SLHT liner w/blank across shale and slots across sand 15) Baker Shoe w/ packoff bushing 14724' 6196' Top of cement ` 7223' MD / 5801' TVD Top Reservoir at +/- Nanuq 8352' MD / 6190' 4-'/" 12.6#/ft L-80 SLHT Mod Slotted Liner Pattern: 32 slots/ft, 2-%4' x 1/8" slots 7" 26 ppf L-80 BTC Mod Production Casing @ +/-86° 8430' MD, 6196' TVD TD 6-1/8" hole ' 14734' MD / 6196' TVD ORIGINAL • • CD4-214 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 2540 / 2400 14.5 1086 1570 7" 8352/6196 16.0 2804 2184 N/A 14734 / 6196 16.0 2804 ~ 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=[(FGx0.052)-0.1] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1 ] x 2400 = 1570 psi OR ASP =FPP - (0.1 x D) = 2804 - (0.1 x 6196') = 2184 psi Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 2804 - (0.1 x 6196') = 2184 psi ORIGINAL • • Cementing Program: 9 5/8" Surface Casing run to 2715' MD / 2400' TVD. Cement from 2715' MD to 2215' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2215' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1000' MD). Lead slurry: (2215'-1600') X 0.3132 ft3/ft X 1.5 (50% excess) = 289 ft3 below permafrost 1600' X 0.3132 ft3/ft X 4 (300% excess) = 2004.5 ft3 above permafrost Total volume = 289 + 2004.5 = 2293.4 ft3 => 516 Sx @ 4.45 ft3/sk System: 516 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% BWOWI 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 Casing run to 8430' MD / 6196' TVD: Cemented in two stages Cement from 8430' MD to 7223' MD (300' MD above the packer & minimum 500' MD above top of Nanuq reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. First Stage• Lead: (8430' -7223') X 0.1503 ft3/ft X 1.4 (40% excess) = 254 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 254 + 17.2 = 271.2 ft3 => 234 Sx @ 1.16 ft3/sk System: 234 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 Second Stage: Cement from ports in a stage tool set 500' below the K2 interval (4907' MD) to +/- 500' above the K2 interval with ArcticSet Lite 3 @ 10.7 ppg. Assume 40% excess annular volume Lead: (5431'-4407') X 0.1503 ft3/ft X 1.4 (40% excess) = 215.5 ft3 annular vol. Total Volume = 215.5 ft3 => 49 Sk @ 4.45 ft3/sk System: 49 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% D 124 extender and 9% B WOW2 D044 freeze suppressant ' By Weight Of mix Water, all other additives are BWOCement ~RlGINAL ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 10/6/2006 Tfine: 15:56:09 Page: 1 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plarr. CD4-214, True North Site: Alpine CD4 Vertical (TVD) Reference: Plan CD4-214.56.1. Well: Plan: CD4-214 Section (VS) Reference: Well (O.OON,O.OOE,178.83Azi) Wellpath: Plan: CD4-214wp04 Survey Calculation Method: Minimum Curvature Db: Oracle Plan: CD4-214wp04 Date Composed: 9/18/2006 Version: 10 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: bggm2006 Site: Alpine CD4 Site Position: Northing: 5957526.10 ft Latitude: 70 17 32.966 N From: Map Easting: 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: CD4-214 Slot Name: Alpine CD4 Well Position: +N/-S -64.88 ft Northing: 5957465.31 ft - Latitude: 70 17 32.328 N +E/-W -251.70 ft Easting : 377922.00 ft • Longitude: 150 59 18.098 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD4-214wp04 Drilled From: Well Ref. Point Tie-on Depth: 36.30 ft Current Datum: Plan CD4-214 Height 56.10 ft Above System Datum: Mean Sea Level Magnetic Data: 10/6/2006 Declination: 23.03 deg Field Strength: 57549 nT Mag Dip Angle: 80.66 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 178.83 Survey Program for Definitive Wellpath Date: 9/18/2006 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft d eg/100ft deg 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 7.50 228.31 699.14 -13.04 -14.64 2.50 2.50 0.00 228.31 1766.19 39.30 239.99 1665.43 -233.97 -368.22 3.00 2.98 1.10 14.01 5893.99 39.30 239.99 4859.69 -1541.61 -2632.18 0.00 0.00 0.00 0.00 8429.43 86.52 147.73 6196.10 -3400.45 -2656.98 3.50 1.86 -3.64 -93.95 CD4-214wp04 T1 8476.15 85.85 146.49 6199.21 -3439.59 -2631.67 3.00 -1.44 -2.64 -118.65 9049.25 85.85 146.49 6240.68 -3916.20 -2316.13 0.00 0.00 0.00 0.00 9336.77 90.00 154.06 6251.10 -4165.50 -2173.83 3.00 1.44 2.63 61.43 CD4-214wp04 T2 9459.76 93.69 154.04 6247.14 -4276.02 -2120.05 3.00 3.00 -0.02 -0.34 10113.70 93.69 154.04 6205.06 -4862.76 -1834.38 0.00 0.00 0.00 0.00 10236.70 90.00 154.09 6201.10 -4973.29 -1780.62 3.00 -3.00 0.04 179.27 CD4-214wp04 T3 10469.14 81.97 154.09 6217.35 -5181.69 -1679.39 3.45 -3.45 0.00 179.95 10582.82 81.97 154.09 6233.22 -5282.95 -1630.21 0.00 0.00 0.00 0.00 10838.51 90.00 154.07 6251.10 -5512.16 -1518.82 3.14 3.14 -0.01 -0.20 CD4-214wp04 T4 10924.37 92.58 154.07 6249.17 -5589.35 -1481.28 3.00 3.00 0.00 0.00 11951.03 92.58 154.07 6203.03 -6511.69 -1032.76 0.00 0.00 0.00 0.00 12036.89 90.00 154.07 6201.10 -6588.89 -995.22 3.00 -3.00 0.01 179.89 CD4-214wp04 T5 12159.71 86.32 154.07 6205.05 -6699.27 -941.56 3.00 -3.00 0.00 -180.00 12814.91 86.32 154.07 6247.15 -7287.30 -655.67 0.00 0.00 0.00 0.00 12937.72 90.00 154.07 6251.10 -7397.68 -602.00 3.00 3.00 0.00 0.03 CD4-214wp04 T6 12997.16 91.78 154.07 6250.18 -7451.12 -576.02 3.00 3.00 0.00 0.00 14734.96 91.78 154.07 6196.10 -9013.27 183.40 0.00 0.00 0.00 0.00 CD4-214wp04 T7 ORIGINAL c q O 25 O ^~ + 3 ~e < ~ T$ ma 8 g o. a $ Ss L mH s oz a~ .~~ c ~ _ i ~Y Q~ .~ s 0 0 O V _ ,~ _ _ .. _.. ~, ~.. - - ~ ~ ~~ ~ ~ , ~ ~ ~ ~ - o ~ , ,,, _ ~ ~~ ~. ~. ~ _ i~ . ~~ :. ~ ~ ~ ~; In!/8005] ~+)4uoAI/(-)4mos ~ z 3 00 o _° a ^, 0 z 7 ~ .] 'N+1 r 0 5 g ~ a W W Prn Q ~7 Y J ~ _ ~ 9 'n 3 ;~ O ~ z N 3 N ~ m z ~ N Q v v z a d _EE ~ dm =5 ~ u Pc.G~YfeY Q ~ .. <~- ~ ~ ~"p5& ~3 LL a888$88aa ~ xa~~3~e3x ~ $ ~ ~ ~~ A ~ ~ ¢ 3 ~ fi fi o ae,sas$aci~rsa~~g$eassa ~` Q @ °<9 2Ae R~ee P $8A$8$8B$$$8 8.$$$afla$8 a ~ egad? a a a nap$&e~S$ ~ a AnAnnP azPZ a"s aa9$es b q ~ aeas ^xRRg a3 $$ a _G. F s$$s~ssy as Aa iaag<<RP Y 88RRF,p~gB 88$SS,$PT$#.'~'8 FR ~~ ~ $ :8s&8 8608. 8~a Q Rd$$88ss a°y~yRR .Rg~ '6yLy~ 46$ ~~_P 336&a ~a 8b ~~=RraA ~_ mss= ~~ y~W~~ ~ ~~=_~ s~ E~~~~3 ~"~ l~-~ ~E - F 5 ~ vv $ eE~ - ~ d S ~ 6 gS~ E 3 S2A ~ a~ s goo sE e~zga ~aa 8,% 6~~~ z _.~.. ` b~ ~n Q~~~~ g $a~~s - F ~ S sod gem hm~rn ~~-i°-F g ss-s.~a~m~x ~88e"°•" ~= as 's; ~ 8 «~ » ~~$.a<~nean Y ~< ~~ a+ $ s~ a~ ~c ~~ ~~ 25 e ~ ~~ ,~ ~~ - ~~. 1 i ~ ~ 93° - ~ ~ -- '-- ~~ i i - - '" i i ~ ~ ~~ ~ ~ Ii .. ~ ~. II ~~ I.I ~~ i.i ~ .. ii ~ ,. ii ii 1 i ~ _- ° I - n 98 ~ c ~ i f i i ~ I.I _._ 8 ~ c ~~ ~ . m I- ~ - ~ _..- . ~ ~ I S ' i c 3 x~ ~~ ~ , V _. _. $ y ft I i .. _ ~ ~~ ii: I II. 11' 1 I {I- : - _ . ~. ,~ i i ~u!P3005] 41daQ ~ea!uan amp c 0 0 m A 0 U W V1 u onocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 10/6/2006 Time: 15:56:09 Page: 2 Field: Colville River Unit Co-ord inate(NE) Reference: Well: Plan: CD4-214, True North Site: Alpine CD4 Vertica l (TVD) Reference: P lan CD4-214 56.1 Well: Plan: CD4-2 14 Section (VS) Reference: Well (O.OON,O. OOE,178 .83Azi) Wellpath: Plan: CD4-2 14wp04 Survey Calculation Method: Minimum Curvature Db: Oracle: Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 36. 30 0 .00 0. 00 36. 30 -19 .80 0. 00 0. 00 5957465 .31 - 377922 .00 • 0.00 0. 00 100. 00 0 .00 0. 00 100. 00 43 .90 0. 00 0. 00 5957465 .31 377922 .00 0.00 0. 00 200. 00 0 .00 0. 00 200. 00 143 .90 0. 00 0. 00 5957465 .31 377922 .00 0.00 0. 00 300. 00 0 .00 0. 00 300. 00 243 .90 0. 00 0. 00 5957465 .31 377922 .00 0.00 0. 00 • 400. 00 0 .00 0. 00 400. 00 343 .90 0. 00 0. 00 5957465 .31 377922 .00 0.00 0. 00 500. 00 2 .50 228. 31 499. 97 443 .87 -1. 45 -1. 63 5957463 .89 377920 .35 2.50 1. 42 600. 00 5 .00 228. 31 599. 75 543 .65 -5. 80 -6. 51 5957459 .62 377915 .39 2.50 5. 67 700. 00 7 .50 228. 31 699. 14 643 .04 -13. 04 -14. 64 5957452 .51 377907 .15 2.50 12. 74 800. 00 10 .44 232. 32 797. 91 741 .81 -22. 92 -26. 69 5957442 .83 377894 .95 3.00 22. 37 900. 00 13 .40 234. 58 895. 75 839 .65 -35. 17 -43. 30 5957430 .85 377878 .14 3.00 34. 29 1000. 00 16 .38 236. 03 992. 38 936 .28 -49. 77 -64. 44 5957416 .60 377856 .77 3.00 48. 45 1100. 00 19 .36 237. 04 1087. 54 1031 .44 -66. 67 -90. 04 5957400 .12 377830 .89 3.00 64. 82 1200. 00 22 .35 237. 79 1180. 98 1124 .88 -85. 83 -120. 05 5957381 .45 377800 .59 3.00 83. 37 1300. 00 25 .34 238. 38 1272. 44 1216 .34 -107. 18 -154. 36 5957360 .66 377765 .93 3.00 104. 02 1393. 58 28 .14 238. 81 1356. 00 1299 .90 -129. 12 -190. 30 5957339 .31 377729 .64 3.00 125. 22 Base Permafrost 1400. 00 28 .33 238. 84 1361. 66 1305 .56 -130. 69 -192. 90 5957337 .78 377727 .02 3.00 126. 74 1500. 00 31 .33 239. 23 1448. 40 1392 .30 -156. 27 -235. 55 5957312 .90 377683 .96 3.00 151. 45 1600. 00 34 .32 239. 55 1532. 42 1476 .32 -183. 87 -282. 20 5957286 .06 377636 .87 3.00 178. 09 1700. 00 37 .32 239. 83 1613. 50 1557 .40 -213. 40 -332. 72 5957257 .36 377585 .89 3.00 206. 58 1766. 19 39 .30 239. 99 1665. 43 1609 .33 -233. 97 -368. 22 5957237 .37 377550 .06 3.00 226. 43 1800. 00 39 .30 239. 99 1691. 60 1635 .50 -244. 68 -386. 76 5957226 .97 377531 .35 0.00 236. 76 1900. 00 39 .30 239. 99 1768. 98 1712 .88 -276. 36 -441. 61 5957196 .18 377476 .00 0.00 267. 32 2000. 00 39 .30 239. 99 1846. 37 1790 .27 -308. 04 -496. 46 5957165 .40 377420 .65 0.00 297. 87 2100. 00 39 .30 239. 99 1923. 75 1867 .65 -339. 71 -551. 30 5957134 .62 377365 .30 0.00 328. 43 2200. 00 39 .30 239. 99 2001. 13 1945 .03 -371. 39 -606. 15 5957103 .84 377309 .95 0.00 358. 99 2300. 00 39 .30 239. 99 2078. 52 2022 .42 -403. 07 -661. 00 5957073 .06 377254 .60 0.00 389. 54 2400. 00 39 .30 239. 99 2155. 90 2099 .80 -434. 75 -715. 84 5957042 .28 377199 .25 0.00 420. 10 2462. 15 39 .30 239. 99 2204. 00 2147 .90 -454. 44 -749. 93 5957023 .14 377164 .85 0.00 439. 09 C-40 2500. 00 39 .30 239. 99 2233. 29 2177 .19 -466. 43 -770. 69 5957011 .49 377143 .90 0.00 450. 66 2600. 00 39 .30 239. 99 2310. 67 2254 .57 -498. 11 -825. 54 5956980 .71 377088 .55 0.00 481. 21 2700. 00 39 .30 239. 99 2388. 05 2331 .95 -529. 79 -880. 38 5956949 .93 377033 .20 0.00 511. 77 2725. 77 39 .30 239. 99 2408. 00 2351 .90 -537. 95 -894. 52 5956942 .00 377018 .94 0.00 519. 64 C-30 2800. 00 39 .30 239. 99 2465. 44 2409 .34 -561. 47 -935. 23 5956919 .15 376977 .85 0.00 542. 32 2900. 00 39 .30 239. 99 2542. 82 2486 .72 -593. 15 -990. 08 5956888 .37 376922 .51 0.00 572. 88 3000. 00 39 .30 239. 99 2620. 21 2564 .11 -624. 82 -1044. 92 5956857 .59 376867 .16 0.00 603. 44 3100. 00 39 .30 239. 99 2697. 59 2641 .49 -656. 50 -1099. 77 5956826 .81 376811 .81 0.00 633. 99 3200. 00 39 .30 239. 99 2774. 97 2718 .87 -688. 18 -1154. 62 5956796 .02 376756 .46 0.00 664. 55 3201. 33 39 .30 239. 99 2776. 00 2719 .90 -688. 60 -1155. 34 5956795 .62 376755 .72 0.00 664. 96 C-20 3300. 00 39 .30 239. 99 2852. 36 2796 .26 -719. 86 -1209. 46 5956765 .24 376701 .11 0.00 695. 11 3400. 00 39 .30 239. 99 2929. 74 2873 .64 -751. 54 -1264. 31 5956734 .46 376645 .76 0.00 725. 66 3500. 00 39 .30 239. 99 3007. 13 2951 .03 -783. 22 -1319. 16 5956703 .68 376590 .41 0.00 756. 22 3600. 00 39 .30 239. 99 3084. 51 3028 .41 -814. 90 -1374. 00 5956672 .90 376535 .06 0.00 786. 78 3700. 00 39 .30 239. 99 3161. 89 3105 .79 -846. 58 -1428. 85 5956642 .12 376479 .71 0.00 817. 33 3800. 00 39 .30 239. 99 3239. 28 3183 .18 -878. 26 -1483. 70 5956611 .33 376424 .36 0.00 847. 89 3900. 00 39 .30 239. 99 3316. 66 3260 .56 -909. 94 -1538. 54 5956580 .55 376369 .01 0.00 878. 45 4000. 00 39 .30 239. 99 3394. 05 3337 .95 -941. 61 -1593. 39 5956549 .77 376313 .66 0.00 909. 00 4100. 00 39 .30 239. 99 3471. 43 3415 .33 -973. 29 -1648. 24 5956518 .99 376258 .31 0.00 939. 56 4200. 00 39 .30 239. 99 3548. 81 3492 .71 -1004. 97 -1703. 08 5956488 .21 376202 .96 0.00 970. 12 4300. 00 39 .30 239. 99 3626. 20 3570 .10 -1036. 65 -1757. 93 5956457 .43 376147 .61 0.00 1000. 67 4400. 00 39 .30 239. 99 3703. 58 3647 .48 -1068. 33 -1812. 78 5956426 .65 376092 .27 0.00 1031. 23 4500. 00 39 .30 239. 99 3780. 97 3724 .87 -1100. 01 -1867. 62 5956395 .86 376036 .92 0.00 1061. 79 4581. 46 39 .30 239. 99 3844. 00 3787 .90 -1125. 81 -1912. 30 5956370 .79 375991 .83 0.00 1086. 68 K-3 4600. 00 39 .30 239. 99 3858. 35 3802 .25 -1131. 69 -1922. 47 5956365 .08 375981 .57 0.00 1092. 34 ORIGINAL onocoPhilhps Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 10/6/2006 Tim e: 15:56:09 Page: 3 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD4-214, True North. Site: Alpine CD4 Vertical (TVD) Reference: Plan CD4-214 56.1 Well: Plan: CD4-214 Section (VS) Reference: Well (O.OON,O.OOE,178:83Azi) Wellpath: Plan: CD4-214wp04 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD ft 4700.00 4800.00 4900.00 4907.10 5000.00 5042.79 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5893.99 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600,00 6700,00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7300.77 7400.00 7500.00 7600.00 7700.00 7800.00 7900.00 8000.00 8100.00 8200.00 8300.00 8352.11 8400.00 8429.43 8476.15 8500.00 8600.00 8700.00 8800.00 8900.00 9000.00 9049.25 Incl Azim TVD Sys TVD N/S E/W deg deg ft ft ft ft 39.30 239.99 3935.73 3879.63 -1163.37 -1977.32 39.30 239.99 4013.12 3957.02 -1195.05 -2032.16 39.30 239.99 4090.50 4034.40 -1226.73 -2087.01 39.30 239.99 4096.00 4039.90 -1228.98 -2090.91 39.30 239.99 4167.89 4111.79 -1258.40 -2141.86 39.30 239.99 4201.00 4144.90 -1271.96 -2165.33 39.30 239.99 4245.27 4189.17 -1290.08 -2196.70 39.30 239.99 4322.65 4266.55 -1321.76 -2251.55 39.30 239.99 4400.04 4343.94 -1353.44 -2306.40 39.30 239.99 4477.42 4421.32 -1385.12 -2361.24 39.30 239.99 4554.81 4498.71 -1416.80 -2416.09 39.30 239.99 4632.19 4576.09 -1448.48 -2470.94 39.30 239.99 4709.57 4653.47 -1480.16 -2525.78 39.30 239.99 4786.96 4730.86 -1511.84 -2580.63 39.30 239.99 4859.69 4803.59 -1541.61 -2632.18 39.29 239.66 4864.34 4808.24 -1543.52 -2635.47 39.19 234.13 4941.82 4885.72 -1578.04 -2688.41 39.36 228.60 5019.26 4963.16 -1617.54 -2737.81 39.78 223.15 5096.36 5040.26 -1661.86 -2783.49 40.46 217.82 5172.86 5116.76 -1710.85 -2825.28 41.37 212.66 5248.45 5192.35 -1764.32 -2863.02 42.50 207.70 5322.85 5266.75 -1822.07 -2896.56 43.84 202.97 5395.80 5339.70 -1883.89 -2925.79 45.37 198.48 5467.01 5410.91 -1949.54 -2950.60 47.06 194.24 5536.22 5480.12 -2018.79 -2970.89 48.90 190.23 5603.18 5547.08 -2091.36 -2986.58 50.86 186.44 5667.63 5611.53 -2167.00 -2997.63 52.95 182.87 5729.33 5673.23 -2245.42 -3003.98 55.14 179.49 5788.06 5731.96 -2326.32 -3005.62 57.41 176.29 5843.59 5787.49 -2409.41 -3002.53 57.43 176.27 5844.00 5787.90 -2410.06 -3002.49 59.76 173.26 5895.71 5839.61 -2494.38 -2994.73 62.18 170.36 5944.24 5888.14 -2580.90 -2982.25 64.66 167.60 5988.98 5932.88 -2668.66 -2965.14 67.18 164.94 6029.79 5973.69 -2757.33 -2943.46 69.75 162.39 6066.49 6010.39 -2846.57 -2917.28 72.36 159.91 6098.96 6042.86 -2936.06 -2886.71 74.99 157.51 6127.07 6070.97 -3025.46 -2851.87 77.65 155.17 6150.72 6094.62 -3114.44 -2812.87 80.33 152.87 6169.82 6113.72 -3202.66 -2769.87 83.02 150.61 6184.30 6128.20 -3289.80 -2723.03 84.43 149.45 6190.00 6133.90 -3334.67 -2697.16 85.72 148.38 6194.11 6138.01 -3375.53 -2672.52 86.52 147.73 6196.10 6140.00 -3400.45 -2656.98 85.85 146.49 6199.21 6143.11 -3439.59 -2631.67 85.85 146.49 6200.93 6144.83 -3459.42 -2618.54 85.85 146.49 6208.17 6152.07 -3542.59 -2563.48 85.85 146.49 6215.41 6159.31 -3625.75 -2508.42 85.85 146.49 6222.64 6166.54 -3708.91 -2453.36 85.85 146.49 6229.88 6173.78 -3792.08 -2398.30 85.85 146.49 6237.11 6181.01 -3875.24 -2343.25 85.85 146.49 6240.68 6184.58 -3916.20 -2316.13 MapN MapE DLS VS Comme ~ ft ft deg/100ft ft 5956334.30 375926.22 0.00 1122.90 5956303.52 375870.87 0.00 1153.46 5956272.74 375815.52 0.00 1184.01 5956270.55 375811.59 0.00 1186.18 K-2 (Qannik) 5956241.96 375760.17 0.00 1214.57 5956228.78 375736.49 0.00 1227.65 K-2 Base 5956211.17 375704.82 0.00 1245.13 5956180.39 375649.47 0.00 1275.68 5956149.61 375594.12 0.00 1306.24 5956118.83 375538.77 0.00 1336.80 5956088.05 375483.42 0.00 1367.35 5956057.27 375428.07 0.00 1397.91 5956026.49 375372.72 0.00 1428.47 5955995.70 375317.38 0.00 1459.02 5955966.77 375265.35 0.00 1487.74 5955964.91 375262.03 3.50 1489.59 5955931.26 375208.54 3.50 1523.02 5955892.58 375158.51 3.50 1561.51 5955849.00 375112.12 3.50 1604.89 5955800.70 375069.55 3.50 1653.02 5955747.86 375030.95 3.50 1705.71 5955690.66 374996.47 3.50 1762.77 5955629.33 374966.25 3.50 1823.98 5955564.10 374940.38 3.50 1889.11 5955495.20 374918.97 3.50 1957.93 5955422.89 374902.10 3.50 2030.17 5955347.45 374889.83 3.50 2105.57 5955269.15 374882.20 3.50 2183.84 5955188.29 374879.25 3.50 2264.70 5955105.17 374880.99 3.50 2347.83 5955104.52 374881.02 3.50 2348.48 Albian 97 5955020.10 374887.41 3.50 2432.94 5954933.39 374898.48 3.50 2519.70 5954845.37 374914.16 3.50 2607.79 5954756.37 374934.40 3.50 2696.88 5954666.72 374959.12 3.50 2786.64 5954576.75 374988.23 3.50 2876.73 5954486.81 375021.62 3.50 2966.82 5954397.22 375059.16 3.50 3056.57 5954308.31 375100.72 3.50 3145.65 5954220.43 375146.13 3.50 3233.72 5954175.15 375171.28 3.50 3279.11 Top Nanuq (Albi i 5954133.90 375195.24 3.50 3320.46 5954108.74 375210.37 3.50 3345.69 CD4-214wp04 T 5954069.19 375235.04 3.00 3385.34 5954049.15 375247.85 0.00 3405.44 5953965.11 375301.55 0.00 3489.70 5953881.07 375355.24 0.00 3573.97 5953797.03 375408.94 0.00 3658.24 5953712.99 375462.63 0.00 3742.50 5953628.95 375516.33 0.00 3826.77 5953587.56 375542.78 0.00 3868.27 96 ORIGINAL ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 10/6/2006 Time: 15:56:09 Page: 4 Field: Colville River Unit Co-ord inate(NE) Reference: Well: Plan: CD4-214, True North Site: Alpine CD4 Vertical (TVD) Reference: Pl an CD4-21456:1 Well: Plan: C D4-2 14 Section (VS) Reference: Well (O.OON,OOOE,178 .83Azi) Wellpath: Plan: C D4-2 14wp04 Survey Calculation Method: M inimum Curvature Db 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 9100. 00 86. 58 147. 83 6244. 03 6187. 93 -3958. 75 -2288. 67 5953544 .58 375569. 54 3.00 3911. 37 9200. 00 88. 02 150. 47 6248. 74 6192. 64 -4044. 49 -2237. 46 5953458 .02 375619. 35 3.00 3998. 14 9300. 00 89. 47 153. 10 6250. 93 6194. 83 -4132. 58 -2190. 19 5953369 .19 375665. 18 3.00 4087. 16 9336. 77 90. 00 154. 06 6251. 10 6195. 00 -4165. 50 -2173. 83 5953336 .00 375681. 00 3.00 4120. 42 CD4-214wp04 T 9400. 00 91. 90 154. 05 6250. 05 6193. 95 -4222. 35 -2146. 17 5953278 .72 375707. 73 3.00 4177. 82 9459. 76 93. 69 154. 04 6247. 14 6191. 04 -4276. 02 -2120. 05 5953224 .64 375732. 97 3.00 4232. 01 9500. 00 93. 69 154. 04 6244. 55 6188. 45 -4312. 12 -2102. 47 5953188 .25 375749. 96 0.00 4268. 46 9600. 00 93. 69 154. 04 6238. 12 6182. 02 -4401. 85 -2058. 79 5953097 .84 375792. 18 0.00 4359. 05 9700. 00 93. 69 154. 04 6231. 68 6175. 58 -4491. 57 -2015. 10 5953007 .43 375834. 40 0.00 4449. 65 9800. 00 93. 69 154. 04 6225. 25 6169. 15 -4581. 29 -1971. 42 5952917 .01 375876. 61 0.00 4540. 24 9900. 00 93. 69 154. 04 6218. 81 6162. 71 -4671. 02 -1927. 74 5952826 .60 375918. 83 0.00 4630. 83 10000. 00 93. 69 154. 04 6212. 38 6156. 28 -4760. 74 -1884. 05 5952736 .19 375961. 05 0.00 4721. 43 10100. 00 93. 69 154. 04 6205. 94 6149. 84 -4850. 47 -1840. 37 5952645 .77 376003. 26 0.00 4812. 02 10113. 70 93. 69 154. 04 6205. 06 6148. 96 -4862. 76 -1834. 38 5952633 .38 376009. 05 0.00 4824. 44 10200 .00 91. 10 154. 07 6201. 45 6145. 35 -4940. 29 -1796. 67 5952555 .26 376045. 50 3,00 4902. 71 10236 .70 90. 00 154. 09 6201. 10 6145. 00 -4973. 29 -1780. 62 5952522 .00 376061. 00 3.00 4936. 04 CD4-214wp04 T 10300. 00 87. 81 154. 09 6202. 31 6146. 21 -5030. 22 -1752. 97 5952464 .64 376087. 72 3.45 4993. 51 10400. 00 84. 36 154. 09 6209. 13 6153. 03 -5119. 94 -1709. 38 5952374 .23 376129. 84 3.45 5084. 11 10469. 14 81. 97 154. 09 6217. 35 6161. 25 -5181. 69 -1679. 39 5952312 .01 376158. 83 3.45 5146. 45 10500. 00 81. 97 154. 09 6221. 66 6165. 56 -5209. 17 -1666. 04 5952284 .31 376171. 73 0.00 5174. 20 10582. 82 81. 97 154. 09 6233. 22 6177. 12 -5282. 95 -1630. 21 5952209 .97 376206. 35 0.00 5248. 69 10600 .00 82. 51 154. 09 6235. 54 6179. 44 -5298. 25 -1622. 78 5952194 .55 376213. 54 3.14 5264. 15 10700 .00 85. 65 154. 08 6245. 85 6189. 75 -5387. 71 -1579. 32 5952104 .40 376255. 54 3.14 5354. 47 10800 .00 88. 79 154. 07 6250. 69 6194. 59 -5477. 53 -1535. 66 5952013 .89 376297. 73 3.14 5445. 16 10838 .51 90. 00 154. 07 6251. 10 6195. 00 -5512. 16 -1518. 82 5951979 .00 376314. 00 3.14 5480. 12 CD4-214wp04 T 10900. 00 91. 84 154. 07 6250. 11 6194. 01 -5567. 45 -1491. 93 5951923 .28 376339. 99 3.00 5535. 95 10924. 37 92. 58 154. 07 6249. 17 6193. 07 -5589. 35 -1481. 28 5951901 .22 376350. 28 3.00 5558. 06 11000. 00 92. 58 154. 07 6245. 77 6189. 67 -5657. 30 -1448. 24 5951832 .75 376382. 21 0.00 5626. 66 11100. 00 92. 58 154. 07 6241. 28 6185. 18 -5747. 14 -1404. 55 5951742 .22 376424. 43 0.00 5717. 37 11200. 00 92. 58 154. 07 6236. 78 6180. 68 -5836. 97 -1360. 86 5951651 .69 376466. 65 0.00 5808. 08 11300 .00 92. 58 154. 07 6232. 29 6176. 19 -5926. 81 -1317. 18 5951561 .16 376508. 87 0.00 5898. 79 11400 .00 92. 58 154. 07 6227. 79 6171. 69 -6016. 65 -1273. 49 5951470 .63 376551. 09 0.00 5989. 50 11500 .00 92. 58 154. 07 6223. 30 6167. 20 -6106. 49 -1229. 80 5951380 .10 376593. 31 0.00 6080. 21 11600. 00 92. 58 154. 07 6218. 81 6162. 71 -6196. 33 -1186. 11 5951289 .57 376635. 53 0.00 6170. 92 11700. 00 92. 58 154. 07 6214. 31 6158. 21 -6286. 17 -1142. 42 5951199 .04 376677. 75 0.00 6261. 63 11800. 00 92. 58 154. 07 6209. 82 6153. 72 -6376. 01 -1098. 74 5951108 .51 376719. 97 0.00 6352. 34 11900. 00 92. 58 154. 07 6205. 32 6149. 22 -6465. 85 -1055. 05 5951017 .98 376762. 19 0.00 6443. 05 11951 .03 92. 58 154. 07 6203. 03 6146. 93 -6511. 69 -1032. 76 5950971 .78 376783. 73 0.00 6489. 34 12000 .00 91. 11 154. 07 6201. 46 6145. 36 -6555. 71 -1011. 35 5950927 .43 376804. 41 3.00 6533. 78 12036 .89 90. 00 154. 07 6201. 10 6145. 00 -6588. 89 -995. 22 5950894 .00 376820. 00 3.00 6567. 28 CD4-214wp04 T 12100. 00 88. 11 154. 07 6202. 14 6146. 04 -6645. 63 -967. 63 5950836 .82 376846. 66 3.00 6624. 57 12159. 71 86. 32 154. 07 6205. 05 6148. 95 -6699. 27 -941. 56 5950782 .77 376871. 86 3.00 6678. 72 12200. 00 86. 32 154. 07 6207. 64 6151. 54 -6735. 43 -923. 98 5950746 .33 376888. 85 0.00 6715. 24 12300. 00 86. 32 154. 07 6214. 06 6157. 96 -6825. 18 -880. 34 5950655 .90 376931. 02 0.00 6805. 85 12400 .00 86. 32 154. 07 6220. 49 6164. 39 -6914. 92 -836. 71 5950565 .46 376973. 19 0.00 6896. 47 12500 .00 86. 32 154. 07 6226. 92 6170. 82 -7004. 67 -793. 07 5950475 .02 377015. 35 0.00 6987. 09 12600 .00 86. 32 154. 07 6233. 34 6177. 24 -7094. 42 -749. 44 5950384 .58 377057. 52 0.00 7077. 71 12700 .00 86. 32 154. 07 6239. 77 6183. 67 -7184. 17 -705. 80 5950294 .15 377099. 69 0.00 7168. 32 12800 .00 86. 32 154. 07 6246. 19 6190. 09 -7273. 92 -662. 17 5950203 .71 377141. 86 0.00 7258. 94 12814. 91 86. 32 154. 07 6247. 15 6191. 05 -7287. 30 -655. 67 5950190 .23 377148. 14 0.00 7272. 45 12900. 00 88. 87 154. 07 6250. 73 6194. 63 -7363. 75 -618. 50 5950113 .18 377184. 06 3.00 7349. 64 12937. 72 90. 00 154. 07 6251. 10 6195. 00 -7397. 68 -602. 00 5950079 .00 377200. 00 3.00 7383. 90 CD4-214wp04 T 12997 .16 91. 78 154. 07 6250. 18 6194. 08 -7451. 12 -576. 02 5950025 .14 377225. 11 3.00 7437. 86 ORIGINAL ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 10/6/2006 Time: 15:56:09 Page: 5 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: C~4-214, True North Site: Alpine CD4 Vertical (TVD) Reference: Plan CD4-214 56.1 Well: Plan: CD4-214 Section (VS) Reference: Well (O.OON,O.OOE,178.83Azi) Wellpath: Plan: CD4-214wp04 Survey Calculation Method:: Minimum Curvature Db: 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 13000.00 91.78 154.07 6250.09 6193.99 -7453.67 -574.78 5950022.57 377226.31 0.00 7440.44 13100.00 91.78 154.07 6246.98 6190.88 -7543.57 -531.08 5949931.99 377268.54 0.00 7531.20 13200.00 91.78 154.07 6243.86 6187.76 -7633.46 -487.38 5949841.41 377310.77 0.00 7621.96 13300.00 91.78 154.07 6240.75 6184.65 -7723.35 -443.68 5949750.82 377353.00 0.00 7712.73 13400.00 91.78 154.07 6237.64 6181.54 -7813.24 -399.98 5949660.24 377395.23 0.00 7803.49 13500.00 91.78 154.07 6234.53 6178.43 -7903.14 -356.28 5949569.66 377437.46 0.00 7894.25 13600.00 91.78 154.07 6231.42 6175.32 -7993.03 -312.58 5949479.08 377479.70 0.00 7985.01 13700.00 91.78 154.07 6228.30 6172.20 -8082.92 -268.88 5949388.49 377521.93 0.00 8075.78 13800.00 91.78 154.07 6225.19 6169.09 -8172.81 -225.18 5949297.91 377564.16 0.00 8166.54 13900.00 91.78 154.07 6222.08 6165.98 -8262.70 -181.48 5949207.33 377606.39 0.00 8257.30 14000.00 91.78 154.07 6218.97 6162.87 -8352.60 -137.78 5949116.75 377648.62 0.00 8348.07 14100.00 91.78 154.07 6215.86 6159.76 -8442.49 -94.08 5949026.16 377690.85 0.00 8438.83 14200.00 91.78 154.07 6212.75 6156.65 -8532.38 -50.38 5948935.58 377733.08 0.00 8529.59 14300.00 91.78 154.07 6209.63 6153.53 -8622.27 -6.68 5948845.00 377775.31 0.00 8620.35 14400.00 91.78 154.07 6206.52 6150.42 -8712.17 37.02 5948754.42 377817.54 0.00 8711.12 14500.00 91.78 154.07 6203.41 6147.31 -8802.06 80.72 5948663.83 377859.78 0.00 8801.88 14600.00 91.78 154.07 6200.30 6144.20 -8891.95 124.42 5948573.25 377902.01 0.00 8892.64 14700.00 91.78 154.07 6197.19 6141.09 -8981.84 168.12 5948482.67 377944.24 0.00 8983.40 • 14734.96 91.78 154.07 6196.10 • 6140.00 -9013.27 183.40 5948451.00 377959.00 0.00 9015.14 CD4-214wp04 T Targets Map Map <~ Latitude --> <-- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft CD4-214wp04 T7 6196.10 -9013.27 183.40 5948451.00 377959.00 70 16 3.682 N 150 59 12.761 W CD4-214wp04 T1 6196.10 -3400.45 -2656.98 5954108.74 375210.37 70 16 58.880 N 151 0 35.493 W CD4-214wp04 T1 Circle 6196.10 -3400.45 -2656.98 5954108.74 375210.37 70 16 58.880 N 151 0 35.493 W -Circle (Radius: 1320) CD4-214wp04 T1 Prod Int 6196.10 -3400.45 -2656.98 5954108.74 375210.37 70 16 58.880 N 151 0 35.493 W -Rectangle (6306x2640) CD4-214wp04 T7 Circle 6196.10 -9013.27 183.40 5948451.00 377959.00 70 16 3.682 N 150 59 12.761 W -Circle (Radius: 1320) CD4-214wp04 T3 6201.10 -4973.29 -1780.62 5952522.00 376061.00 70 16 43.413 N 151 0 9.955 W CD4-214wp04 T5 6201.10 -6588.89 -995.22 5950894.00 376820.00 70 16 27.525 N 150 59 47.076 W CD4-214wp04 T4 6251.10 -5512.16 -1518.82 5951979.00 376314.00 70 16 38.114 N 151 0 2.328 W CD4-214wp04 T6 6251.10 -7397.68 -602.00 5950079.00 377200.00 70 16 19.571 N 150 59 35.625 W CD4-214wp04 T2 6251.10 -4165.50 -2173.83 5953336.00 375681.00 70 16 51.357 N 151 0 21.413 W Annotation MD TVD ft ft 400.00 400.00 KOP; 2 .5 DLS, 400' MD 700.00 699.14 Build; 3 DLS, 700' MD 1766.19 1665.43 Sail 39. 3° Inc, 1766' MD for 4128' 5893.99 4859.69 Build; 3.5 DLS, 5894' MD, 4860' TVD 8429.43 6196.10 T1, 8429' MD, 6196' TVD 9336.77 6251.10 T2 10236.70 6201.10 T3 onocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 10/6/2006 Time: 15:56:09 Page: 6 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD4-214, True North Site: Alpine CD4 Vertical (TVD) Reference: Plan CD4-214 56.1 Well: Plan: CD4-214 Section (VS) Reference: Well (O.OON,O.OOE,178. 83Azi) Wellpath: Plan: CD4-214wp04 Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 10838.51 6251.10 T4 12036.89 6201.10 T5 12937.72 6251.10 T6 14734.96 6196.10 Toe, 14734' MD, 6196' TVD Casing Points MD TVD Diameter Hole Size Name ft ft in in 2715.44 2400.00 9.625 12.250 9 5/8" 8429.43 6196.10 7.000 8.750 7" 14734.96 6196.10 6.125 6.125 6 1/8" Open Hole Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 1393.58 1356.00 Base Permafrost 0.00 0.00 2462.15 2204.00 C-40 0.00 0.00 2725.77 2408.00 C-30 0.00 0.00 3201.33 2776.00 C-20 0.00 0.00 4581.46 3844.00 K-3 0.00 0.00 4907.10 4096.00 K-2 (Qannik) 0.00 0.00 5042.79 4201.00 K-2 Base 0.00 0.00 7300.77 5844.00 Albian 97 0.00 0.00 8352.11 6190.00 Top Nanuq (Albian 96) 0.00 0.00 ORIGINAL ~ M ConocoPhillips Alaska, Inc. Anticollision Report Company: ConocoPhillips Alaska lnc. Date: 10/6/2006 Tim e: 14:29:03 Page: 1 Field: Colville River Unit Reference Site: Alpine CD4 Co-ordinate(NE) Reference: Well: Pla n: CD4-214, True NOrth Reference Well: Plan: CD4-214 Vertical (TVD) Reference: Plan CD4-244 56..1 Reference Wellpath: Plan: CD4-214wp04 'bbt Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD4-214wp04 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 36.30 to 14734.96 ft Scan Method: Trav Cylinder North Maximum Radius: 1669.87 ft Erro r Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 2715.44 2400.00 9.625 12.250 9 5/8" 8429.43 6196.10 7.000 8.750 7" 14734.96 6196.10 6.125 6.125 6 1/8" Open Hole Plan: CD4-21 4wp04 Date Composed: 9/18/2006 Version: 9 Principal: Yes Tied-to: From Well Ref. Point Summary ~_-____-______ Offset Wellpath -- ----------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Alpine CD4 CD4-208 CD4-208 V7 424.79 425.00 118.88 7.33 111.55 Pass: Major Risk Alpine CD4 CD4-208 CD4-208P61 V6 424.79 425.00 118.88 7.33 111.55 Pass: Major Risk Alpine CD4 CD4-209 CD4-209 V4 447.91 450.00 95.25 8.42 86.83 Pass: Major Risk Alpine CD4 CD4-210 CD4-210 V3 442.54 425.00 79.97 7.94 72.03 Pass: Major Risk Alpine CD4 CD4-318 CD4-318 V6 351.18 350.00 82.21 7.41 74.80 Pass: Major Risk Alpine CD4 CD4-318 CD4-318A V5 350.14 350.00 82.19 7.38 74.80 Pass: Major Risk Alpine CD4 CD4-318 CD4-318PB1 V3 351.18 350.00 82.21 7.41 74.80 Pass: Major Risk Alpine CD4 CD4-319 CD4-319 V5 300.55 300.00 102.06 6.06 96.00 Pass: Major Risk Alpine CD4 CD4-320 CD4-320 V7 299.35 300.00 119.11 5.48 113.63 Pass: Major Risk Alpine CD4 CD4-320 CD4-320PB1 V4 299.35 300.00 119.11 5.48 113.63 Pass: Major Risk Alpine CD4 Nanuq 3 Nanuq 3 V1 364.10 350.00 260.56 6.08 254.47 Pass: Major Risk Alpine CD4 Nanuq 5 Nanuq 5 V1 253.39 250.00 41.56 4.57 36.99 Pass: Major Risk Alpine CD4 Nanuq 5 Plan: CD4-212 VO Plan: 253.39 250.00 41 _56 4.59 36.97 Pass: Major Risk Alpine CD4 Plan: CD4-16 Plan: CD4-16 V1 Plan: 375.29 375.00 40.69 7.91 32.78 Pass: Major Risk Alpine CD4 Plan: CD4-203 Plan: CD4-203 V1 Plan: 423.95 425.00 220.17 8.74 211.43 Pass: Major Risk Alpine CD4 Plan: CD4-204 Plan: CD4-204 V1 Plan: 350.99 350.00 200.46 7.34 193.12 Pass: Major Risk Alpine CD4 Plan: CD4-205 Plan: CD4-205 V1 Plan: 447.66 450.00 180.40 9.25 171.14 Pass: Major Risk Alpine CD4 Plan: CD4-206 Plan: CD4-206 V4 Plan: 125.97 125.00 160.79 2.59 158.20 Pass: Major Risk Alpine CD4 Plan: CD4-207 Plan: CD4-207 V2 Plan: 448.37 450.00 140.40 9.26 131.14 Pass: Major Risk Alpine CD4 Plan: CD4-211 Plan: CD4-211wp05 VO P 424.23 425.00 60.12 8.96 51.16 Pass: Major Risk Alpine CD4 Plan: CD4-211 Prelim: CD4-211wp04 V3 36.50 35.10 59.95 No Offset Stations Alpine CD4 Plan: CD4-213 Plan: CD4-213 V1 Plan: 525.06 525.00 16.34 8.76 7.59 Pass: Major Risk Alpine CD4 Plan: CD4-215 Plan: CD4-215 V1 Plan: 326.00 325.00 20.23 6.56 13.67 Pass: Major Risk Alpine CD4 Plan: CD4-222 Plan: CD4-222 VO Plan: 325.10 325.00 160.32 6.56 153.76 Pass: Major Risk Alpine CD4 Rig: CD4-17 Plan: CD4-17 V1 Plan: 553.92 550.00 61.45 9.65 51.80 Pass: Major Risk Alpine CD4 Rig: CD4-17 Prelim: CD4-17L1 V1 36.60 36.30 59.95 No Offset Stations Alpine CD4 Rig: CD4-17 Rig: CD4-17 V11 300.29 300.00 61.31 6.26 55.05 Pass: Major Risk Alpine CD4 Rig: CD4-321 Plan: CD4-321 V2 Plan: 375.80 375.00 140.41 7.88 132.54 Pass: Major Risk Alpine CD4 Rig: CD4-321 Rig: CD4-321 V3 300.79 300.00 140.91 6.09 134.82 Pass: Major Risk Alpine Nanuq EIS Pa~lan: Nanuq 4 Prelim: Nanuq 4 Lat A 56.10 0.00 109.96 No Offset Stations Alpine Nanuq EIS Pa~lan: Nanuq 4 Prelim: Nanuq 4 Lat B 56.10 0.00 109.96 No Offset Stations Alpine Satellites Nanuk 2 Nanuk 2 VO 7804.46 6850.00 723.54 102.83 620.71 Pass: Major Risk )GRAM ^41GINAL WELL DETAB,S ~W-S +J-W Northing Eastivg Latitude f.mgiNdc Slot CI)4-214 -64.R8 -251.70 5957465.31 3779?~.00 70°l7'3?7?RN INl"39'18D98W N/A 75 50 0 0 7 'D4-206) It- 0 CD4-207) .pat) 8 CD4-215 (Plan: -~ 25 µ-'-12) -33 sIRVRY P0.; x.R N ~n~n rm o .. s a i~,~.l ervied c'IN-31 aWpM v9 ioao.oo ;nsc ea ei.Md:rn+-_;tWpu vv utwn~ltat uc<n[sc PIeR tVL2ltvpt RQ Dewm' NI nt1M~31t 56.IOfl A~¢al~ ~w..s ~rew r1iom TVB t18 B3" n00 000 lb.JO From Colour To MD 36 - 250 ~sn - - - 500 7so tooo 1250 1500 1750 2000 2250 2500 2750 3000 7500 7750 8000 4-213) Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [25tUin] -150 -175 ANTI-COLLISION SC'ITINGS COMPANY nITAI1S Inlerpnlalion MelhodMD Interval: '_5.011 l'nnouil'hilllps Alnslu; Inc. Depth Range Erom: 36.30 To: 14734 95 Pngurcermg Maximum Range: I669.R7 Reference: Plan: ('D4-214wP114 I.I:GIJJD CIH-'_O8 (CU4-'_OB), Major Risk C04-'_08 (CD4-?OBPBI), Major Risk ('D4-309 (CD4-209),MJOr Rick ('D4-210 (CD4'_IO), Major Risk ('04318 (CIYL?IBI.M jar Risk CD4-i18 (CIX31Rn), Mxjur Rick CD4318 (CD4-318PB 1), Major Risk CD4-319 (CD431 Y),Mjor Riak Plnn: C'U0.?06 (Plan: ('.D4.2f16), Major Rick ~ Plnn:('IM-'_f17 (Plan: ('IN-'_07), Mnlor kick ~ PInn:CD4-?II(Plon_('D4-_'IIwp05), Aial~~r Risk Plnn:('U4-211 (Prelim: ClN-?IIuy047, Major Risk Plnn:('.U4-'_13 (Plan: Clb-_'13), Major Risk Plan:('13l'_IS(Plan: ('IW-_'IS), Alajor Risk ~ Plnn_('.I?1-?"(Plan: C.I?1-222), Major Risk Rig_('.D4171PInn_('IN-171. Major Risk (.D4320 (CIN-3'0)Mjor Risk -- CD43'0 (CD4320PBI), Malor Risk - Nanuq 3 (Nanuq 3), Major Risk Nanuq 5 (Nanny 5), Major Risk Nenuy 5 (Plan: C04--212), Mjor Rick Plan:['D4-Ib (PI¢n: C'.IYt-16), Major Risk Plan_ CD42(13 (Plan: CD4'_03), Major Risk Plan: CIM-'_04 (Plan: C'D4-204), Major Risk Rig:C'I1417 (Prelim: ClH-1]1,11, Mjor Risk Rib:CD4-171Rig: C'D4-I7k M1Ljor Risk ~ Rig: CIX-321 (Plan: CD13211. ~4njor Risk ~ Rig: CD4321 (Rig: C'1X-321), Major Risk ~ PWn: Nanuq 4 (Pnl'an: Nanuq 41e1 A), M jot Risk ~ PI¢n:Nwug4(Prclvn: Nanuq 4181 B), Maj.~r Risk ~ Nnnuk 2 (Nnnuk 2), Major Riak ~ Plan: ('IYl-? 14`vP(14 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [75ft/in] Culculalion M~hd: Mir;irnum Curvature Enur SYSle^r: ISCWSA Senn Mvllnd: Trov Cylvder NoM Error Surface: EllipicalCasing From Colour bl To MD aming Mahod: Ru4s Basod 36 250 250 300 500 750 750 1000 1000 1250 1250 1500 1500 1730 1730 2000 2000 2250 zzso zsao r38 s« Mn IrK n~ 7vD *w-s tPJ-w nl<g TPnm vse~ Target 1 36.30 0.00 0.00 36.30 0.170 000 0.00 0.00 0.00 z 4oo.w o.oo o.a7 400.00 o.w o.oo o.oo o.oo o.w 3 700.00 7.511 ?78.31 699.14 -13.04 -14.64 2.50 2?8.31 1274 4 1766.19 39.30 ?39.99 156543 X33.97 -?6622 300 14.01 2'_643 5 5893.99 39.311 '_i9.99 4839.69 -134161 X632.18 0.00 0.00 1467.74 6 842943 86.52 1477? fi196.10 -74IX1.45 ?655.98 3.50 -9395 3345.69 CD4214wp04 T1 7 8476.13 8385 14(49 6199.21 -3439.59 36?1.67 3.00 -118.65 3385.34 8 9f749.3 85.85 145.49 6240.58 -3915.20 -2315.73 0.00 0.00 3868.?7 9 9336.77 9000 15405 6251.10 -4163.30 X173.63 3.00 61.43 41:0.4? CD4-214wp04tt 10 9459.76 93.69 154.04 6247.14 -4276.02 -21?0.05 3.00 -0.34 4232.01 ll 10113.70 93.69 15404 6205.06 -4862.7h -1834.38 000 0.00 482444 12 1023670 90.00 154.09 6201.10 -497.129 -1780.fi2 3.00 17927 4936.04 CD4214wp00 T3 13 10469.14 81.97 15409 6217.35 -518169 -1579.39 3.45 179.95 5146.45 14 10582.82 81.97 154.09 6237.22 -5282.95 -1570.21 0.00 0.00 3248.69 15 10838.51 90.00 154 07 6251.10 -5512.16 -1518 82 3.14 -0.20 5480.12 CD4214e-p04 T4 16 10929.37 92.58 IS407 6249.17 -3389.?S -148128 3.00 0.00 5558.06 17 11951.03 92.58 IS407 620303 -fi311.69 -1032.76 0.00 0.00 6489.34 18 1136.89 90.00 154 07 b?01.10 -5588.8'1 -995 22 3.00 179 89 6567.28 CD4214wp114 T3 19 12159.71 Bfi.32 15407 6?05.05 -6699.27 -941.Sfi 3.00 -180.00 6678.7'_ 20 12814.91 R6.32 154.07 fi297.15 -7287.30 -655.67 0.00 0.00 727245 21 1293) 72 9(1.00 154.07 6251.10 -7397.68 -602.00 3.00 0 03 7383.9(7 CD4214wP174 Tfi ?2 12997.16 91.78 154.07 6?SD.IB -7451.1'_ -57602 3.00 0.00 7437.86 ?i 1473496 91 78 154.07 6196.10 -901?.27 183.40 0.00 0.00 9015.14 CD4-214wp04 T7 -200 n J 0 ° o -400 ~~ ~7~ 0 ~ -600 - . , .~ 0 ~ p -000 -1000 -1200 -80 00 -60 00 -40 00 -20 00 0 20 00 4000 60 00 West(-)/ East(+) [200 0ft/in] ' ' CD4-210 CD 4-210 D4-208 CD4-2 08PB1 Nanu 5 Plan: CD4-212 ' CD 2-60 CD2-60 Nanuk 1 anuk I Ri ~: CD4-17 Prelim: CD4-17L1 t 2 o en for fut ure well Nanu 3 anu 3 Ri :CD4-3 '°~T 21 Ri :CD4-321 00 Ri :CD4-17 Ri :CD 4-17 50tT0 00 000 2 0 0 5 5000 2500 00 2500 57 500 y00 00 Nanuk 2 anuk 2 _ -- s o0 ~ ~ CD4-209 CD 4-209 Nanu 5 anu 5 ' i CD4-214w 04 04 ~ ~ O O 0 0 0 0 0 -2000 r-t .--i 0 °o -4000 ~N ~~~ -~ -~ ~/ i ! {~..+ 7 ~ ~-~ -6000 ~~ t u r. ~ p (~ -8000 -1000C -12000 ' ' CD4-210 CD 4-210 D4-208 CD4-2 08PB1 Nanu 5 Plan: CD4-212 CD2-60 CD2-60 CD4-319 CD4-319 Nanuk I anuk 1 CD4-320 CD4-320PB] Ri :CD4-17 Prelim: CD4-17L1 t 2 o en for fut ure well Nanu 3 anu 3 ~ Ri ;CD4-3 21 Ri :CD4-321 Ri :CD4-17 Ri :CD 4-17 _-- - -- - Nanuk 2 Nanuk 2 ~ CD4-318 CD4-318PB 1 --- CD4-318 CD4-318 ~ CD4-320 CD4-320 I CD4-318 CD4-318A CD4-209 CD4-209 Nanu 5 anu 5 CD4-214w 04 04 I -8000 -6000 -4000 -2000 0 West(-)/East(+) [2000ft/in] 2000 4000 6000 Closest in POOL Closest Approac h: Reference Well: CD4-214wp04 Plan Offset Well: Nanuk 2 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Min. Dist. Depth Angle TRUE Azi. TVD E(+)/W(-) (178.83°) Comments Depth An le TRUE Azi. TVD E(+)/W(-) (178.83°) Comments POOL Min Distance POOL Min Distance (995.42 ft) in POOL (995.42 ft) in POO (8429 - 14734 MD) to (8429 - 14734 MD Nanuk 2 (6134 - 6314 CD4-214wp04 Plan 995.42 8429 86.52 147.7 6139.697 5954105 375213.9 3349.304 TVDss) 7065 1.9 272.7 6154.308 5954427 374272.2 3053.056 (6134 - 6314 TVDss) osest Approac h: Reference Well: CD4 214wp04 Plan Offset Well: CD4 -209 Coords. - Coords. - ASP ASP - ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS m. Dist. Depth Angle TRUE Azi. TVD E(+)/W(-) 178.83°) Comments Depth Angle TRUE Azi. TVD E(+)/W(-) (178.83°) Comments POOL Min Distance POOL Min Distance (2884.72 ft) in POOL (2884.72 ft) in POOL (8429 - 14734 MD) to (8429 - 14734 MD) to CD4-209 (7237 - CD4-214wp04 Plan 2884.72 13886 91.78 154 6166.057 5949218 377610.3 8245.932 13215 MD) 12437 92.28 153.9 6168.296 5950432 380226.9 7042.477 (7237 - 13215 MD) Closest Approac h: Reference Well: CD4-214wp04 Plan Offset Well: CD4 -210 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Min. Dist. .: ; Depth An le TRUE Azi. TVD E(+)/W(-) (178.83°) Comments Depth Angle TRUE Azi. TVD E(+)/W(-) (178.83°) Comments POOL Min Distance POOL Min Distance (2968.19 ft) in POOL {2968.19 ft) in POOL (8429 - 14734 MD) to (8429 - 14734 MD) to CD4-210 (7468 - CD4-214wp04 Plan 2968.19 2967.ea~I 8429 86.52 147.7 6139.697 5954105 375213.9 3349.304 11710 MD) 7468 85.04 335.6 6196.921 5957032 375701.6 424.07 (7468 - 11710 MD) CD4-214wp04 POOLSummary.xls 10/6/2006 3:49 PM • ~ SHARON K. ALLSUP-DRAKE CONOCOPHILLLPS 1158 AT0 1'530 700 GST. jU l~ ~~/_ ANCHORAGE AK 99501 DarE / ss-1551/441 -,~ PAY TO THE ~~~ ~~ ~ /~ / fJ_~ (/~. ~D /~ ~ P ORDER OP l/1 i ! ~T[ (l. C~ (i ~ ~ Boa o ~ 5 ~ ~ ,p Y w g ~ DOLLARS LJ o.. ,~ JPMor anChase ~~ 9 .1 Valid Up To 5000 Dollars JPMorgan Chase Bank, N,A. Columbus, OH r ~: 0 4 4 i L 5 5 ~ L ~: 5 2 8 7 4 7 i 9 0? 9 2 7 u' L L S g ---- --- ---------- _ .~ -~ _ • • TRANSMITTAL LETTER CHECKLIST WELL NAIVTE ~'/2G! ~ ~- ZIP PTD# Z~~o ' ~`f'S~- Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-Oiv'S WHAT (OPTIONS) APPLIES ~ TEXT FOR APPROV:4L LETTER MULTI LATERAL ~ The permit is for a new wellbore segment of existing ~ well (If [ast two digits in ~ Permit No. ,API No. ~0- - ~ API number are ~ - between 60-69) I Production should continue to be reported as a function of the original API number stated above. PILOT HOLE U accordance with 20 AAC 25.005(f), all records, data and logs i acquired for the pilot hole must be clearly differentiated in both wel[ name ( PH) and API number (~0- - -) from records, data and logs I acquired for well SPACING ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 2~.0~5. Approval to perforate and produce ' in'eLct is contingent upon issuance of a conservation order approving a spacing 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 no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~ Non-Conventional Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed W e!1 I for (name of well) until after (Com a~nv Name) has designed and I Implemented a water well testing program to provide baseline data ~ on water quality and quantity. LCompanv Name) must contact the ~ Commission to obtain advance approval of such water well testing Rev: I; 25/06 C:\jodyltransmittal checklist • • ^^ ~ ~ ~ ~ ~ : ~ o , y N : : ~ O~ a, ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ fl: ~ N ~ ~ ~ ~ N c ~ .-. ' N. N. O ~ O, N c, p No' a: c. ~ ° o. ~ v O. ~ ~ . ~. .N ~, o. , N O' ~ CI ~ ~ ~ ~ p ~ ~ ~ ~ ~ p ~ N• ~ d ~ ~ f6, N, , t O ~ ~ y: ~ ~, ~ ~ ~ ~ O: ~ W, ~ W ~ O. Or ~, f6. O ~ C~ O N ~ Q ~ ~~ ~ ~ ~ ~ ~~ ~ ~ d ~ p• U. W. ~ ~~ ~ ~ a1 N' >' V' Q. ~ ~ c~ C' ~ 0 O ~ 7, ~ C, a ~~ N. ~ C ~ 3~ O ~ ~ ~ G ~ ~ ~ 6~ ( ~ d ~: O ~~ c' o' ~~ ~~ v ~ ~ ~~ ~ ~ ~ , - ~~ ~ ~~ . • ~ ~ t~ ~ ~~ , N• o o ~ ~ Q ~ c O , O v 4 ~ , .3 ~ v N ~ Z G . , ~ o 4 0, ~ , c' , o ~, m. ~ fl, ~ a ~ C ~ C' D: N, y. ~ ~ ~ ~ C' ~ N. ~ ~ T ~~ s ~ ~~ ~, , ~ d ~ N~ ~ , , ~: ~ Z ~ ~ Z o. ~ ~ U ° , ~ °~ °~ o, Q. rn y of ° ~ ~~ ~ _, m t, Z ~ o. ~ ~ o. o, ~, ~, ° ~ ~~ in, ~ ~ a~, o ~ ~ o c. ~m~ ui, °~ Z ti~ r ~, ~ _~ ~~ 3, i ~ >~ i ~~ ~ Q, ,~ Y, N~ ~ ~ ~, O, d ~ M, Q' Q pjf ~~ N~ ~ Q' 00' ~~ N. N, N' ~, ~ ~ ~ ~~ t6. 7, ~ G p '' ' ~, Z, p, ~ ~N, ~ ~ N. d: N, N' ~, W ~ m. co ~ ~ co, co ~ • ' ~ o a~ ~ ~ m. °r p~ '~ ~ 4 V ~ a. ~, °' O. . ,~~ , -~ J, ~ ~ ~ ~ O . c , > ~ a, ~ v~ ~ O c ~ N, ~ E ~ O a a O c y; ~ ~ ~ ~, V: Z, Z. 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To improve the readability of the Well History file and to simplify finding information, informa/ion of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar 28 14:44:59 2007 Reel Header Service name ......... ....LISTPE Date ................. ....07/03/28 Origin ............... ....STS Reel Name ............ ....UNKNOWN Continuation Number.. ....01 Previous Reel Name... ....UNKNOWN Comments ............. ....STS LIS Writing Library Tape Header Service name ......... ....LISTPE Date ................. ....07/03/28 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 Nanuq MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW0004720106 LOGGING ENGINEER: D. RICHARDSO OPERATOR WITNESS: D. BURLEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • Scientific Technical Services Scientific Technical Services CD4-214 501032053700 ConocoPhillips Alaska Inc. Sperry Drilling Services 28-MAR-07 MWD RUN 3 MW0004720106 E. QUAM D. MICKEY 24 11N 4E 2332 322 56.10 19.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2677.0 2ND STRING 6.125 7.000 8698.0 3RD STRING PRODUCTION STRING 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 i~ S~ ~ PRESENTED. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), GEOPILOT ROTARY-STEERABLE BHA (GP) AND PRESSURE WHILE DRILLING (PWD). BIMODAL ACOUSTIC TOOL (BAT) WAS ALSO INCLUDED ON MWD RUN 3. THESE BAT DATA ARE PRESENTED ELSEWHERE. 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 1-3 REPRESENT WELL CD4-214 WITH API#: 50-103-20537-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15072'MD/6279'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 (SEDP). File Header Service name ............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .07/03/28 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 RPD 2645.0 15022.0 FET 2645.0 15022.0 RPS 2645.0 15022.0 RPM 2645.0 15022.0 RPX 2645.0 15022.0 GR 2652.0 15014.5 ROP 2687.5 15072.0 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 2645.0 8706.0 MWD 3 8706.0 15072.0 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2645 15072 8858.5 24855 2645 15072 RPD MWD OHMM 0.59 2000 21.8876 24755 2645 15022 RPM MWD OHMM 0.45 2000 16.4135 24755 2645 15022 RPS MWD OHMM 0.51 2000 14.2904 24755 2645 15022 RPX MWD OHMM 0.64 1775.52 16.7019 24755 2645 15022 FET MWD HOUR 0.13 69.14 1.0788 24755 2645 15022 GR MWD API 42.55 196.96 97.6925 24726 2652 15014.5 ROP MWD FT/H 0.79 484.99 129.718 24770 2687.5 15072 First Reading For Entire File..........2645 Last Reading For Entire File...........15072 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/28 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.......07/03/28 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 for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ~~ FET 2645.0 8664.0 RPX 2645.0 8664.0 RPS 2645.0 8664.0 RPM 2645.0 8664.0 RPD 2645.0 8664.0 GR 2652.0 8671.0 ROP 2687.5 8706.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 02-NOV-06 Insite 72.13 Memory 8706.0 2687.0 8706.0 36.3 86.4 TOOL NUMBER 124724 157645 8.750 2677.0 Polymer 9.70 35.0 10.1 600 1.0 2.990 68.0 1.580 134.6 3.450 68.0 2.250 68.0 S Data Format Specification Re cord 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 Si ze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 ROP MWD020 FT/H 4 1 68 Name Service Unit Min Max DEPT FT 2645 8706 RPD MWD020 OHMM 0.59 2000 RPM MWD020 OHMM 0.45 1743.45 RPS MWD020 OHMM 0.51 1775.77 RPX MWD020 OHMM 0.64 1775.52 FET MWD020 HOUR 0.13 51.17 GR MWD020 API 51.43 196.96 ROP MWD020 FT/H 8.2 484.99 First Reading For En tire File..........2645 Last Reading For Ent ire File...........8706 File Trailer Service name ..... ........STSLIB.002 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......07/03/28 Maximum Physical Record..65535 File Type ........ ........LO Next File Name... ........STSLIB.003 Physical EOF File Header ~J 24 7 28 8 First Last Mean Nsam Reading Reading 5675.5 12123 2645 8706 16.9614 12039 2645 8664 7.28305 12039 2645 8664 6.44328 12039 2645 8664 6.17873 12039 2645 8664 0.766442 12039 2645 8664 108.926 12039 2652 8671 185.264 12038 2687.5 8706 Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/28 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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 RPX 8664.5 15022.0 RPD 8664.5 15022.0 RPM 8664.5 15022.0 FET 8664.5 15022.0 RPS 8664.5 15022.0 GR 8671.5 15014.5 ROP 8706.5 15072.0 LOG HEADER DATA DATE LOGGED: 09-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15072.0 TOP LOG INTERVAL (FT) 8706.0 BOTTOM LOG INTERVAL (FT) 15072.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.2 MAXIMUM ANGLE: 93.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 8698.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S) 58.0 MUD PH: .0 MUD CHLORIDES (PPM): 88000 FLUID LOSS (C3) 1.2 RESISTIVITY (OHMM) AT TEMPERA TURE (DEGF) MUD AT MEASURED TEMPERATUR E (MT) .000 .0 MUD AT MAX CIRCULATING TER MPERATURE: .000 159.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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-ty pe...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8664.5 15072 11868.3 12816 8664.5 15072 RPD MWD030 OHMM 1.38 2000 26.5516 12716 8664.5 15022 RPM MWD030 OHMM 7.45 2000 25.0578 12716 8664.5 15022 RPS MWD030 OHMM 4.13 2000 21.7198 12716 8664.5 15022 RPX MWD030 OHMM 2.44 13 85.52 26.6648 12716 8664.5 15022 FET MWD030 HOUR 0.46 69.14 1.37452 12716 8664.5 15022 GR MWD030 API 42.55 142.8 87.0332 12687 8671.5 15014.5 ROP MWD030 FT/H 0.79 146 77.2005 12732 8706.5 15072 First Reading For Entire File..........8664.5 Last Reading For Entire File...........15072 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/28 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/03/28 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/03/28 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File