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200-043
1 Guhl, Meredith D (OGC) From:Loepp, Victoria T (OGC) Sent:Friday, April 2, 2021 10:45 AM To:'Smith, Travis T' Subject:SSSV Not required for CRU CD1-34 (PTD# 200-043) Follow Up Flag:Follow up Flag Status:Flagged Travis, Well CRU CD1‐34 is not required to be equipped with a SSSV according to 20 AAC 25.265(d)(2). Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Thursday, April 1, 2021 4:47 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: [EXTERNAL]SSSV Exemption for CRU CD1‐34 (PTD# 200‐043) Hello Victoria— The graphic shown below was prepared by our WNS Environmental Coordinator. These measurements indicate CD1‐34 to be close, but outside, the 660’ radius from the Sakoonang Channel. Based on this, and your comments below, should we proceed with CD1‐34 falling outside the requirements of 20 AAC 25.265(d)? Thanks, Travis 2 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, April 1, 2021 9:38 AM To: Smith, Travis T <Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]SSSV Exemption for CRU CD1‐34 (PTD# 200‐043) Travis, Is CD1‐34 within 660 ft of the following: (A) a permanent dwelling intended for human occupancy, including a billeting camp or private residence; NO (B) an occupied commercial building, excluding a structure located within an existing oil or gas field; NO (C) a road accessible to the public; NO (D) an operating railway; NO (E) a government maintained airport runway; NO (F) a coast line measured at mean high water; NO (G) a public recreational facility; or NO (H) navigable waters as defined by the United States Army Corps of Engineers in 33 C.F.R. Part 329.4 with boundaries defined in 33 C.F.R. 329.11 MAYBE Regarding the Sakoonang Channel, it appears that CD1‐34 is more than 660 ft from the water’s edge. However, the map is not adequate to conclusively determine. Please confirm the distance from Mean High Water Line and show the 660ft radius on the map. CPAI may have installed a SSSV on their own volition and not to comply with 20 AAC 25.265(d). If so, no waiver is needed. From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, March 23, 2021 3:09 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> 3 Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: SSSV Exemption for CRU CD1‐34 (PTD# 200‐043) Hello Victoria— Please see my responses below in blue. Let me know if you need any more information. Thanks very much, Travis From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, March 22, 2021 5:31 PM To: Smith, Travis T <Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]SSSV Exemption for CRU CD1‐34 (PTD# 200‐043) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Travis, 1. Please provide map/info on producers and injectors in the area. Why is this the preferred method? See the attached pad map of the CD1 area. Reducing the pressure in this portion of the Alpine reservoir is important to de‐risking drilling of our upcoming disposal well, WD‐03. Flowing CD1‐34 at the maximum possible rate has been identified as a simple and safe way to do this, and one we believe will be less‐impactful to our operations. 2. Why is a SSSV required in this well? Proximity to facilities, water? This well on the CD1 drillsite requires a SSSV because of its proximity to the Alpine camp and waterways. 3. Did the initial completion have a SSSV? What’s the history? The completion of the well includes a BAL‐O nipple at 1,710’ MD with a control and balance line run to surface. This allowed use of a WRDP style SSSV. In May 2010, the control and balance lines became plugged off and thus unusable. Efforts to unplug them were unsuccessful, and a K‐valve had to be used instead. 4. A waiver would be required to allow operation as you are requesting. Agreed—we realize this is a well that would normally require a SSSV. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended 4 recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday, March 10, 2021 11:33 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: SSSV Exemption for CRU CD1‐34 (PTD# 200‐043) Victoria— ConocoPhillips is preparing to drill a new Class 1 disposal well in early 2022, well WD‐03. As part of our preparation for this drilling, we are attempting to reduce Alpine reservoir pressure in the vicinity of the proposed wellpath. The preferred method for this has been identified as producing well CD1‐34 at maximum rate. Currently CD1‐34 produces at approximately 1900 barrels of liquid per day at 98% watercut (the well is not economic to produce, it is being kept online only to reduce reservoir pressure). Our modeling suggests the well needs to flow at a minimum of 2500 barrels of liquid per day until February 2022 to achieve the target pressure of 11 ppg equivalent mud weight. CD1‐34 utilizes a K‐valve for its SSSV. This valve is set with a dome pressure of 440 psi, necessitating the well to be choked to 500 psi wellhead pressure. Reducing the dome pressure of the K‐valve will prevent it from passing the required closure tests. In order to achieve the target 2500 barrels of liquid per day, we are asking for a temporary exemption for CD1‐34 to flow until February 2022 with no SSSV in place. The well will be naturally flowing during this time, with the IA fluid‐packed and the gas lift mandrels dummy’d off. The close proximity to the ACF control room means Alpine Operations staff are typically available to respond to this well location quickly if needed. Thank you very much for your consideration on this matter. Please let me know if you have any questions or need more information. Travis Smith WNS Intervention & Integrity Engineer 907‐659‐4014 Travis.T.Smith@conocophillips.com C CJ - 34- . PTI) e54-3 Regg, James B (DOA) From: Regg,James B (DOA) Sent: Wednesday, August 10, 2016 6:36 PM @eye 3(1,I ita To: Weingarth, Stefan Cc: Kanady, Randall B; NSK Prod Engr Specialist; ALP DS Lead and Simops Coord;ALP Ops Maint Supt;Alexa, Misty J;Johnstone, Sam; Freedman, Kerry C; Mustafin,Ilnur;ALP Prod Engr Subject: RE: CD1-34 Waiver for Operation Thank you. As discussed your request to delay the test of the K-valve is approved. Sent from my Samsung Galaxy smartphone. tailS) JAS 1 12017 Sa Original message From: "Weingarth, Stefan" <Stefan.G.Weingarth@conocophillips.com> Date: 08/10/2016 5:24 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov> Cc: "Kanady, Randall B" <Randall.B.Kanady@conocophillips.com>, NSK Prod Engr Specialist <n1139( conocophillips.com>, ALP DS Lead and Simops Coord<alp1450@conocophillips.com>, ALP Ops Maint Supt <alp1167 c,,r conocophillips.com>, "Alexa, Misty J" <Misty.J.Alexa(a�conocophillips.com>, "Johnstone, Sam" <Sam.Johnstone a,conocophillips.com>, "Freedman, Kerry C" <kerry.c.freedman`,conocophillips.com>, "Mustafin, Ilnur" <Ilnur.Mustafin@conocophillips.com>, ALP Prod Engr<a1p2087@conocophillips.corn> Subject: CD 1-34 Waiver for Operation Jim, CD1-34 is an Alpine C-Sand producer.The well has operated with a K-valve deployed downhole as a subsurface safety valve. On 7/9/16, we pulled the K-valve and deployed downhole gauges to gather data used for a new K-valve design. The well was brought online thereafter until being shut in on 7/18/16 for the Alpine Central Facility shutdown.After reviewing the production data, a new K-valve was fabricated.After deploying the new K-valve on 8/6/16,the well was brought online. While the well was shut in for^'3 weeks. the well's bottomhole pressure built up higherthan anticipated, allowing the well to produce liquids at higher than anticipated rates.The new K-valve was designed for the well's operation under normal flowing conditions, and we've had difficulty function testing the valve while the well is flushing at higher rates.After retrieving the current K-valve downhole,we will deploy an alternative K-valve within the next few days. We would like to request a waiver allowing for CD1-34 to_produce until a passing function test of the K-valve can be achieved.The state witnessed testing scheduled for CD1 safety valve system testing is tentatively planned for August 20`h. We will target achieving a passing function test by then. CD1-34 will be monitored appropriately. Since the CD1 drillsite is part of the Alpine Central Facility, the drillsite will be manned 24 hours a day.Additionally, CD1-34's surface safety valve system is fully functional, and has passed routine testing. For now, we will coordinate with Operations to continue producing the well until advised otherwise. Please let me know if you have any questions. I can be contacted after normal working hours at the Alpine on-call PE cell: 907-943-0103. 1 • S Thank you for taking the time to review. Stefan Weingarth ConocoPhillips Alaska WNS Production Engineering ATO 1760; 700 G Street-Anchorage,AK 99501 Office: 907-265-6038 I Cell: 907-438-6187 2 STATE OF ALASKA • , ALr.—,(A OIL AND GAS CONSERVATION COM,....>SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed SuspendPerforate r r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Scale Inhibitor Treatment For 2.Operator Name. 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 200-043 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20333-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25559 CRU CD1-34 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s). none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 11190 feet Plugs(measured) none true vertical 7087 feet Junk(measured) none Effective Depth measured 11190 feet Packer(measured) 7949 true vertical 7087 feet (true vertical) 6966 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 114 114 SURFACE 2397 9 625 2434 2362 PRODUCTION 8376 7 8410 7106 REC LAVED p,` C a.ill�: �� ' 1G��� Perforation depth: Measured depth: open hole completion 5CAtAKE� JUL 2 72616 True Vertical Depth: open hole .AVGCC Tubing(size,grade,MD,and TVD) 4.5, L-80, 8037 MD,7009 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER S-3 PACKER @ 7949 MD and 6966 TVD 3.812"K-valve set in BAL-O NIPPLE @ 1710 MD and 1698 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8410'-11190' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 755 1352 1764 1260 289 Subsequent to operation 696 1278 1858 1270 324 14.Attachments(required per 20 MC 25.070,25.071,&25 283) 15.Well Class after work: Daily Report of Well Operations p Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r- SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt none Contact Kerry Freedman C,265-6579 Email Kerry.C.Freedman(cr�conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature Phone:265-6579 Date 7,Li y Lo i le•A A AT -IA k e--.A4.----__ r- k-r` S/311 S t/A� RBDM AUG - 2 2015 Form 10-404 Revised 5/2015 Submit Original Only CD1-34 Scale Inhibition Treatment 6/27/15 Aqueous Scale Inhibitor Squeeze Job pumped 6/27/15 from 07:30 to 15:20 hrs. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA-493/1200/850 - ACF pumped 30 bbls seawater tubing flush from seawater injection system at 2 bpm,TBG/IA/OA -555/1000/780 - LRS pumped 10.1 bbls WAW5206 at 0.2 bpm while ACF pumped 91 bbls seawater at 2 bpm, TBG/IA/OA- 112/1000/780 - LRS pumped 15.2 bbls SCW4004 scale inhibitor at 0.45 bpm while ACF pumped 86 bbls seawater at 3 bpm,TBG/IA/OA—342/1000/780 - ACF pumped 1101 bbls seawater overflush at 3 bpm,TBG/IA/OA-265/1000/780 Interval treated: 8,410'—11,190' i } WNS PROD CDI-34 Conoc Ph1II1� 1° Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UW Field Name Wellbore Status ncl('I MD(ftKB) Act Btm(ftKB) r-cm.w.r alam 501032033300 ALPINE PROD 92.02 9,320.01 8,420.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CD1-34,7/2320155:59:38 PM SSSV:WRDP Last WO: 43.21 5/4/2000 Verbal schematic(ectua9 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:Packer Name Correction lehallf 7/23/2015 Casing Strings Casing Description IOD(in) !ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 34.0 114.0 114.0 62.58 H-40 WELDED HANGER;32.3 Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread _d SURFACE 95/8 8.921 36.6 2,433.5 2,361.5 36.00 J-55 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread i "rsst°" 4 PRODUCTION 7 6.276 34.3 8,410.3 7,106.3 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,f OPEN HOLE 61/8 8,410.3 11,189.9 7,086.9 1Tubing Strings Tubing Description String Ma...ID lin) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection • -= TUBING 41/2 3.958 32.3 8,036.6 7,0086. 12.60 L-80 IBTM CONDUCTOR,34.0-114.0-A Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(') Item Des Com (In) 32.3 32.3 0.00 HANGER FMC TUBING HANGER 4.500 1,709.9 1,697.8 13.24 NIPPLE BAL-O NIPPLE 3.812' NIPPLE;1,709.9-, 7,907.1 6,942.4 54.65 NIPPLE HES'X'NIPPLE 3.813 VALVE;1709.9 7,949.3 6,965.6 58.21 PACKER BAKER S-3 PACKER 3.875 id 8,024.3 7,002.9 62.09 NIPPLE HES'XN'NIPPLE 3.725 ® 8,035.3 7,008.0 62.63 WLEG Wireline Entry Guide 4.500 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (') Des Com Run Date ID(in) 1,709.9 1,697.8 13.25 VALVE 3.812"MODIFIED K-VALVE w/DB LOCK(SN:K317) 10/17/2014 2.125 (36"BETWEEN 2 PACKING STACKS OAL 77") DOME CHARGE SET @ 281 PSI @ 60 DEGREES Stimulations&Treatments Min Top Max Btm SURFACE;36.6-2.433.5 Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 8,410.3 11,189.9 7,106.3. 7,086.9 OPEN HOLE 3/3/2008 PUMP C SAND HYDRAULIC FRACTURE FRAC TREATMENT.PUMPED 166,358#OF 16/30 BADGER SAND,PLACING 161,715#INTO FORMATION. 8,410.3 11,189.9 7,106.3 7,086.9 OPEN HOLE 4/5/2014 PUMP C SAND PER DESIGN PLACING 202,160# GAS LIFT,3945.4 FRAC OF 16/20 PROPPANT IN OPEN HOLE COMPLETION Mandrel Inserts St ati N Top(ND) Valve Latch Port Size TRO Run i•. Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1' 3,645.4 3,394.1 CAMCO KBG-2 1 GAS LIFT 'DMY BK 0.000 0.0 3/1/2008 2 5,767.4 5,188.1 CAMCO KBG-2 1 GAS LIFT DMY BK 0000 0.0 3/1/2008 GAS LIFT,67674 3 7,828.4 6,893.2 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 4/7/2014 Notes:General&Safety End Date Annotation __ 6/12/2009 NOTE.VIEW SCHEMATIC w/Alaska Schematic9.0 1/13/2014 NOTE:Mandrel Orientation-1)7:00 2)11:00 3)10;30 GAS LIFT,7,8284 c: NIPPLE;7,907.1 PACKER;7,949.3 NIPPLE,8,024.4 i'.. WLEG;8,0353 PRODUCTION;34.3-8,410.3 OPEN HOLE FRAC;8410.3 , " OPEN HOLE FRAC;8410.3 • OPEN HOLE;8410.3-11,189.9 Ima~_.Project Well History File Cover,._.~ge XHVZE This page identifies those items that were not scanned during the initial production scanning' phase. They are available in the Original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. C,~ O (~- (~ ~,..~ Well History File Identifier Organizing,,o,,,:iaTwo-S,~ed Ill II[[[[lll]l [[[]] RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLey, ROBIN ylNCENT SHERYL MARIA WINDY Project Proofing BY: BEVER[tY"~ '~/INCENT SHERYL MARIA WINDY Scanning Preparation x 30 = OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other BY: BEVERL~VINCENT SHERYL MARIA WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: Stage 2 aY~ (SCANNING 18 COMPLETE AT THIS POINT UNLESS SPECIAl. ATTENTION IS REQUIRED ON AN INDIVIDUAl. PAGE BASIS DUE TO QUAUTY, GRAY$CALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ;;~ YES NO IF NO IN STAGE 1j PAGE(S) DISCREPANCIES WERE FOUND: YES _~ NO ReScanned (individual page l.~pecial attel~tionJ ,.~ca~mit~g ~:ompter. ed) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/10102Rev3NOTScanned.wpd OF 1"4. r 60��1%%%�� THE STATE .� Lit a 21_Ct ‘al f ry � #1, _ 333 West Seventh Avenue > > ; Anchorage Alaska 99501-3572 C�C.� i.1tN«R SEAN I ARNF,LL g� r� 'eft Main: 907 279 1433 LAs" JAL 61 Q Fax: 907.276.7542 Mike Hazen Wells Engineer ao ® _. ©1x..3 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-34 Sundry Number: 314-138 Dear Mr. Hazen: 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 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, Daniel T. Seamount, Jr. _yt Commissioner DATED this/ 9 day of March, 2014. Encl. • STATE OF ALASKA RECEIVED R AL A OIL AND GAS CONSERVATION COMM, .ON APPLICATION FOR SUNDRY APPROVALS MAR 0 7 2014 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Fool f Repair well r Change ADGCnCtir Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r. Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r, 200-043 f 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 50-103-20333-00• 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r CD1-34- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25559 i Colville River Field/Alpine 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): 11190 • 7087 . 11190' - 7087' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 114' 114' SURFACE 2397 9.625 2434' 2362' PRODUCTION 8376 7 8410' 7106' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): open hole completion I open hole completion 4.5 L-80 8037 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER 2-3 PACKER MD=7949 TVD=6966• NIPPLE-BAL-O NIPPLE MD=1710 TVD=1698 , 12.Attachments: Description Summary of Proposal r- 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r. Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/25/2014 Oil r • Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r- WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Hazen @ 265-3230 Email: Micheal.C.HazenOconocoohillips.com Printed Name Mike Title: Wells Engineer Signature Phone:265-3032 Date 6.6441.(L` Commission Use Only Sundry Number: �j Conditions of approval: Notify Commission so that a representative may witness 3\Lk— \� 6 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r SP RBDMS 4.MAY 11 21114 Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: /a — U rl '/E-7;p:3/1APPROVED BY 3�4�/a Approved by: COMMISSIONER THE COMMISSION Date. ved I I I d or 1 months trom the date of approval. Form 10-403(Revised 10/2012) A� •?/ 3171 q Submit Form and Attachment in Duplicate ' i'- 3/!i 114 At 14'y 3SC-� , 31‘AtiVt-i . • • , q 00'' oz a U © c ¢ 33 »»s' a x o € • cao • m m c° g 2 9_ o o>> > >> o y ao y5 •2 3 - 3 F • ' v S 5vacnao= ¢¢ ¢ ¢ ¢ oe� � ZZ0 W cd � � • U ' Od ' � .. f d •• •• •• •• . . w . . . . . . . y • . . . . 7 w � o� O —� V • CO 1 • • ` L U • • 7 N o •' LO 15 / i • •: U W q .. .,.! .••• 0, f ••••aJ� '•� M • •:t• �'•y • :•;+� .,: r Ute. . . ._ - - -. . ,�:9•r,...:.:_::.......,,.�•• :rte Q �+ • • • • ch • • •� V...•••:••• +�. • • •• M • • U o • • • : Uo . • •' • r U• CV �: U': N • U• • a o N •v A. v N ',. n1 N • U.• M :o o Q N a • U rn U= W • . N //f Z U+ / Q• m N/.:.......:.......... • • •• L M • L, /'' • NN • CD1-34 Sundry Application Alpine well CD1-34 was drilled and completed in May 2000 as horizontal producer targeting the Alpine C-sand formation. It is constructed with 6/18" open hole completion from 8410' to 11189' MD and 4-1/2" 12.6# L-80 tubing from surface to 9718'MD. The well was previously fracture stimulated in March 2008 placing 160k#of 16/20 CarboLite proppant with 7-PPA on formation. The well will be re-fracture-stimulated placing approximately 205k# 16/20 CarboLite in nine 0-9-PPA stages at 30-bpm. Proposed Procedure: Schlumberger Pumping Services: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 6 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 2115 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 148 bbl breakdown stage (linear gel) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 30 BPM as quick as possible, pressure permitting. Slowly increase annulus (IA) pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 30 bpm with a maximum expected treating pressure of 2555 psi. Stage 1 • 370 bbl Schlumberger fluid Pad • 90 bbl Schlumberger fluid w/ 1 PPA • 110 bbl Schlumberger fluid w/2 PPA • 120 bbl Schlumberger fluid w/3 PPA • 120 bbl Schlumberger fluid w/4 PPA • 130 bbl Schlumberger fluid w/ 5 PPA • 130 bbl Schlumberger fluid w/6 PPA • 140 bbl Schlumberger fluid w/ 7 PPA • 150 bbl Schlumberger fluid w/ 8 PPA • 160 bbl Schlumberger fluid w/ 9 PPA • Flush with 131 bbl of linear fluid and freeze protect • Total Sand: Approx. 205,228-lb of 16/20 CarboLite Proppant 12. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). Cement Evaluation of CD1-34 and wells within 1/4 mile of CD1-34 CD1-34: 7" Casing two stage cement job was pumped on 4/29/2000 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.2 ppg mud. The plugs were bumped on both stages to 1000 psi and 2100 psi respectively, floats held. Full returns were observed during the job. CD1-38: 7" Casing two stage cement job was pumped on 2/2/2000. The cement pumped was 15.8 ppg Class G cement, displaced by 10 ppg mud. The plug was not bumped and float held. Full returns were observed during the job. Casing was tested to 3500 psi for 30 min. CD1-39: 7" Casing cement job was pumped on 9/8/1999. The cement pumped was 15.8 ppg cement, displaced by 9.6 ppg mud. The plug was not bumped and float held. Approximately 30' of cement was drilled from casing followed by a pressure test on casing at 3500 psi for 30 minutes. This data indicates a competent cement job. CD1-40: 7" Casing cement job was pumped on 5/30/1999 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.2 ppg brine. The plug was bumped at 3500 psi and held for 5 minutes. The float held. CD1-42: 7" Casing two stage cement job was pumped on 2/23/2010 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 10 ppg mud. The plugs bumped on both stages and floats held. Full returns were observed during the job. Held 3500 psi on casing for 5 minutes. CD1-43: 7" Casing two stage cement job was pumped on 8/23/2000. The cement pumped was 15.8 ppg Class G cement, displaced by 10 ppg mud. The plug was not bumped and float held. Full returns were observed during the job. Casing was tested to 3500 psi for 30 min. CD1-44: 7" Casing cement job was pumped on 5/14/2000 as designed, indicating competent cement operations. Cement was displaced at 8 bpm using mud, plugs were bumped and floats held. A pressure test was performed to 5000 psi and held for 10 minutes. CD1-45: 7" Casing two stage cement job was pumped on 11/1/1999. The cement pumped was 15.8 ppg Class G cement, displaced by 10 ppg mud. The plug was not bumped and float held. Full returns were observed during the job. Casing was tested to 3500 psi for 30 min. Full returns were observed during the job. CD1-49: 9-5/8" Casing two stage cement job was pumped on 2/23/2010 as designed, indicating competent cement operations. The cement pumped was 12.2 ppg lead Class G with CemNet and 15.8 ppg tail Class G cement, displaced by 10 ppg mud. The plugs were bumped on both stages and floats held. Full returns were observed during the job. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a % mile radius or any other nearby well. Stimulation Surface Rig-Up 0 Bleed I Tattle �� 1 Tale Tank 00110��� m � tg g • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95%of max 0011001 T2 >DI treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and 1011.tiO4 set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. N g N t 1110. E c 110011 ri '3" ��1- ' `ca s a I t vrul dune Pop-Off Tart ar E 5,4 O' Pop-Off Tank D - Pump Truck Olry d c off. A, �� 1-:3 C N N 1 d Fra Pump Frac Pump Frac Pump r.al 92N —Da- Frac Pump Frac Pump Nal a-- --1 rr J Frac Pump • Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) FRAC IRON fl 1 /CONNECTKN 1 -- „...--f 1 i . 1 • 1� 1 REMOTE OPERATED ' MASTER VALVE a:: MANUAL OPERATED :04'W: C ..d,..1.,, MASTER VALVE m• •• •••. asommumo® a& f ,®i1 I N.%) „,,,,57® / Stinger \ r/ Stinger \ I 1 1 IIII 11:„..„...„.....„,..„ MANDREL VENT ".01f—VALVE isA (. OPEN riI.-5_ 1 i /r1 Illi Mit MI Liii/ /inti 11111: — .\ \I FLOW TEE AND ; `f 4���[• VENT VALVE WELLHEAD .'' . rl111fl.Jrll VALVES %7 INV A. OPEN 4 -- ; 4 :. 1111 . WEU_HEAD - , CLOSED VES ' I MI 1 \Y/. R.,1.#• 1 OUAD PACKOFF .: al\ tiP ASSEMBLY IN 1':• It PLACE IN TUBING OW Ht • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 '/2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm TD 0 2 U L u_ vl c? 0 0 Q- ( Q o 0 0 0 0 0 0 0 0 0 CD o t o_ 0 0 0 0 0 0 0 0 0 0 0 n U o c\i ri v L.6 cd ti C) ai o 0 0 0 co 0 0 0 0 0 N N N N N N N N N 1n CO CO CO CO CD CO CO CO CO 2 O O O N N O O O O "0 J J .J J J J J J . 1-- C 0 0 0 0 0 0 0 0 0 IC . .fl 0 Q d) C6 C6 (0 (9 (6 (6 t0 (4 o a 0 0 0 0 0 0 0 0 0 CD a` I- N -- d Li CD c IS c p) o 0 o O 0 0 0 0 o 0 0 a) Cl) N N N N N N N N N N N _ C.) n - CO o N _0 N 0 N Q.. x— —0 N RCO) %/a/'L N / (V N a 73 E( 9 0 o 0 o 0 0 o 0 CD LU N V J N O (/) u >° CDV CO CO RS r r N .0 O O 0 N (13 d0 ci) HH H. I- H H H H Lo Lo Lo co Ln co co co H E co N co N N N U) H II ft Z LL LL LL LL LL LL LL LL LL LL Lc) I I I UM= 13 3 LL > O N E (13 - o 0 0 0 0 0 0 0 0 0 o CO d ry Jo O M co co co co co co co co co co I— a) -0 CL < < < < < < < ate. L L O J ci) cu a_ EL 0_ a_ 0_ EL CL EL EL () N O N a E 0- o 0 0 0 0 0 000LL .� z T-- N CD t Ln CO N- N CO s- > U • _ 'W 4) '4– 0 O O O O O O a) ° E 2 0 4– � � At "- � > O -- w O , -m;, in to Tr O v- On T . Cm "0 C6 N. N. M O (/)_>, c . O "0 .L_ •V O '> = W 41/ _ � O (6 N Q = L /� E O ca _ 0 (/) o ci) . .O co U c Q O +J = O _ Q +- = CEO 11 tyl) mi. C3 H- J — 0 'Fp 03 0> a) o po.. -1-. -i- 4-, -- 0G)=2CD CD 4-1 = 0. • • Ca3 (i5E °0 a) a) L_ ' _c 1_ 1_ (..) 4-, c:51 Om - 92 '52 }, �' � a) � � o LL LL W >i asL O o Ca c -O = Ws Q -0 0) L co O co 2 •+-+ •++ O O > E O 'c .> co ca N _ _ awQ .. O L -4 c O O — — as u) -0 O D •— o o O O O O ._ • I , 1,..S PROD CD1-34 `ConocoPhillips . Well Attributes Max Angle&MD TD Alaska,Inc:. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) CanmPhillips 501032033300 ALPINE PROD 92.02 9,320.01 8,420.0 ••• �' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date CD1-34,1/18/20148:31:36 AM SSSV:WRDP Last WO: 43.21 5/4/2000 Vertical schematic(actual) , Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RE-SET K-VALVE hipshkf 1/9/2014 -- - t��e��,�{[r Casing Strings ai In Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Grade Top Thread CONDUCTOR 16 15.062 34.0 114.0 114.0 62.58 H-40 WELDED HANGER;32.3 _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I... 1 SURFACE 9 5/8 8.921 36.6 2,433.5 2,361.5 36.00 J-55 BTC-MOD LCasing Description PRODUCTION OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 7 6.276 34.3 8,410.3 7,106.3 2600 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread OPEN HOLE 6 1/8 8,410.3 11,189.9 7,086.9 Ilil Tubing Strings Tubing Description String Ma... ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection -- ' 5k TUBING 41/2 3.9581 32.3 8,036.61 7,008.61 12.60 L-80 IIBTM CONDUCTOR;34.0-114.0 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 32.3 32.3 0.00 HANGER FMC TUBING HANGER 4.500 1,709.9 1,697.8 13.24 NIPPLE BAL-O NIPPLE 3.812 7,907.1 6,942.4 54.65 NIPPLE HES'X'NIPPLE 3.813 VALVE;1,709.911 NIPPLE;1,709.9 ii 7,949.3 6,965.6 58.21 PACKER BAKER 2-3 PACKER 3.875 tit k 8,024.3 7,002.9 62.09 NIPPLE HES'XN'NIPPLE 3.725 s 8,035.3 7,008.0 62.63 WLEG Wireline Entry Guide 4.500 Other In Hole(Wireline retrievable plugs,valves, pumps,fish,etc.) Top(ND) Top Incl I Top(ftKB) (ftKB) F) 1, Des Corn Run Date ID(in) 709.9 1,697.8 13.25 VALVE 3.812"K-VALVE Type w/DB LOCK(SN:K11A)(OAL 41" 1/9/2014 2.125 w/LOCK)DOME CHARGE SET @ 281 PSI @ 60 DEGREES Stimulations&Treatments Min Top ' Max Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Date Com SURFACE;36.6-2,433.5 '' 8,410.3 11,189.9 7,106.3 7,086.9 OPEN 3/3/2008 PUMP C SAND HYDRAULIC FRACTURE TREATMENT. HOLE PUMPED 166,3584 OF 16/30 BADGER SAND, FRAC PLACING 161,7154 INTO FORMATION. Mandrel Inserts GAS LIFT:3,645.4 St ati C on Top(TVD) Valve Latch Port Size TRO Run o No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 3,645.4 3,394.1 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/1/2008 2 5,767.4 5,188.1 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/1/2008 3 7,828.4 6,893.2 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 5/3/2010 Notes:General&Safety 111 End Date _ Annotation GAS LIFT;5,767.4 6/12/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1/13/2014 'NOTE: Mandrel Orientation-1)7:00 2)11:00 3)10;30 i GAS LIFT;7.828.4 1121 NIPPLE;7.907.1 PACKER;7,949.3 m. Y NIPPLE,8,024.4 11 WLEG;8,035.3 I t PRODUCTION;34.3-8,410.3 It•• a OPEN HOLE FRAC;8,410.3 •• •., I OPEN HOLE;8,410.3-11,189.9 4 1 STATE OF ALASKA • ALA OIL AND GAS CONSERVATION CO 1I SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 1 Repair w ell g Plug Perforations r Perforate 1 . Other F. Scale Inhibtion '''' Treatment r'' Alter Casing r Pull Tubing j Stimulate - Frac it Waiver E Time Extension r Change Approved Program L'" Operat. Shutdow n I- Stimulate - Other - Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development j� . Exploratory f _ 200 -043 . 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic E Service 50 103 - 20333 - 00 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25559 CD1 -34 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 11190 ' feet Plugs (measured) none true vertical 7087 feet Junk (measured) none Effective Depth measured 11190 feet Packer (measured) 7949 true vertical 7087 feet (true vertical) 6966 1 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 114 114 SURFACE 2397 9.625 2433 2362 PRODUCTION 8376 7 8410 7110 ,--' w'; ', ' :" 4 Li NI 0 r. 20 ,I .,' + " 4:7„,‘ 1 � Perforation depth: Measured depth: open hole completion ' ' True Vertical Depth: open hole completion Tubing (size, grade, MD, and TVD) 4.5, L -80, 8037 MD, 7009 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 2 -3 PACKER @ 7949 MD and 6966 TVD SSSV - BAL -O SSSV @ 1710 MD and 1698 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8410' 11190' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 274 2078 1063 -- 279 Subsequent to operation 244 1965 1035 — 322 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development (47 • Service E Stratigraphic F 16. Well Status after work: Oil r.; . Gas I WDSPL F Daily Report of Well Operations )0X GSTOR I WINJ fl WAG fl GINJ r SUSP (- SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Michael Dammeyer a 265 - 6548 Email Michael. Dammeyerecop.com Printed Name Michael Dammeyer Title Senior Production Engineer Signature a Phone: 265 -6548 Date s — /3o /I • 3 ,/t r RBDMS JUN - 5 20 /, /I¢ /�' Jt3 . ' ifr�y Form 10 -404 Revised 10/2012 Submit Original Only s WNS CD1 -34 ConocoPhillips l$ Well Attributes Max Angle & MD TD Alaska, Inc Weilbore APIIUWI Field Name Well Status !nei (°) MD (ftKB) Act Btm (ftKB) Coeont ps 501032033300 ALPINE PROD 92.02 9,320.01 11,189.9 Comment H2S (ppm) Date Annotation End Date KB-Ord (ft) Rig Release Date Well conno - cD1 -3a 2r3l2011 9 - n 21 AM SSSV: WRDP Last WO: 43.21 5/4/2000 Schematic -Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag. Rev Reason: FORMAT UPDATE Imosbor 2/3 /2011 Casing Strings Y *a. Casing Description String 0.. String ID Top (ftKB) Set Depth (f... Set Depth (TVD) . String Wt... String String Top Thrd CONDUCTOR 16 15.062 34.0 114.0 114.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 32 a• I SURFACE 95/8 8.697 36.6 2,433.5 2,361.5 36.00 J - 55 BTC - MOD • / Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 34.3 8,410.3 7,109.9 26.00 L BTCM M.: Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd / ) OPEN HOLE 6 1/8 6.125 8,409.9 11,189.9 7,086.9 IP Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (5... Set Depth (TVD) _. String Wt... String ... String Top Thrd ■9I1L a TUBING 41/2 3.958 32.3 8036.6 7,008.6 12.60 L -80 IBTM Completion Details CONDUCTOR, Top Depth 34-114 (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) j j 32.3 32.3 -0.36 HANGER FMC TUBING HANGER 4.500 1,709.9 1,697.5 12.73 SAFETY VLV BAL -O SSSV 3.812 i_i SAFETY VLV, 7,907.1 6,942.3 54.65 NIPPLE HES 'X' NIPPLE 3.813 1,710 vALVE. 7710 7,949,3 6,965.4 58.44 PACKER BAKER 2 -3 PACKER 3.875 8,024.4 7,002.8 62.09 NIPPLE HES 'XN' NIPPLE 3.725 8,035.4 7,008.0 62.63 WLEG Wireline Entry Guide 4.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth 1= — (TVD) Top Inc! Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 1,709.9 1,697.6 12.73 VALVE 3.812" K -VALVE (S /N. K54A) SET ON DB -LOCK 5/19/2010 2.125 Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) . (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment SURFACE, 8 ,410.0 11,189.9 7 ,109.9 7,086.9 OPEN HOLE 3/3/2008 PUMP C SAND HYDRAULIC FRACTURE 37 - 2,433 FRAC TREATMENT. PUMPED 166,358# OF 16/30 ' - - -- BADGER SAND, PLACING 161,715# INTO FORMATION Notes: General & Safety GAS LIFT, End Date Annotation 3 • 6 /12/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 1 GAS LIFT, 5,767 al GAS LIFT, _- 7.028 NIPPLE, 7,907 L_ _ r i' PACKER, 7,949 - -- w NIPPLE, 8,024 Mandrel Details WLEG, 8,035 Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (!n) sery Type Type (W (psi) Run Date Com... 1 3,645.4 3,394.2 32,94 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/1/2008 2 5,767.4 5,188.3 32.27 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/1/2008 3 7,828.4 6,893.1 48.23 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 5/3/2010 PRODUCTION, I o ... , I 34.8,410 OPEN HOLE OPEN PEN HOLE, OLE, 8,410-11,190 TD, 77,790 • • CD1 -34 Scale Inhibition Treatment: 5/17/2013 Initial pressure TBG -400; Facility pumped 50 bbls SW preflush; LRS pumped 4.3 bbls WAW5206 (181 gal) at 0.45 bpm while facility pumped 37 bbls SW at 4 bpm, 400; LRS pumped 43 bbls SCW4004 (1806 gal) at 0.65 bpm while facility pumped 245 bbls of SW at 4 bpm, 400; facility pumped 1658 bbls of SW over- displacement. Final pressures: 400. Intervals treated: 8410' — 11190' STATE OF ALASKA • ALASKA •AND GAS CONSERVATION COMMISSO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell f Rug Perforations r Stimulate r SG Other r Alter Casing r Pull Tubing E Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development IV Exploratory r " 200 - 043 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 - 103 - 20333 - ^ 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25559 N CD1 -34 9. Field /Pool(s): Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 11190 feet Plugs (measured) None true vertical 7087 feet Junk (measured) None Effective Depth measured 11190 feet Packer (measured) 7949 true vertical 7087 feet (true vertucal) 6966 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 SURFACE 2397 9.625 2433 2362 PRODUCTION 8376 7 8410 7110 , ::,, 's Mt AUG (5 2U1'I RE( ,..: . f : ;! Perforation depth: Measured depth: open hole completion 8410' 11190' True Vertical Depth: 7110' - 7087' (V ; . - `,3; r c:,611 ° _. I11ISSIOn !:is,1) g Tubing (size, grade, MD, and TVD) 4.5, L - 80, 8035 MD, 7008 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 2 -3 PACKER @ 7949 MD and 6966 TVD SSSV - BAL-0 SSSV @ 1710 MD and 1698 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8410'- 11190' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 528 2286 1136 -- 253 Subsequent to operation 397 2003 1261 -- 252 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r✓ Service r Stratigraphic r 15. Well Status after work: Oil f , Gas r"" WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact David Neville , 265 -6402 Printed Name avid Neville Title WNS Production Engineer Signature . ,. // � tI '' Phone: 265 -6402 Date ('� `,/ . /6�1n0 �"� /�j��c d ( *yy REIDNIS AUG 0 4 2611+4? Form 10-404 Revised 10/2010 Submit Original Only • • CD1 -34 7/15/2011: Initial pressure TBG /IA - 917/1288; facility pumped 50 bbls SW preflush; LRS pumped 1.9 bbls WAW5206 (83 gal) at 0.4 bpm and facility pumped 18 bbls SW, 675/1288; LRS pumped 19.6 bbls SCW4004 (825 gal) at 0.65 bpm and facility pumped 111 bbls SW, 500/1335; facility pumped 1077 bbls SW over - displacement • CD1 -34 WNS �'. ,..-_,,,..;1,,,-,,..., , 4 C oP�l = * a Wp11 Attributes - Max Angle & MD TD /4 Wellbore APUUWI Field Name Well Status Ind () MD (ftKB) Act Btm (ftKB) [ „,,, 501032033300 ALPINE PROD _ 92.02 i 9,320.01 11 189.9 `'' Covent - -- H2S (ppm) Data Annotation End Date KB (ft) Rig Release Date SSSV: WRDP Last WO: 43.21 5/4/2000 „ . Annofation Depth (ftKB) End Date Annotation Last Mod ... End Dab LL Last Tag: Rev Reason: FORMAT UPDATE 1 Imosbor 2/3/2011 Casing Strings b,.. Description String 0... String ID _. Top ftKB Set Depth t Set Depth ND String Wt... String 'String Top Thrd 9 t Pion 9 9 P l ) P (��� P ( ) ... 9 9�� P � Casing `F CONDUCTOR 16 15.062 34.0 114.0 114.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (RKB) Sat Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 32 SURFACE 95/8 8.697 36.6 2,433.5 2,361.5 36.00 J - 55 BTC - MOD i :. / Casing Description String 0... String ID ... Top (ftKB) Sal Depth (1.. Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 34.3 8,410.3 7,109 9 26.00 L - 80 BTCM '..;- Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd . OPEN HOLE 6 1/8 6.125 8,409.9 11,189.9 7086 9 1 / Tubing Strings s 9 P 9 Tubing Descn tion St 0... String ID... Top (ftKB) Set Depth (f.. Set Depth (TVD) _. String Wt... String String Top Thrd III TUBING 41/2 1 3 -958 32.3 8,036.6 7,0086 1260 L80 IBTM Com pletion Details CONDUCTOR, Top Depth 34-114 (TVD) (ND) Top Intl Nomi... Top (ftKB) ( B) (°) Item Description Comment ID (in) 32.3 32.3 -0.36 HANGER FMC TUBING HANGER 4.500 1,709.9 1,697.5 12 73 SAFETY VLV BAL -O SSSV 3.812 SAFETY1/I LV, ' _ 7,907.1 6,942.3 54.65 NIPPLE HES'X' NIPPLE 3.813 VALVE, 1,710 7,949.3 6,965.4 58.44 PACKER BAKER 2 -3 PACKER 3.875 8,0244' 7,002.8 62.09 NIPPLE HES 'XN' NIPPLE 3.725 8 035 4 7 008.0 62 63e e trleVable Wireline Entry Guide 4 - 500 �• Other In Hoe ire In plugs, valves pumps, fish, etc.) Top Depth (TVD) Top Ind I Top 11108), ( (°) Description Comment Run Date ID (in) [a ) F l' 1 /09 91 1 697 6 12.73 VALVE 3.812' K VALVE (S, N K54A) SET ON DB LOCK 5/19/2010 2 125 j ' I 1' Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (ND) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Data Comment SURFACE,_ - -- - --- 37-24.33 8,410.0 11,189.9 7,109.9 7,086.9 OPEN HOLE 3/3/2008 PUMP C SAND HYDRAULIC FRACTURE FRAC TREATMENT. PUMPED 166,358# OF 16/30 BADGER SAND, PLACING 161,715# INTO FORMATION. Notes: General & Safety End Date Annotation 3.645 6/12/2009 NOTE: VIEW SCI IEMATIC w /Alaska Schematic9 0 GAS ',T1 5 ,76 GAS LIFT, __.__ 7,828 I : . - NIPPLE, 7,907 —' 1 1 is PACKER, 7,949— -___ NIPPLE,8,024 .. 1'. Details WLEG,8,035 —... 1 Mandrel D ' Top Depth Top Port _ (TVD) Incl OD Valve Latch S¢e TRO Run Stn Top (ftKB) (908) (") Make Model (in) Sery Type Type (in) (Pail Run Date Com... 1 3,645.4 3,394.2 32.94 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/1/2008 I 2 5,767.4 5,188.3 32.27 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/1/2008 3 7,828.4 6,893.1 48.23 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 5/3/2010 PRODUCTION, 34-8,410 OPEN HOLE FRAC, 8,410 I OPEN110LE," 6,TD,11,190 TD, 11,190 • Regg, James B (DOA) • Page 1 of 1 From: Regg, James B (DOA)��' I Sent: Tuesday, October 26, 2010 11:52 AM To: 'Schneider, Tim S.'��' d Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA); Aubert, Winton G (DOA); Schwartz, Guy L (DOA); Foerster, Catherine P (DOA) Subject: RE: Wireless SSSV installation We are excited about the opportunities represented by this technology, but you've got some work to do to convince the Commission that it is ready for reliable operation. We know very little about the wireless SSSV technology. Some questions to get us started evaluating a request include: - What are details of the technology, including downhole valve and surface controls? (include functional diagrams) - How does it interface with existing SVS? - What testing and performance data are you relying on? Have tests involved repetitive closing; slam tests; leakage evaluation? - Where has wireless SSSV technology been tested (or deployed) in the field, and for how long? Results? - Are equipment proven fail -safe and reliable - downhole valve and communications components? - Limitations of the technology (pressure, depth, distance for communication, temperature, fluids, wellbore integrity, etc.) - Setting depth of valve dependencies (permafrost; casing design; ?) - Is this technology applicable to any well or are there certain candidate wells being targeted by CPAI? - Has a safety assessment of technology been completed? - Function and performance testing in the field once installed? There may be other information CPAI relied on to convince yourselves this is an acceptable technology for shutting in a well downhole - encourage you to make that available to the Commission as well. We are certainly open to discussing this proposal in a meeting, but we require physical information as support for any decision the Commmission might make. And the preference is to receive that info and have the opportunity to review it before a meeting is scheduled - that would make the meeting more productive for CPAI and the Commission. Jim Regg AOGCC % NOV �� Q 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Schneider, Tim S. [mailto: Tim. S.Schneider @conocophillips.com] Sent: Tuesday, October 26, 2010 9:55 AM To: Regg, James B (DOA) Subject: Wireless SSSV installation Nib zoo _CY4 _�, Mr. Regg, CPAI would like to propose a wireless SSSV installation in an Alpine well; CD1 -34, that currently has a K- valve installed for SSSV control. We have done some preliminary work and would like to know if any additional information is required other than a 10 -403 defining our intention. Thanks Tim 5. Schneider Subsurface Development Staff Production Engineer WN5- Alpine 2 Phone: 907 - 265 -6859 9 Fax: 907 - 265 -1515 0 Mobile: 907 - 632 -8136 O Email: tim .s.schneider@conocophillips.com 10/26/2010 STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS•N REPORT OF SUNDRY WELL OPERATIONS t. operations Pertormed: Abandon Repair w ell Rug Pf'rforations ("" Stimulate °" Other ~' K valve Alter Casin Pull Tubin Pierforate New Pbol Waiver installation g ~ 9 ~~ Time Extension "'"' Change Approved Program Operat. Shutdown [~` Perforate ~" Re-enter Suspended Well ~"""` 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~' Exploratory ~"' 200-043 3. Address: Stratigraphic ~' Service ..API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20333-00 7. Property Designation;. 8. Well Name and Number: ADL 25559 CD1-34 9. Field/Pool(s): ~ Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 11190 feet Plugs (measured) None true vertical 7087 feet Junk (measured) NOne Effective Depth measured 11190 feet Packer (measured) 7949 true vertical 7087 feet (true vertucal) 6966 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 114 114 SURFACE 2397 9.625 2433 2361 PRODUCTION 8376 7 8410 7110 Perforation depth: Measured depth: open hole completion ~,hl n ~~~~\ /C ~ „ " ( t y G True Vertical Depth: '` ~ ... ~ ~fUN 2 4 2010 Tubing (size, grade, MD, and TVD) 4.5, L-80, 8037 MD, 7008 TVD Alaska Oil & r~ Gens. Cammissi~~ Packers &SSSV (type, MD, and TVD) PACKER -BAKER 2-3 PACKER @ 7949 M,D and 6966 TVD Antarerage SSSV - BAL-O SSSV @ 1710 MD and 1698 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 635 2097 2173 -- 208 Subsequent to operation 553 1392 1662 -- 304 13. Attachments 4~4. Well Class after proposed work: Copies of Logs and Surveys run E~loratory Development ~ Service . Well Status after work: Oil Gas "-" WDSPL °'" Daily Report of Well Operations GSTOR ("'" WAG ("" GASINJ WINJ ~ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 310-144 contact David Neville Cad 265-6402 Printed Name David Neville Title WNS Production Engineer ~7 1/~ Signature /~}G~ ~f~i~~~ / ,, Phone: 265-6402 Date /~~~? /L.~1(/ ~iBDMS .SUN 2 ~ 1~ °7-7-cv e l//~ Form 10-404 Revised 7/2009 - d Submit Original Only Cr~nrxci~iltips t a1..i. lr'y4;. ~ WNS - CD1-34 - __- Well Attribute s ""- ---- - Max An le & MD ~ 1 TD __ Wellbore API/UWI Fieltl Name ~ Well Status 'Incl (°) MD (ftKB) iACt Btrn (ftKB) I 501032033300 (ALPINE (PROD 92.02 9,320.01 11,189.9 'Comment M2S (ppm) (Date Annotation 'Entl Date KB-Grd (k) Rig Release Date SSSV~ WRDP l Last WO' 5/4/2000 '.Annotation Depth (ftKB) '~, End Date Annotation Last MOd .../End Date Last Tags ~'~ (Rev Reason: RESET K-VALVE __ Imosbor I 5/20/2010 IC n Strin s _._. ~ -- - --- (Casing Description String 0.. - . String ID ... Top (ftKB) __ Set Depth ((... S t Depth (ND) Ttrin Wl... ,String .. a 9 . String Top Thrd ICONDDGIGR 16 iS 062 34.0 714.0 114.0 62.58 ~ H-40 WELDED Casing Description String 0.. . String lD... Top (ftKB) Set Depth(f__ Set Depth(ND)..-.String W[... String.. . String TOp Thrd SURFACE 9518 8.697 36.6 2,433.5 2,361.5 36.00 J-65 BTC-MOD Casing Description String 0.. . (String ID ._ Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 34.3 8,410.3 7,109.9 26.00 L-80 __ BTCM Casing Description String 0... i.String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String.. . String Top Thrd (OPEN HOLE 61/8 ! fi_125 8,409.9 11,189.9 7,086.9 i uoing uescnpuon IUBING awing u... awing iu . ~ 4112 ~ 3.958 . top Imo/ 32.3 aer vepu~ li... 8,036.6 oe~ v~p~~~ t~.~./ ... ~~~~~y ...... ,,,....y .. ... 7,008.6 1260 L-80 ....y ~..e ~..... IBTM - i Completion Det _ ails _.-. -_ T p Depth 1 (NDJ ~ T Incl P 0 N i... ttK61 Top (ftKB) ( (°) Item Descnptr on Comment ID (n) 323 32.3 , I 0.36 CHANGER FMC TUBING HANGER 4 500 Min TOp Max Bim Inc Top Depth Top (ND) Incl ~p (ftKB(( (ftKB) (°) 3,6454'i 3,394.2 32.9 5,7674 5,188.3 32.2 7,828.4 6,893.1 48.2'. ~srnption Comment Run Date JE 3.812' K-VALVE (S/N K54A) SET ON DB LOCK 5/[9/2010 _ - ____. IS 3ottom Depth ii (TVD) ~i (ftKB) Type Date Comment 7,086.9 OPEN HOLE 3/3f2008 PUMP C SAND HYDRAULIC FRACTURE FRAC TREATMENT- PUMPED 166,358# OF 16/30 BADGER SAND, PLACING 161,715# INTO ,FORMATION. "s. __ Annotation NEMATIC w/Alaska SchemaYic9.0 Port OD Valve Latch Stre TRO Run I (in) Serv TYPe Typ (in) (psQ Run Date 1Com... 1GAS LIFT DMY BK ~0.000~ 003/112008 ' ~ • CD1-34 Well Events Summary DATE SUMMARY 4/25/10 SET 3.812" WRDP (S/N: HSS-197) @ 1709' RKB, OBTAIN GOOD CLOSUR EST. COMPLETE. 4/26/10 PULLED 3.812" WRDP f/ 1709' RKB, BRUSHED BAL-O NIP @ SAME, UNABLE TO FREE UP OBSTRUCTED CONTROL & BALANCE LINE. JOB SUSPENDED. 5/2/10 SET CAT SV @ 8024' RKB. PULLED OV FROM 7828' RKB. LOADED IA AND TBG WITH 290 BBL HOT SW AND 95 BBL HOT DSL. CONTROL LINES CONTINUE PLUGGED. IN PROGRESS. 5/3/10 SET 1/4" OV @ 7828' RKB. PULLED CAT SV FROM 8024' RKB. PRESSURED CONTROL /BALANCE LINES TO 7500 PSI AS DIRECTED. CONTROL LINES CONTINUE PLUGGED. JOB SUSPENDED. 5/8/10 SET DUAL PANEX GAUGES ON 3.812" DB LOCK W/ FLOW THROUGH SUB @ 1709' RKB. IN PROGRESS. 5/10/10 PULLED PANEX GAUGES FROM DB NIPPLE @ 1709' RKB. IN PROGRESS. 5/15/10 TUBING OPEN 3.85 TO 1709' RKB, SET 3.812 DB LOCK & K-VALVE @ 1709' RKB (S/N: K49A). GOOD CLOSURE TEST. COMPLETE 5/18/10 ATTEMPTED PULL K-VALVE @ 1710' RKB. PRESSURE SURGE PROPELLED TOOLSTRING UPHOLE. PARTED WIRE, LEAVING TOOLS @ 1530' SLM. RECOVERED TOOLSTRING (PRS SHEARED) & APPARENTLY ALL WIRE. K-VALVE STILL @ 1710' RKB. IN PROGRESS. 5/19/10 PULLED K-VALVE @ 1710' RKB (S/N: K49A). DRIFTED TBG TO 1750' SLM WITH 4-1/2" BLB & 3.77" GAUGE RING; RECOVERED 8" WIRE. DRIFTED TBG WITH 4-1/2" BLB & 4 PRONG WIRE GRAB TO 2000' SLM; TBG CLEAR. SET 3.812 K-VALVE @ 1710' RKB (S/N: K54A); GOOD CLOSURE TEST. COMPLETE. Page 1 of 2 n U CJ Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, May 18, 2010 10:32 AM To: 'NSK Prod Engr Specialist' Cc: Regg, James B (DOA) Subject: RE: CD1-34 (PTD 200-043) Request for flow period extension Bob, Go ahead and install the K valve you have set up. If this one fails however, a 7 day extension will not be granted and you will be required to shut the well in until you can justify why you think this particular well is a viable candidate for a K valve. This particular well (CD1-34) may not lend itself to the narrow operating pressure/ temperature window that the dome charge requires for reliable operation. In this case a RWO may be the ultimate answer to fix the control line problem and allow re-installment of the surface controlled SSSV. Thanks, ,.~a~~ ~;J Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent: Tuesday, May 18, 2010 9:52 AM To: Schwartz, Guy L (DOA) Cc: ALP DS Lead and Simops Coord Subject: FW: CD1-34 (PTD 200-043) Request for flow period extension Guy, Per our previous discussion, ConocoPhillips requests an additional extension on the test period of CD1-34 (PTD 200-043). A K-valve design was set and passed the closure test on 05/15/10. The well was allowed to flow for 2 days at which point a follow up test was performed. During this test the K-valve failed to close. A new K-valve design has been scheduled to be installed today with a follow up test to be performed after the well has stabilized. ConocoPhillips requests an additional 7 day extension in the event that this new K-valve design also fails. S:.b Christc;os4n / Darrell Humphrey fir.. t~:r ~„~ [A~ UI GQtG1 I \tApUl 1.1 ~\ Y~1 GG , . ..,u~,_..~...._,:y,~._v..:.~ _,~,..~,a,.:..,. t Muir-c F4f1?1 ;^.~~_'L,~F. ?;rCl/_~G - - ..._ ,. l.J -.. , 1 -r ~ -r. ~ ...... ... :..:„n ~r,v,r~rd ' ~ r~ r ,?~r,.; ;s -- _, `: `- ~.,...-r. ,: ~a34.:.. ,. ,> r,.-,t,fi, it ~.a.. c,-~nr:ar .'~~,,; i ina ~iiiui~ u~u~ vv~nuu ... ~ nv~a ~.~ui ~uwu uuuvn. ~ u ~~.v~avv un.r ~. i~~un u~ a..~iv ~i~..u.~~. nvu~y .r~.~.v~a ra ~u y ., From: ALP DS Lead and Simops Coord Sent: Tuesday, May 18, 2010 8:55 AM To: NSK Prod Engr Specialist 5/18/2010 i • Subject: FNV: CD1-34 (PTD 200-043) Request for flow period extension From: Neville, David ] Sent: Monday, May 10, 2010 5:29 AM To: ALP DS Lead and Simops Coord Subject: FNV: CDi-34 (PTD 200-043) Request for flow period extension Page 2 of 2 From: Schwartz, Guy L (DOA) [mailto:guyschwartz@alaska.gov] Sent: Thursday, May 06, 2010 11:18 AM To: NSK Problem Well Supv Cc: Schneider, Tim S.; Barreda, Brian B; Neville, David J; ALP DS Lead and Simops Coord; Regg, James B (DOA) Subject: RE: CD1-34 (PTD 200-043) Request for flow period extension Brent, An extension of 7 days for stabilizing CD1-34 is approved. If addition time is required notify the commission again for justification and approval. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Thursday, May 06, 2010 11:00 AM To: Schwartz, Guy L (DOA) Cc: Schneider, Tim S.; Barreda, Brian B; Neville, David J; ALP DS Lead and Simops Coord; NSK Problem Well Supv Subject: CD1-34 (PTD 200-043) Request for flow period extension Guy, As per our conversation, ConocoPhillips requests an extension on the test period of CD1-34. Currently the well is online and stabilization is trying to be achieved in order to gather information for a K-valve design. During the current test period the production is still fluctuating and has not become stable yet. The current shut-in date far the well will be May 10th. ConocoPhillips requests an additional 14 days to allow stabilization for proper settings of the K-valve in order to optimize production. Please let me know if the additional time is acceptable. Thank you. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 5/18/2010 . • • ~~Q~C~ 0~ a~Q~~Q /.E..o.~«~,~a~w Tim Schneider WNS Production Engineer ConocoPhillips Alaska, Inc. ~. r'~ ~~~~; ~.r.%+ ~ ~ ~`~~,; P.O. Box 100360 Anchorage, AK 99510 ©O _, ~ („{, 1' Re: Colville River Field, Alpine Oil Pool, CD1-34 Sundry Number: 310-144 Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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 May, 2010. Encl. tr ~j STATE OF ALASIG4 ~ 0 ~~~ '" ALASI~ AND GAS CONSERVATION COMMISSI ~ it ~ } ~qY O 4 2~10'~ ~ ~0 APPLICATION FOR SUNDRY APPROVA ~ 20 AAC 25.280 ,,,,,v„ ruff Q_ r~ (~~, i~'(1tn -- - 1. Type of Request: Abandon ]~"` Rug for Redrill Perforate New Pool ~ Repair well ~IQ~71~G1 VII M ~/M~ ~' Change A~gram ~° Suspend ~ Rug Perforations Perforate ~"` Pull Tubing ~`"" Time Extension r Operational Shutdow n Re-enter Susp. Well ~ Stimulate `°, ARer casing Other: K valve installation 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ - Exploratory j""" 200-043 . 3. Address: Stratgraphic J ` Service '"` 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20333-00 - 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 changes: Spacing Exception Required? Y2S )~ No ~`, CD1-34 9. Property Designation: 10. Field/Pool(s): ADL 25559 - Colville River Field /Alpine 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): 11190 7087 11190' 7087' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0 16 114' 114' SURFACE 2397 9.625 2433' 2361' PRODUCTION 8376 7 8410' 7110' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole completion 4.5 L-80 8037 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER -BAKER 2-3 PACKER MD= 7949 TVD= 6966 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: 5/10/2010 Oil ~- Gas WDSPL Suspended ) 16. Verbal Approval: Date: WINJ " GINJ ~" WAG Abandoned Commission Representative: GSTOR ~ SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider @ 265-6859 Printed Name Tim Schneider Title: WNS Production Engineer Signature ~~ / ~ Phone: 265-6859 Date ~ - f' C mmi i nl Sundry Number: ~~!(~ y' % /) L ( Conditions of approval: Notify Commission so that a representative may witness .~ ~ v n Clearance '~` st "' Locatio echanical IntegrityTe BOP Test '"~` M Plug Integr it y ~"` n / / n / q / Other: f' TD~~ t`~ ~n,s nt~DY' -~ twli-f -t~.SS //Li T-ica.~ C-JO,S'4.v'~, ~~'~i Subsequent Form Required: ~ ~ - 1 ~ [~ trt/l NC C ~~,~ ~..v.`,,~~L ~yt, -~p rrnq,~')~0~74 , APPROVED BY ~ p ~ D Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Req~V118 ~Y 12 `~ Q R I G I N A L ~ ~~~~~ Submit in Duplicate ~~~~~~ ConocoPhillips Al;tgk~1. InC. HANGER. CONDUCTOR, 34-114 SSSV, 1,770 GAS LIFT, 3,645 GAS LIFT, 5,7fi7 GAS LIFT, 7,828 NIPPLE, 7,907 PACKER. 7.949 NIPPLE. 8,024 WLEG, 8.035 WNS CD1-34 e I Attributes An le & MD TD Welibore API/UWI Fieltl Name Well Status Incl (°) MD (ftKB) Act Btm (RKB) 501032033300 ALPINE PROD 92.02 9,320.01 11,189.9 Comment H25 (ppm) Date Annotation End Date KB-Grd (R) Rig Release Dat SSSV: WRDP Last W0: 5/4/2000 70 11:56:50 AM el Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: PULL WRDP Imosbor 4/27/201( - Casin Strin s Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String WL.. String ... String Top Thrd CONDUCTOR 16 15.062 34.0 114.0 114.0 62.58 H-40 WELDED 1~" Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.697 36.6 2,433.5 2,361.5 36.00 J-55 BTC-MOD J F~ Casing Description Stnng 0... String ID ... Top (RKB) Set Depth (1... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 34.3 8,410.3 7,109.9 26.00 L-80 BTCM ~~ _~ Caein9 Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND)... Slring Wt... String ... String Top Thrd OPEN HOLE 61/8 6.125 8,409.9 11,189.9 7,086.9 Tubin Strin s Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 32.3 8,036.6 7,008.6 12.60 L-80 IBTM Com le tion De Top Depth tails (ND) Top Incl Nom .. Too IRKBI (ftKB) (°) Item Deaeriptlon Comment ID pi Min Top Depth (ftKB) Max Btm Depth (ftKB) Top Depth (ND) (ftKB) ••Botton Depth (ND) (ftKB) 8,410.0 11,189.9 7,109.9 7,086 Notes: General & Safe End Date 6/12/2009 NOTE: VIEW SCHEM/ PUMPED 166,358# OF 16/30 ), PLACING 161,715# INTO (ND) Incl OD Valve Latch Size TRO Run Stn Top (RKB) (RKB) (°) Make Model lin) Serv Type Type (in) (psf) Run Date Com... 1 3,645.4 3,394.2 32.94 CAMCO KBG2 1 GAS LIFT DMY BK 0.000 0.0 3/1/2008 2 5,767.4 5,188.3 32.27 CAMCO KBG2 1 GAS LIFT DMY BK 0.000 0.0 3/1/2008 3 7,828.4 6,893.1 48.23 CAMCO KBG2 1 GAS LIFT OV BK 0.250 0.0 ?F472998~ S-3 /C PRODUCTION, • ' 34-8,410 • OPEN HOLE ~ FRAC, 0.410 • • OPEN HOLE, o 8,410-11,190 • TD, 11,190 • Alpine Well CD1-34 (PTD 200-043) Justification for Administrative Relief Request As per Conservation Order 563, Rule 12, ConocoPhillips Alaska, Inc. requests a variance from Rule 6, Automatic Shut-in Equipment per bulletin No. 06-04. Colville River Unit well CD1-34 has inoperable control lines to the Sub Surface Safety Valve (SSSV). The current 14 day temporary operation of the well without an SSSV should be adequate for configuring and testing an alternative SSSV. - ~ ,,(~ ~x-/-~•~sia., ~r~,,,~~ ,S •G •% Well Status CRU well CD1-34 (PTD 200-043) was originally completed in May, 2000 as a development well. On April 25th after performing a coiled tubing cleanout on the well, the SSSV control and balanced lines were found to be plugged. The well was Shut-in for further diagnostics. All attempts to unplug the lines has been unsuccessful. A K-valve installation is currently planned upon approval from AOGCC. The well was opened on May 4, 2010 to establish stabilized flow to design the K-valve. Proposed Operating Plan 1. Continue operating the well in normal production service without an operable SSSV no later than May 10th (14 days since last successful SSSV test; May 25th). 2. Once the production rate stabilizes (~4-5 days), perform a flowing survey to capture pressure and temperature data for the K-valve design. 3. Set the closing pressure of the valve at 20 psi above operating wellhead pressure. 4. Provide information to the AOGCC as per Industry Guidance Bulletin No. 06-04, "Subsurface Safety Valves". 5. Stabilize well with K-valve installed and perform witnessed closure test. ~ 6. Incorporate the K-valve test frequency into the current SVS testing cycle at CD1 pad. Well History Date Event Well History CD 1-34:501032033300:5/4/2010 05/03/2010 SET 1/4" OV @ 7828' RKB. PULLED CAT SV FROM 8024' RKB. PRESSURED CONTROL LINES TO 7500 PSI AS PER CWG; CONTROL LINES ARE STILL PLUGGED. IN PROGRESS. 05/02/2010 SET CAT SV @ 8024' RKB. PULLED OV FROM 7828' RKB. LOADED IA AND TBG WITH 290 BBL HOT SW AND 95 BBL HOT DSL. CONTROL LINES CONTINUE PLUGGED. IN PROGRESS. 04/26/2010 PULLED 3.812" WRDP f/ 1709' RKB, BRUSHED BAL-O NIP @ SAME, UNABLE TO FREE UP OBSTRUCTED CONTROL & BALANCE LINE. JOB SUSPENDED. 04/25/2010 SET 3.812" WRDP (S/N: HSS-197) @ 1709' RKB, OBTAIN GOOD CLOSURE TEST. COMPLETE. 04/16/2010 TAG IN OPEN HOLE @ 8735' CTMD. FLUFF & STUFF W/ SLICK SEAWATER & BIOZAN, WHILE SIMULTANEOUSLY FLUSHING WELL @ 3 BPM WITH PRODUCED WATER, GET DOWN TO 8925' CTMD. ANOTHER ATTEMPT TO GET ~ ~ • DEEPER RESULTED IN LOSS OF DEPTH TO 8863' CTMD. LAY IN 150 BBLS OF 75 DEG DIESEL FROM 8800' CTMD TOP OF OPEN HOLE @ 8409'. RKB. TURNED WELL OVER TO DSO FOR PRODUCTION. 04/15/2010 GAUGE TBG TO 3.845" TO 1709' RKB. PULLED WRDP (SER# HRS-277) @ 1709' RKB. GAUGE TBG TO 3.78" TO 8024' RKB. READY FOR COIL. 03/03/2010 Pumped Crude / M209 bullhead job from 1:30 to 4:34 on 3/3/10. Pumped first 98 bbls (120 deg F) at 3.2 BPM with tbg at 200 psi; then pumped remaining 282 bbls at 2 BPM with tbg on VAC (380 bbls total). 02/28/2010 SET 3.812 WRDP-2 (S/N:HRS-277) @ 1709' RKB, GOOD CLOSURE TEST. JOB COMPLETE 02/22/2010 TAGGED UP @ 8393' CTMD (EST 10' INTO THE OPEN HOLE) UNABLE TO GET BY. DECIDED TO PUMP SCALE TREATMENT WITHOUT I COIL DATA. PUMPED 50 BBLS SW FLUSH FOLLOWED BY A 6 STAGE SCALE SQZ: EACH STAGE CONTAINED THE FOLLOWING: 2 BBLS SW/5206 (4.5 GAL)/14.5 bbls SW/SCW- 3001 WC (92 GALS)/2 BBLS SW/5206(4.5 GAL)/146 BBLS SW FLUSH/16.2 BBLS (10% J237A - OSR) FOR DIVERSION. SAMPLES TAKEN FOR QA/QC. WELL ON VAC DURING TREATMENT. TBG & FLOWLINE FREEZE PROTECTED W/ 40 BBLS OF DIESEL. ALLOW 12 HOURS SI PRIOR TO PRODUCTION. JOB COMPLETE. 02/21/2010 ATTEMPT SCALE PUMP JOB WITH I COIL. THE DTS POWER BOX SHORTED OUT PRIOR TO STARTING PUMPING STAGE. TROUBLESHOOT AND FINALLY FOUND A 24 VOLT (5 AMP) POWER SUPPLY & WAS GETTING DOWN HOLE DATA. RE- START INTHE A.M. IN PROGRESS. 02/18/2010 TAG UP IN 7" CSG @ 8239' CTMD. FLUFF & STUFF DOWN INTO THE OPEN HOLE TO 9125' CTMD WHERE COIL STUCK. ABLE TO PULL FREE UP TO 9060' CTMD WHERE TOOLS STUCK AGAIN, FINALLY WORKED IT FREE & PULLED COIL TO SURFACE. IN PROGRESS. 02/17/2010 GET UNIT RIGGED UP. PT ALL EQUIP AND PERFORM BOP TEST. FRESH START IN A.M. IN PROGRESS. 02/16/2010 PULLED 3.812" WRDP FROM 1709' RKB. GAUGED TUBING 3.78" TO 8024' RKB. COMPLETE. Tim S. Schneider Subsurface Development Staff Production Engineer WNS-Alpine ~ Phone: 907-265-6859 ~' Fax: 907-265-1515 ~ Mobile: 907-632-8136 D Email: tim.s.schneider@conocophillips.com Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, May 06, 2010 11:18 AM To: 'NSK Problem Well Supv' Cc: Schneider, Tim S.; Barreda, Brian B; Neville, David J; ALP DS Lead and Simops Coord; Regg, James B (DOA) Subject: RE: CD1-34 (PTD 200-043) Request for flow period extension Brent, An extension of 7 days for stabilizing CD1-34 is approved. If addition time is required notify the commission again for justification and approval. Ss/ i5 ®pQ,.,.~;,K.~. ~~ -G./v Guy Schwartz Senior Petroleum Engineer ~~S 't-®~~~~~ ~~ ~,c~~;,,,_ AOGCC !!! `' 793-1226 (office) 444-3433 (cell) From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Thursday, May 06, 2010 11:00 AM To: Schwartz, Guy L (DOA) Cc: Schneider, Tim 5.; Barreda, Brian B; Neville, David ); ALP D5 Lead and Simops Coord; NSK Problem Well Supv Subject: CD1-34 (PTD 200-043) Request for flow period extension Guy, As per our conversation, ConocoPhillips requests an extension on the test period of CD1-34. Currently the well is online and stabilization is trying to be achieved in order to gather information for a K-valve design. During the current test period the production is still fluctuating and has not become stable yet. The current shut-in date for the well will be May 10th. ConocoPhillips requests an additional 14 days to allow stabilization for proper settings of the K-valve in order to optimize production. Please let me know if the additional time is acceptable. Thank you. Brent RogerslMartin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 5/11/2010 STATE OF ALASKA i ALASKA AND GAS CONSERVATION COMMtSS1~4V REP01~7 OF SUNDRY WELL OPERATIbNS MAR }; 5 2010 ~Q 1. operations Performed: .Abandon Re air w ell ~ p ~` flug Fi'rforations ~"' Stimulate ~ ~ ~ ~~~' Alter Casing ~ Puli Tubing `°` Perforate New Pool ~ Waiver r" 1Trrie Extension ~' Change Approved Program ~ Operat. 8hutdow n ~'°" Perforate ~" Re-ente Suspended Well ""` 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska,. Inc. Development ~ Exploratory ~ 200-f143 - 3. Address: Stratigraphic ~"" Serve 8. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20333-00 7. Prop rty Designation: $. Weli Name and Number: ADL 25559' ~- CD1-34 9. Field/Pool(s): Colville River Field !Alpine Oil Pool 10. Present Well. Condition Summary: Total Depth measured 11190 feet Plugs (measured) None true vertical 70$7 .feet Junk (measured) None Effective Depth measured 11190 feet °Packer (measured) 7949 true vertical 7087 feet (true vertucaq 6966 Casing .Length Size MR TVD Burst Collapse CONDUCTOR $0 16 114 114 SURFACE 2397 9.625 2433 2361 __„_ ~~ PRODUCTION 8376 7 8410 711 ff ' ~ ^ ~~ Perforation depth: Measured depth: none ~~ ~~~ ~ `~ ~.o~~ True Vertical Depth: Wane. Tubing (size, grade, MD, and TVD) 4.5, L-80, 8037 MD, 7008 TVD Packers &SSSV (type, MQ, and TVD} PACKER - BAKER 2-3 PACKER @ 7949 MD and 6966 TVD SSSV - BAL-d SSSV 1710 MD and 1698 ND i 1. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 1279 bblS (7Umped 12. Representative Daily Average Production or Injection Data Oil-Bbt Gas-Mcf Water-Bbl Casing Pressure Tutaing Pressure Prior to well operation 627 2125 582 -- 199 Subsequent to operation 191 1924 365 -- 178 3. Attachments Well Class after proposed-work: Copies of Logs and Surveys run Exploratory '` Development Service ..Well Status after work: Oil ~'; Gas ~` WDSPL '°"" .Dairy Report of Well Operations XXX GSTOR "' WAG ~"` GASINJ ~ WINJ ~"; SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Ivia if C.O. Exempt. none Contact Brian Barreda Cc~ 265-6036 Printed Name -Brian Barrgda Title WNS .Production Engineer Signature ~ ~ Phone: 265-6036 Date ~ ' '~~ ' ~ ~ ~. ,. RHDMS MAR 15 ~~~'~~ Form 10-404 Revised 7/2009 ~ 3-~~'~U Submit Original Only CD1-34 Well Events Summary DATE- SUMMARY 2/16/10 PULLED 3.812" WRDP FROM 17~RK6. GAUGED TUBING 3.78" TO 8024'~B. COMPLETE. 2/17/10 GET UNIT RIGGED UP. PT ALL EQUIP AND PERFORM BOP TEST. FRESH START IN A.M. IN PROGRESS. 2/18/10 TAG UP IN 7" CSG (a~ 8239' CTMD. FLUFF & STUFF DOWN INTO THE OPEN. HOLE TO, 9125' CTMD WHERE COIL STUCK. ABLE TO PULL FREE UP TO 9060' CTMD WHERE TOOLS STUCK AGAIN, FINALLY WORKED IT FREE & PULLED COIL TO SURFACE. IN PROGRESS. 2/21/10 ATTEMPT SCALE PUMP JOB WITH I COIL. THE DTS POWER BOX SHORTED OUT PRIOR TO STARTING PUMPING STAGE. TROUBLESHOOT AND FINALLY FOUND A 24 VOLT (5 AMP) POWER SUPPLY & WAS GETTING DOWN HOLE DATA. RE-START IN THE A.M. IN PROGRESS.. 2/22/10 TAGGED UP @ 8393' CTMD (EST 10' INTO THE OPEN HOLE) UNABLE TO GET BY. DECIDED TO PUMP SCALE TREATMENT WITHOUT I COIL DATA. PUMPED 6 STAGE SCALE RX PER PROCEDURE & SAMPLES TAKEN. TBG & FLOWLINE FREEZE PROTECTED W/ 40 BBLS OF DIESEL. ALLOW 12 HOURS SI PRIOR TO PRODUCTION. JOB COMPLETE. 2/28/10 SET 3.812 WRDP-2 (S/N:HRS-277) @ 1709' RKB, GOOD CLOSURE TEST. JOB COMPLETE Cdnoc©Phi{dips ~t i~:l., if K;. ... __ _ Well( Ig: CO134. 3/'.l: ~ema:tc Ac HANGER, 32 SSSV. t ]10, W RDP. 1,]10 - SURFACE._ 37-2,d33 GAS LIFT. _. __.. 3,665 GAS LIFT. __ 5,767 GAS LIFT NIPPLE. 7,907 - - PACKER, ].94N NIPPLE. 6.024 WLEG. 6.035-- PRODUCTION, 34-Bp10 OPEN HOLE FRAC, 8.410 OPEN HOLE,_ 8.410-11,190 \ TD, 11.190 ~ WNS 'll Attributes Ilwre APl/UWI Field Name 501032033300 ALPINE ent ~~.H2S iWP~nl 3V: WRDP ota[ion Depth (ftK8) IEnd Daie t Tag Ising Strin_g_s _ ' D s r' t' Str'n O Strni IL C D 1-34 .~,.. Max Angle 8~ MD TD (Well Statuti Incl (') IMD (HKB) Act Bbn (ftK6) PROD 92 G2 9,320.01 11,189 9 Date Annotation IEnd Date K8-Grd (ft) Rig Release Date ''Last WO: 5/4/2000 Annotation ~ Last Mod ._ End Date Rev Reason: RESET WRDP Imosbor 3/1/2010 - -- To (itK6) Set Da th (f Set De th(ND) Str g Wt Str g 'String Top Thrd .,mg e c Ip Ion '.ONDUCIOR I g g ... 16 1:i 1762 p 34.0 P ~~~ 114.0 P 114.0 I 62.58 ~ H-40 WELDED asing Description String 0... String ID ._ Top (HKB) Set Depth (f... Sel Depth (ND) ... String W[... String ... String Top Thrd URFACE 9518 8.69% 36.6 2,433.5 2,361.5 36.00 J-56 '. BTC-MOD asing Description String 0... (String ID ... Top (HKB) Set Depth (f_. Set Depth (ND) ... ( String Wt... String ... ~; String Top Thrd RODUCTION 7 ~ 6.151 34.3 8,410.3 7,109.9 26.00 L-80 ~ BTCM asing Description String O._ 'String 10 ._ Top (kKB) Set Depth (f... Set Depth (ND) ... I String Wt... String ... (String Top Thrd (PEN I-IDLE 61/8 '. 6.125 8409.9 11,189.9 _/086.9 . L ,~ "ubin Stnn s ub'ng Des 'pt'on _ ~ .String O._ Slo g ID . _ _ __ _ _ Top (flK6) Set Depth (f - _- - Set Depth (ND) . %< __ St mg Wt... Str g 'String Top Thrd UBING '~ 41/2 ~ i+:SF. ~ 323 I 80366 /008.6 I IBTM 1260 L 80 . . _- :ompletion De tails. - ,Top Daplh '~ IND) Top Incl Nomi... op (HKB)(, (HKB) (°) l~em Descriptio n Commend ID (in) 32.3 32.3 -0.36 HANi= L-R. FMC TUBING HANGER 4.500 1,709.9 1,697.5 12.73 SSS`,i BAL-O SSSV 3.812 7,907.1 6,942.3 54.65 _............_._ NIPPLE HES'X' NIPPLE 3.813 7,949.3 6,965.4 58 44 PACKER- ~ - BAKER 2-3 PACKER 3.875 8,024.4 7,002.8 62.09 NIPPLE HES'xN' NIPPLE 3.725 8,035.4 7,008.0( 62.63 WLEG WIRELINE ENTRY GUIDE 4.500 )thee I n Hole j Wireline rgtrievab le plugs, valves, pu mps, fish, e~S .~ ,_.~, ; ____ Top Depth (TVD) lop Incl op (ftK8( (HKB) (°) Deg. '1 uori Comment Run Date ID (in) 1,710 1697.6 _ 1273~4NRD6~ j3.812"WRDP (HRS-277) 2/28/2010 2.125 >tlmulations 8 ' - Treat menu _ ' _ - -__ _~ ~ ~- ^_ ~ _ - Min Top Max Bbn E.~noln Top Depth Dept~'i Depth ~i Depth (ND) (TV04 (ftK8) (HKB) 'I (HKB) IItK E,i Type Date Comment 8,410.0 11,189.9 7,109.9 7.086.9 OPEN HOLE 3/3/2008 PUMP C SAND HYDRAULIC FRACTURE FRAC TREATMENT. PUMPED 166,358# OF 16/30 BADGER SAND, PLACING 161,715# INTO ~FORMAfION. dotes: General 8 Safety _~,_- _ _ End Date Annotation • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS s. 1. Operations Pertormed: 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. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhllllps Alaska, InC. Development ~• Exploratory ^ 200-043 /. 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20333-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' ~ CD1-34 . 8. Property Designation: 10. Field/Pool(s): , ADL 25559 - Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 11190' - feet true vertical 7087 - feet Plugs (measured) Effective Depth measured 11190' feet Junk (measured) true vertical 7087 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 2433' 9-5/8" 2433' 2361' PRODUCTION 8410' 7" 8410' 7110' OPEN HOLE 2780' 5-1/2" 11189.9' 7087' '~~'~~/ ~~ ~` ~~~~'~ Perforation depth: Measured depth: none ~ ~~~~~ true vertical depth: none i~AY` ~ ~ 209 Tubing (size, grade, and measured depth) 4.5", L-80, 8037' MD. ~iI8Si43 (lil ~t G8S Ctall~. ~'iQft1f'ill~~iilt~ Packers & SSSV (type & measured depth) Baker S-3 pkr @ 7953' Anc~~afaq,~ Camco nipple @ 1710' 12. Stimulation or cement squeeze summary: Intervals treated (measured} pumped 973 bbls, refer to attachment 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 1276 1894 685 -- 198 Subsequent to operation 1022 1914 794 -- 200 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after 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 N/A if C.O. Exempt: none contact Tim Schneider @ 265-6859 Printed Name Tim Schneider - Title Alpine Staff Engineer ' ` ..~~ ,% Signature t Phone: 265-6859 3 U " D f Date Y ~ Pre aced b Sharon Allsu -Drake 263-4612 Form 10-404 Revised 04/2006 Submit Original Only ~. WNS _ ConOCOPI'Iiltips ~~ weii Attributes ~ _ Wellhore APIIU WI Field Name Well Status `,~`~S'~".I 1" 501 03 20 3 33 00 ALPINE PRODUCING Comment H25 (ppm) (Data 'Annobtic _.__ __ wznc M1g coy--3a lezou'visvu a~N - SSSV: WRDP 0 7!1/2009 ,Last WO ___. S n ma. A I -- _ !Annotation 'I Depth (kKB) End Dale ~,IAnnotation CONDUCTOR. 110 NIPPLE, 1,710 WRDP. 1.710 PRODUCTION Top Inc! SURFACE. 2.x33 GAS LIFT. 3.645 GAS LIFT. 5.767 GAS LIFE. 7.828 NIPPLE, 7.907 °ACKER, 7.953 NIPPLE, 8.024 WLEG, B U37 PRODUCTION, Bp 10 t OPEN HOLE I FRAC, 9,410 OPEN HOLE. 11190 J TD, 11,190 - 7,828 CD1-34 A B tm (HKB) 71,789.9 Rig RBleasa Date 5/4!2000 End Date 4!812009 1 ,008.8 2 (SER# 13/19/2009 2. PKG STACKS) I 'Comment STA 1 '~, 3!1/2008 3. ' Comment STA 2 ~3l1 /2008 3. ~!/Comment: STA 3 3/4/2008 3. stimulations & Treatments ___ _ __ _ - BOLtOm Min Top i Max Btm Top Depth Depth Depth Dapih (TVD) (TVD) (ftK6) (HKB) ~ (HKB) (ttKB) Type Date Commant _ 8,410.0 11,189.91 7,109.9 7,086.9 OPEN HOLE 3/3!2008 PUMP C SAND HYDRAULIC FRACTURE ~ FRAC TREATMENT. PUMPED 16fi,358# OF 16!30 BADGER SAND, PLACING 161,715# INTO FORMATION. WSR -Well Service Report Well Service Report Page 1 of 2 Weli :Job Scope CPAI. Rep CD1-34 Scale Inhibition Shirtliffe, Ryan Date Daily Work Unit Number 4/16/2009 Steve Abbott -Cementing and Stimulation Services MISC Initial & T/IA/OA Start - Final 1050/1050/850 End - Pressures: VAC/1100/850 Field: ALPINE 2~l hr. Summary Pumped a multi stage aqueous scale inhibition squeeze. Total volume pumped wa 973 bbls. Treatment report shows 855 bbls pumped but Schlumberger meter seem to be out compared to tank strap and truck volumes. STARTTIME OPERATION 08:00 AM LRS heating water in uprights. 12:00 PM Rigging up schlumberger. 01:00 PM Check Lines and pressure test. 01:30 PM Pump first stage of job. SW+WAW5206 chemical at 2-5 bpm. Schlumberger meter reading was 109.7 bbls. Stage pumped at 320 psig. 02:06 PM Switch valves and pump SW+SCW3001 chemical at 300 psig and 2-Sbpm. Metered 43.6 bbls through pump. 02:21 PM Switch and pump SW±WAW5206 post flush at 283 psig, and 2 bpm. Truck empty. 02:27 PM Pump stage flush volume of straight sea water at 2-7 bpm. Metered 144.1 bbls. 03:15 PM Shut down the pump and mixed 8 bbl benzoic acid flake gel. Pumped slury into well 03:45 PM Switch to SW+SCW3001 WC Chem and pump a metered vo143.6bbls at 7 bpm, 215psig. 03:57 PM Pump seawater flush metered vol of 148.2 bbls at 150psig, 7 bpm 04:27 PM Mix and pump second benzoic acid flake slurry 04:57 PM Pump SW+SCW3001 WC them stage. Metered 38.2 bbls then ran out of mix. 05:12 PM Switch over to seawater and pump remainder of job. Metered 301 bbls SW. Tubing pressure was 140-220psig at 7bpm. Stage called for 410 SW. 06:00 PM Shut down, rigged out equipment. 07:00 PM LRS pum ped freeze protect 30 bbls diesel Fluid Type Ta WeIl From Well Nan- recoverable Note SEAWATER, SCW- 3001 WC 706 SEAWATER, SCW- 3001 WC 131 SEAWATER, WAW- 143 http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=03 6DF2C... 4/22/2009 %a • STATE OF ALASKA ~ , i ~ - ALASKA OIL AND GAS CONSERVATION COMMISSION ~" REPORT OF SUNDRY WELL OPERATION~~ ~ ;,_ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q 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: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 200-043 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20333-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB = 36' ~ CD1-34 ' 8. Property Designation: 10. Field/Pool(s): ADL 25559 • Colville River Field /Alpine Oil Pool • 11. Present Well Condition Summary: Total Depth measured 11190' ~ feet true vertical 7087' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2433' 9-5/8" 2433' PRODUCTION 8410' 7" 8410' OPEN HOLE 2780' 6-1/8" 11190' Perforation depth: Measured depth: ++~~(~}} -.~:1 ~4~t; ~ ~ G4~J ~~~ i~~ true vertical depth: Tubing (size, grade, and measured depth) 4-1/2", L-80 @ 8037' MD Packers & SSSV (type & measured depth) Baker S-3 Packer @ 7953' MD Camco Bal-O Nipple @ 1710' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1941 2297 611 762 205 Subsequent to operation 1306 1034 1029 1234 189 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: OilO • 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 N/A if C.O. Exempt: N/A Contact Tim Schneider Printed Name T/i~~'S hn ider Title Ph Production Engineer ~"'j©"~~ D t Signature .~-° j~ 1 one a e 265-6859 / / Pre ared b Jeann L. Haas 263-4470 ~p //•(3• s .~ t ~ Form 10-404 Revised 04/26p6 ,~ " f ~~ ~ ~,x ``~~=~ # ~,.~' ~ ~ ~Qd~ Submit O~yinal Only ~+`~ ~,, i!~/f ~~'~ ~: Cotc~coF'hil~ip~ Alaska, ln~. ALPINE CD1-34 CD1-34 API: 501032033300 Well T e: PROD An le TS: de SSSV SSSV Type: WRDP Orig Com letion: 5/4/2000 Angle @ TD: 91 deg @ 11190 (1710.7711, Annular Fluid: Last W/O: Rev Reason: Format U date OD:3.812) Reference Lo Ref Lo Date: Last U date: 11/24/2003 Last Ta TD: 11190 ftK6 Last Tag Date: Max Hole Angle: 92 deg @ 9320 Casin 5trin -ALL Descri lion Size To Bottom TVD Wt Grade Thread Gas Lift CONDUCTOR 16.000 0 114 114 62.58 H-40 WELDED MandrelNalve SURF CASING 9.625 0 2433 2361 36.00 J-55 BTC-MOD 1 (36453646, PROD CASING 7.000 0 8410 7105 26.00 L-80 BTCM OD:5.948) OPEN HOLE 6.125 8410 11190 11190 0.00 Tubin Strin -ALL Size To Bottom TVD Wt Grade Thread 4.500 0 8037 7009 12.60 L-80 IBTM Gas Lift Ma ndrelsNalves Gas Lift MandrelNalve ~'" St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VIv Cmnt 2(5767-5768, 1 3645 3394 CAMCO KBG2 CAMCO GLV 1.0 BK 0.188 1770 1/27/2001 OD:5.948) 2 5767 5188 CAMCO KBG2 CAMCO GLV 1.0 BK 0.250 1856 1/27/2001 3 7828 6893 CAMCO KBG2 CAMCO OV 1.0 BK 0.250 0 1/26/2001 Other lu s e'ui .etc. -JEWELRY De th TVD T e Descri lion ID 1710 1698 NIP CAMCO BAL-O LANDING NIPPLE 3.812 Gas Lift 1710 1698 SSSV CAMCO WRDP-2 2.125 MandrelNalve 7907 6942 NIP HES'X' NIPPLE 3.813 3Q828-7829, _ 7953 6967 PKR BAKER S-3 PACKER 3.875 OD:5.948) ~ 8024 7003 NIP HES'XN' NIPPLE 3.725 8037 7009 WLEG BAKER RE-ENTRY GUIDE 3.875 NIP (1907-7908, OD:4.500) PKR (79537954, OD:7.000) NIP (8024-8025, OD:4.500) TUBING (0037, OD:4.500, ID:3.958) OPEN HOLE (8410-11190, OD:6.125) 1 , ' , 1 ' WSR -Well Service Report Well Service Report Page 1 of 1 well ;~~~ Scope CPAI Rep CD 1-34 Scale Inhibition Brake, Jared Date Daily Work Unit Numt-er 10/24/2008 Scale Squeeze 32 Network # Daily Cost Cum Cost Company Unit. Supervisor 10236635 $7,300 $7,300 LRS LUNDSTROM Initial & INITIAL T/I/0= Final 1000/1000/700 FINAL Field: ALPINE Pressures: T/I/0= 0/1000/800 MIRU LRS AND PUMP SCALE INHIBITIONS UEEZE. PUMPED TOTAL OF 868 BBLS OF SEAWATER DOWN TUBING. PUMPED 200 BBLS SW, 36 BBLS PRE-FLUSH WITH 153 GALLONS WAW-5206, 243 BBLS SW WITH 24 hr. Summary 1,530 GALLONS SCW-3001, 36 BBLS POST FLUSH 153 GALLONS WAW- 5206, PUMPED 353 BBLS SW FOR OVER DISPLACEMENT. FREEZE PROTECT WELL WITH 25 BBLS DIESEL. TURN WELL OVER TO OPERATIONS. STARTTIiVIE OPERATION 02:00 PM MIRU LRS and PT surface equipment to 3,000 psi. 02:30 PM Start pumping intital 200 bbls seawater 4.35 BPM intial tbg pressure 1200 psi. 03:30 PM Start pumping 36 bbls of pre-flush 4.35 BPM TBG psi 650 psi. 03:45 PM Start pumping 243 bbls SW with SCW-3001 4.35 BPM TBG 650 psi. 04:45 PM Start pumping 36 bbls of post flush 4.35 BPM TBG 600 psi. 05:00 PM Start oumping 353 bbls of over displacement 4.35 BPM TBG 600 psi. 06:30 PM Pump 25 bbls diesel for freeze protect @ 2.50 BPM TBG 325 psi. Well currently on vac. Fluid Type To Well From. Weil 'Yon- recoverable ,vote SEAWATER, WAW- 70 DWN TBG 5206 SEAWATER, SCW- 243 DWN TBG 4004 SEAWATER 550 DWN TBG DIESEL 25 FP file://C:\Documents and Settings\sallsup\Local Settings\Temporary Internet Files\OLKB6... 10/30/2008 • STATE OF ALASKA • MAR 2 6 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION AI?~k8 Uil g Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 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^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 200-043 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20333-00 ' 7. KB Elevation (ft): ~ 9. Well Name and Number: RKB = 36' CD1-34 8. Property Designation: 10. Field/Pool(s): ADL 25559 Colville River Field /Alpine Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 11190' ~ feet true vertical 7087' ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' SURF CASING 2433' 9-5/8" 2433' PROD CASING 8410' 7" 8410' OPEN HOLE 2780' 6-1l8" 11190' {~~ APR 2008 Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 8037' MD. Packers &SSSV (type & measured depth) pkr= BAKER S-3 PAC KER pkr= 7953' SSSV= NIP ; SSSV SSSV= 1710' ; 1710' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1842 ~ 997 236 87 196 Subsequent to operation 3445 8695 498 109 281 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^O Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: ° OilO , 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: 308-021 Contact Printed Name Tim Sc Heider Title Production Engineer Signature ~-- ~~~~ t° Phone 265--6859 Date .3 ~ ~~ ~~, ~ Form 10-404 Revised 04/2004 0 R 1 G 1 ~ A L V J~"~ ( ~ t'tC l Submit Original Only ~~ 3~7/©~ ~ • CD1-34 Stimulation Results Summary of stimulation job: 3-03-08: Pump frac in one stage: The frac ramped from 2-9 ppa; 2755 bbls flush volume, 1412 bbls SW flush. Frac: AIR-40 BPM, AIP-1866 psi prior to the screen out. 161,715 lbs. 16/30 Badger sand was placed. Well test: 3/22/08: 3445 bopd, 498 bwpd, 8.7 mmcfpd, 281 WHP • ¢ ~ ~ r ~ t ~ ~ ~ 11 ALASKA OII, A1~TD GA-S COI~TSERQATI011T COMt~IIS5IOrIT Brian Barreda Production Engineer Conoco Phillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 • SARAH PAI.IN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Alpine Oil Pool, CD 1-34 Sundry Number: 308-021 ~ ~' Dear Mr. Barreda: 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 (pagerj. 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 January, 2008 Encl. Sincerely. di~,~ ~~~ ~!I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~Cd~ID JAN ~ 7 ~il(?8 APPLICATION FOR SUNDRY APPROVAL ~ .. 20 AAC 25.2so Alaska nil ~ Gas Cans. ~;orftmissan 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ „_ V~1i~~(~ 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 ^ 200-043 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20333-00 ' 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 ~ CD1-34 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25559 RKB 36' Colville River Field /Alpine Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (n): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11190' 708T Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURF CASING 2433' 9-5/8" 2433' PROD CASING 8410' 7" 8410' OPEN HOLE 2780' 6 1/8" 11190' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1 /2" L-80 8037' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER S-3 PACKER pkr= 7953' SSSV= NIP ; SSSV SSSV= 1710' 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: February 15, 2008 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: Brian Barreda Printed Name Brian Barreda Title: Production Engineer ~ ff11 Signat a ~r~~.-. ~aZ-/~.:Y~ Phone 670-4798 Date 1/16/08 Commission Use Onl al: Notif Commission so that a re resentative ma witness Co ditio s of a ro Sundry Nu ber: ~~ ~ + ~ ~' p n n pp v y y Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: . _ ~ S ~If"~- ,)~~ ~ ~ ~dfl~ Subsequent Form Required: ~(1~.1 APPROVED BY / Approved by: S TONER ~~ ~~~ THE COMMISSION Date: ` Form 10-403 Revised 06!2006 ~ f ~'[ ~ ~ ~~ ~ ~ Submit in Duplicate • • Overview: CD1-34: A hydraulic fracture treatment will be performed in the openhole horizontal section to establish communication vertically and longitudinally through the Alpine "C" sand. This will increase the wells production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU 8 clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment) "'-, 2. Rig up Schlumberger equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 100 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 40 BPM with a maximum pressure of 6000 psi, add breaker as per lab results. Maintain 2000-3000 psi on the IA during the treatme~ nom' • 100 bbls YF125ST Pad • 100 bbls YF125ST w/ 2 ppa 16/30 White Sand • 170 bbls YF125ST w/ 4 ppa 16/30 White Sand • 250 bbls YF125ST w/ 7 ppa 16/30 White Sand • 40 bbls YF125ST w/12 ppa 16/30 White Sand Repeat treatment above 4 times. • Flush the last stage with linear YF125ST and freeze protect Total Sand: 450,000 lbs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. . . Conoc;Phillips Alaska .- P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 "i. March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 1 0 2007 JJ}D-O'-r3 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-1 06 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 ?/16/?007 Alpine Field March 31,2007 MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ConoCoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface easing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD 1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS BBLS Cement CD1-1 2.25' 0.3 WI 1.8 CD1-2 4' 0.6 WI 3.6 CD1-3 10' 1.4 MI 8.5 CD1-4 7.33' 1 P 6.0 CD1-5 4' 0.6 MI 3.6 CD1-6 10.42' 1.4 Gl 8.5 CD1-16 14.33' 2 WI 12.1 CD1-17 8.75' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 CD1-22 1.83' 0.3 P 1.8 CD1-23 15.42' 2.1 MI 12.7 CD1-24 2' 0.3 P 1.8 CD1-25 5.66' 0.8 P 4.8 CD1-27 18.83' 2.6 P 15.7 CD1-28 6.75' I P 6.0 CD1-32 8.33' 1.2 P 7.2 -- CD1-34 41.83' 5.7 P 34.4 CD 1-36 16.75' 2.3 WI 13.9 CD1-38 3.5' 0.5 P 3.0 CD1-42 5.83' 0.8 MI 4.8 CD2-16 11.66' 1.6 INJ 9.7 CD2-17 18' 2.5 INJ 15.1 CD2-19 11.66' 1.6 P 9.7 CD2-22 13.5' 1.8 INJ 10.9 CD2-25 2~.25' 3.-7 P 22.3 CD2-26 10.42' 1.4 INJ 8.5 CD2-32 8.5' 1.2 INJ 7.2 CD2-33 --- 7' 1 P 6.0 CD2-34 4' 0.6 P 3.6 CD2-41 11.83' 1.6 P 9.7 CD2-46 7.42' 1 INJ 6.0 CD2-48 10.33' 1.4 INJ 8.5 CD2-49 9.33' 1.3 INJ 7.8 CD2-50 1.66' 0.25 P 1.5 Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04~23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry. I agree Jerry that individual 404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling · the conductors with cement. I believe 34 wells were treated. Chuck Scheve · and John Crisp were notified but declined to witness when we told them what · we were doing. Some time past we had agreed to submit a 10-404 for this · kind of work. Due to the number of these, is a 10-404 needed on each well? · I don't want to commit the time to doing this if it is not necessary; · 10-404's are time consuming to prepare. Would a list of the jobs suffice, · or something similar? We have the well numbers, depth to cement top, and · sacks used to fill the void. My proposal would not affect future · submissions of 10-404's for this work. What do you think? Thanks! · Jerry Dethlefs (See attached file: tom_maunder.vcf) I of 2 4/24/2003 7:55 AM i[AOGCC t Name: AOGCC ALPINE cement top outs 04-16-03,xlsl ALPINE cement top outs 04-16-03,xlst Type: EXCEL File (application/msexcel) . IEncoding: base64 DCement Top Fill AOGCC Letter 04-23-03,doc Name: Cement Top Fill AOGCC Letter 04-23-03,doc Type: WINVVORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder~admin,state, ak, us> sr, Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 4/24/2003 7:55 AM Permit to Drill No. 2000430 DATA SUBMITTAL COMPLIANCE REPORT 5/13/2002 Well Name/No. COLVILLE RIV UNIT CDI-34 Operator PHILLIPS ALASKA INC. MD 11190 TVD 7087 Completion Date 5/4/2000 ~ Completion Status I-OIL Current Status I-OIL AP1 No. 50-103-20333-00-00 UIC N REQUIRED INFORMATION Mud Log N_.~o Samples N~o Directional Survey N._~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Dataset Scale Media No Start Stop CH Received Number Comments L ARRAY RES-TVD ~.-'""SRw RpT L ARRAY RES-MD *W'~RVY CALC 25 FINAL 25 FINAL 2385 7100 0 1119O 2385 11143 115 11119 OH 61112000 OH 5/16/2000 SPERRY O 611/2000 09631 '-'/2385-11190 OH 6/1/2000 OH 6/29/2000 BHI . Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis Received? Daily History Received? (~J N Formation Tops Receuived? '~ N Comments: Compliance Reviewed By: Annular Dis ~osal durin the second quarter of 2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date / 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1C-133, 1C-121, 1C-123, 1C-127 ~ 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 .100 0 3633 0 3633 Jun 01 Jun 01 1C-127 ( Total Volumes into Annuli for which Dis ~osal Authorization Expired during the second ,uarter 2001' Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume .Status of Annuln.~ " 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1 D-38, 1D-30 / CD1-25 · 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD 1-32, CD 1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down. CD1-34 only - CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 31, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Second Quarter, 2001 - REVISED Dear Ms. Mahan: Please find attached the revised report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. We have revised the amount for CD2-42 because the original manifest incorrectly reported the CD2-24 annulus used for the disposal. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake ~,o] -osd Annult Dis ~osal durin the second ~uarter ~2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1c-133, IC-121, IC-123, 1c-127 2N-315 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 . 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli ~or which Dis oosal Authorization Expired during, the second quarter 2001: ' ' Total volume - ' Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus 1D-11 135, 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD1-41 only CD1-34 27'8 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down 'CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQI goo -Ol :/ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 26S-6224 July 17, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Second Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad RECEIVED JUL i 9 2001 CC: Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Alaska Oil & Gas Cons. Commission Anchorage Annular Dis ~osal durin the second quarter of 2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C.17 33139 100 0 33239 0 33239 May 01 Jun 01 lC-133, 1C-121, 1C-123, 1C-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 16902 100 0 17002 0 17002 May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli ~or which Disposal Authorization Expired during the second quarter 2001: ' Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus ID-Il 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only cD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down/ CD1-34 only ~... CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CDI-28, CD1- 33, cD1-NQ1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _X Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 56 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Servia__ Colville River Unit 4. Location of well at surface 8. Well number 458' FNL, 2938' FEL, Sec. 5, T11 N, R5E, UM (asp's 385765, 5975671) CD1-34 At top of productive interval 9. Permit number / approval number 2518' FNL, 357' FEL, SEC. 6, T11 N, R5E, UM (asp's 383041, 5973654) 200-043 At effective depth 10. APl number 50-103-20333 At total depth 11. Field / Pool 5173' FNL, 4199' FEL, Sec. 5, T11 N, R5E, UM (asp's 384448, 5970977) Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured 11190 feet Plugs (measured) true vertical 7087 feet Effective depth: measured 11190 feet Junk (measured) true vertical 7087 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" 10 cu yds Portland Type 3 114' 114' SURF CASING 2433' 9-5/8" 390 Sx AS III L, 217 Sx Class G 2433' 2361' PROD CASING 8410' 7" 137 Sx C~ass e 8410' 7105' OPEN HOLE 2780' 6.125" 11190' OPEN HOLE Perforation depth: measured None RECEIVED-' true vertical None and measured depth 4-1/2', 12.6~, L-80 Tbg O 8037' MD. - · Tubing (s~ze, grade, Packers & SSSV (type & measured depth) BAKER S-3 PACKER O 7953' MD. CAMCO BAL-O LANDING {~ 1710' MD. 13. Attachments Description summary of proposal ~ Detailed operations program__ BOP sketch__ 14. Estimated date for commencing operation 15. Status of well classification as: April 14, 2001 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing Is true and correct to the best of my knowledge. Questions? C~ll Michael Erwin ~ 265-1478. Signed 'ntie: Alpine Production Engineer Prepared b~, Sharon Al/su~-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: PlugN°tifYintegrilyC°mmissi°n_ so representatiVeBoP Test __ may witneSSLocation clearance --~',~.~ , I Approval no. ~:~l - [ i 7 Mechanical Integrity Test__ Subsequent form required 10- "~ / Approved by order of the Commission n -r-,,,i,,, c, ..... Commissioner Date Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLICATE Stimulation Procedure Colville River Field CD1-34 Conversion operations will commence following ice road construction on or about April 1, 2001. Completion is expected on or about April 15, 2001. This procedure is designed to clean out and stimulate a newly drilled producer. The goal is to remove filtercake, drilled solids, and polymer from the openhole completion. 1. RU coil tubing unit. GIH with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with diesel. 2. Spot +/-110 bbl. of DS MudSolv mixed in a 9.2 ppg KCL base fluid in the openhole interval. 3. POOH and RD coil tubing. 4. Allow the breaker to soak for 24 hours. 5. Return the well to production. ""-"' STATE OF ALASKA '"'~" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Pertorate_ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 56 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 StratigraphY__ Anchorage, AK 99510-0360 ser~__ Colville River Unit 4. Location of well at surface 8. Well number 458' FNL, 2938' FEL, Sec. 5, T11 N, R5E, UM (asp's 385765, 5975671) CD1-34 At top of productive interval 9. Permit number / approval number 2518' FNL, 357' FEL, SEC. 6, T11N, R5E, UM (asp's 383041, 5973654) 200-043 / At effective depth 10. APl number 50-103-20333 At total depth 11. Field / Pool 5173' FNL, 4199' FEL, Sec. 5, T11 N, R5E, UM (asp's 384448, 5970977) Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 11190 feet Plugs (measured) true verUcal 7087 feet Effective depth: measured 11190 feet Junk (measured) true vertical 7087 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" lO cu yds Portland Type 3 114' 114' SURF CASING 2433' 9-5/8" 390 sx AS III L. 217 Sx Class G 2433' 2361' PROD CASING 8410' 7" 137 Sx cross e 8410' 7105' OPEN HOLE 2780' 6.125" 11190' Perforation depth: measured None RECEivED true vertical None Tubing (size, grade, and measured depth) 4-1/2'. 12.6#. L-80 Tbg O 8037' MD. Packers & SSSV (type & measured depth) BAKER S-3 PACKER O 7953' MD. CAMCO BAL-O LANDING ~ 1710' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached description Treatment description including volumes used and final pressure 14. Representative Dally Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2541 3403 9 - 187 Subsequent to operation 3380 2609 0 - 202 15. Attachments 16. Status of well classificaUon as: Copies of Logs and Surveys run __ Daily Report of Well Operations _.~ Oil __X Gas __ Suspended ~ Service 17. I hej:qby (~ertify that the foregoing]s true and correct to the best of my knowledge. .[I Sign Title Alpine Production Engineer Data Michael Erwin Prepared by Sharon A/Isup-Drake 263-46~, Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE CD1-34 Summary of Work Completed CT Enzyme Treatment 4/14/01: TAGGED TD AT 11,171' CTM DOWN (11,190' MD). LAID IN 134 BBL MUDSOLV FROM 11,120' MD THRU OPENHOLE AT 1:1. LEFT DIESEL TO 7300', WELL SI FOR 24 HOUR SOAK. FDR TOOL EFFECTIVE IN REACHING TD. [Other Stim, Tag] 4/15/01: FLOWED 111 BBL DIESEL AND 148 BBL CRUDE AT APPROX 1 BPM. NO WATER OR EMULSIONS SEEN. TURNED WELL OVER TO PRODUCTION. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Poet Office Box 100360 Anchorage, Alaska 99510-0360 P. Maz. zolinl Phone (907) 263-4603 Fax: (907) 265-6224 July 25, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the second quarter of 2000, as well as total-volumes injected into annuli for which injection authorization expired during the second quarter of 2000. . . Annular Injection durin$ the second quarter of 2000: h(1)' h(2) h(~) TOtal for previous New Well Name Volume Volume Volume Quarter Total Total 2N-341 20406 100 0 20506 0 20506 2L-313 4640 100 0 4740 12533 17273 CD 1-40 108 100 0 208 32669 32877 CD1-23 16751 100 '0 16851 17135 33986 CDI-16 25 0 0 25 29025 29050 CD1-32 82 100 0 182 33331 33513 CD1-38 11056 100 0 11156 9164 20320 CDI-27 32333 100 0 32433 381 32814 1L-28 5853 100 0 5953 3984 9937 --' 1D-11 135 100 0 235 0 235 1D-14 1337.6 100 0 1437.6 0 '1437.6 CD1-25 8141 100 0 8241 386 8627 CD1-34 278 100 0 378 0 378 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 D. Chester Phone (907) 263-4792 Fax: (907) 265-6224 June 22, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for CD 1-34 (200-043) Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Completion Report for the drilling operations on CD 1-34. If you have any questions regarding this matter, please contact me at 263-4792 or Brian Robertson at 265-6034. D. (~lfester Alpine Drilling Team Leader PAI Drilling DC/skad RECEIVED JUN 2 9 2000 Alaska Oil & Gas Cons. Commission .Anchorage --..__,.- STATE OF ALASKA ---,~'-- ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r'~ Gas D Suspended E] Abandoned D Service r"l 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. ,~ .~ 200-043 __m ii __ __J-~ ,. P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20333-00 4. Location of well at surface~'~ '~ ..'T',',',',',',',~,.. ~ ~ r 19. Unit or Lease Name 459' FNL, 2342' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385767, 5975672) --;";'"'%~'T~-" ~ ,~..:u ....... ~'~ j Colville River Unit ; .~ATE At Top Producing Interval !~I ' 10. Well Number CD1-34 2518' FNL, 357' FEL., Sec. 6, T11N, R5E, UM (ASP: 383041, 5973654) At Total Depth ! --~'~--- ~ ...T,J 11. Field and Pool 103' FSL, 1083' FWL, Sec. 5, T11 N, R5E, UM (ASP: 384448, 5970977) ,-.-~-..-,- .... Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool DF 56 feetI ADL 25559 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions April 22, 2000 May 3, 2000 May 4, 2000I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11190'MD/7087'TVD 11190'MD/7087'TVD YES I~] No [--II 1710' feetMD 1564' 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. CASING, LINER AND CEMENTING RECORD SE-'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 115' 42' 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2433' 12.25" 390 sx AS III L, 217 sx Class G 7" 26# L-80 Surface 8410' 8.5" 137 sx Class G .24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 8037' 7949' 6.125" OH completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on Facility Start-Up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A ORI$1NAL ooo Alaska 0i}& Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. CD1-34 Top Alpine 8151' 7054' TD 11190' 7087' Annulus left open - freeze protected with diese 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certi_fy that the following is true and correct to the best of my knowledge. Questions? Call Brian Robertson 265-6034 Signed Title Drilline Team Leader Date ~' /('~/~ O,~,.~,ester ~ / if' - - INSTRUCTIONS Prepared by Sharon AIIsup-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 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 RECEIVED ,.JUN 2 9 2000 Alaska 0il & Gas Cons. Commission Anchorage Date: 06/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-34 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:04/22/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20333-00 04/22/00 (D1) TD/TVD: 0/0 SUPV: MW: 8.7 VISC: 320 PV/YP: 12/68 0) Drilling ahead @ 1034' APIWL: 15.0 Move rig, level, spot pit modules. N/U diverter system. Aceept rig @ 1530 hrs. Function test diverter. Pre-spud meeting. Spud-drill from 115' to 440' 04/23/00 (D2) MW: 9.6 VISC: 162 PV/YP: 14/43 TD/TVD: 2389/2316 (2389) RIGGING UP TO RUN CASING. SUPV: Drill from 440' to 2389' APIWL: 13.0 04/24/00 (D3) MW: 9.6 VISC: 58 PV/YP: 12/18 TD/TVD: 2443/2369 ( 54) RIH WITH BHA #2. SUPV:SCOTT REYNOLDS APIWL: 10.4 Drill from 2389' to 2443'. Pump sweep and circulate hole clean. Short trip from 2443' to 1070'. A little tight @ 800'. Pump sweep and circulate hole clean. Monitor well, static. Pump dry job. POOH. RIH w/9-5/8" casing. Wash through tight spot from 984' to 1024'. PJSM. Pump cement. Plug bumped and floats held. NU BOPE and test to 250/3500 psi. 04/25/00 (D4) MW: 9.6 VISC: 45 PV/YP: 9/23 TD/TVD: 4011/3703 (1568) DRILLING AHEAD @ 4831' SUPV:SCOTT REYNOLDS APIWL: 6.2 Continue testing BOPE. RIH to 2343'. Circulate and condition mud. Test casing to 2500 psi, good. Drill cement, float equipment and 20' of new hole to 2463'. Circulate and condition mud for LOT. Perform LOT to 16 ppg EMW. Drill from 2463' to 3631'. Pump hivis sweep. Circulate hole clean for wiper trip. Short trip to 2433'. No hole problems. Drill from 3631' to 4011' 04/26/00 (D5) MW: 9.6 VISC: 40 PV/YP: 7/19 APIWL: 5.4 TD/TVD: 6611/5905 (2600) DRLG AT 7300' SUPV:LUTRICK/ROBERTSON Drilling from 4011' to 5630'. Circ sweep. Wiper trip to 3535'. No problems. Pump sweep. Drilling from 5630' to 6611' RECEIVED ,.JUN 2 9 2000 Alaska Oil& Gas Cons. Commission Anchorage Date: 06/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/27/00 (D6) MW: 9.6 VISC: 40 PV/YP: 7/19 APIWL: 5.3 TD/TVD: 7629/6747 (1018) DRLG AT 7940' SUPV:DONALD LUTRICK Drilling from 6611' to 7344'. Circ sweep. Monitor well. POH' to 6392'. No problems. Monitor well. Pump slug. POH. RIH with BHA #3. Circ sweep. Wash from 7248' to 7344'. Drilling from 7344' to 7629' 04/28/00 (D7) MW: 9.7 VISC: 40 PV/YP: 7/24 APIWL: 5.5 TD/TVD: 8420/7107 ( 791) RIH W/ 7" CSG SUPV:DONALD LUTRICK Drilling from 7629' to 8420'. Circ hi-vis sweep. Wiper trip to 6420'. No problems. Circ hi-vis sweep. POH. 04/29/00 (D8) TD/TVD: 8420/7107 ( SUPV:DONALD LUTRICK MW: 9.8 VISC: 39 PV/YP: 10/19 0) PU 3 1/2" DP. APIWL: 6.2 PJSM. RIH w/7" casing. CBU at shoe and 6000' Pump cement. Bumped plug. Install packoff and test to 5000 psi. Test all BOPE to 300/3500 psi. 04/30/00 (D9) MW: 9.2 VISC: 60 PV/YP: 12/25 TD/TVD: 8582/7109 ( 162) DRLG AT 8911' SUPV:DONALD LUTRICK APIWL: 3.4 Finish test BOPE. RIH. Tag stringer at 8224'. Test casing to 3500 psi. OK. BOP drill. Perform 3 stand stripping drill. Drill out float equipment, cement and 20' new formation to 8440'. CBU. Perform 12.5 ppg FIT. Displace well to 9.2 flo-pro. Drilling from 8440' to 8582' 05/01/00 (D10) MW: 9.2 VISC: 52 PV/YP: 11/24 APIWL: 3.6 TD/TVD: 9800/7108 (1218) DRILLING @ 9928. SUPV:DONALD LUTRICK/PAT REILLY Drill from 8582 to 9180'. C/O 200 bbls mud @ 8950. Kick drill. Drill from 9180' to 9800'. C/O 20 bbls mud @ 9368' 05/02/00 (Dll) MW: 9.2 VISC: 48 PV/YP: 11/24 APIWL: 3.8 TD/TVD:10946/7092 (1146) WIPER TRIP. SUPV:DONALD LUTRICK/PAT REILLY Drill from 9800' to 9835'. Circ lo/hi vis sweeps, check flow. Wiper trip, pump out to shoe. CBU. RIH. Drill from 9835' to 10946' 05/03/00 (D12) MW: 9.2 VISC: 27 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:ll190/7086 ( 244) RUNNING COMPLETION. SUPV:DONALD LUTRICK/PAT REILLY Drill from 10946' to 11190'. Circ lo/hi sweeps. Pump out to shoe, 8410'. CBU. RIH. Circ sweep - CBU. Pump seawater and spacer. Displace with seawater. Monitor well for losses, well taking 16.8 bph. POOH to shoe 8410'. Monitor losses, pump slug. POOH. RECEIVED JUN 2 9 2000 & Cons. Commission An orage Date: 06/15/00 ARCO ALASKA INC. WELL S~RY REPORT Page: 3 05/04/00 (D13) MW: 9.6 VISC: 27 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:ll190/7086 ( 0) PICKING UP BHA. SUPV:DONALD LUTRICK/PAT REILLY PJSM. Run 4.5" tubing. Test SSSV to 5000psi. RIH with 4.5" tubing. N/D BOPE. M/U tree and test to 5000 psi. Set packer and test tubing to 3500 psi. PJSM. Freeze protect with diesel. Set BPV, secure well. Release rig @ 2200 hrs. RECEIVED JUN 2 9 2000 Alaska Oil & Gas Cons. Commission i J I J I J I J i J i J i J I J i J I J I i · j I J I J I J i i · J · J · II SURVEY CALCULATION AND FIELD WORKSHEET Job No, 0450-00025 Sidetrack No. Page 1 of 5 ~/·._ [1[~'- I =~l Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig #19 Field ALPINE FIELD ~llrr~~ Well Name & No. PAD CD#1/34 Survey Section Name Definitive Survey BHI Rep. NEWLON / GEHRES WELL DATA Target TVD (F13 Target Coord. N/S Slot Coord. N/S -459.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL D. SS~ Target Description Target Coord. E/W Slot Coord. E/W 2342.00 Magn. Declination 25.840 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 30mD 10m~ Vert. Sec. Azim. 228.52 Magn. to Map Corr. 25.840 Map North to: OTHER ,. SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'r) (F-r) ~ (FT) Per 100 Fr) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT -- 23-APR-O0 GSS 115,00 0,00 0,00 115,00 115.00 0,00 0.00 0,00 0,00 0,00 9 1/2" M1C 1,4 DEG AKO 23-APR-O0 GSS 173,00 0,25 332,00 58,00 173,00 -0,03 0,11 -0,06 0,43 0,43 23-APR-00 GSS 263,00 0,50 .. 172,00 90,00 263,00 0,14 -0.10 -0,10 0,82 0,28 23-APR-O0 GSS 350,00 1,75 154,00 87,00 349,98 0,71 -1,67 0,54 1,48 1,44 23-APR-00 MWD 467,64 4,33 157.31 117,64 467,45 2,62 -7.39 3,04 2,20 2,19 23-APR-00 MWD 557,10 6,90 158,29 89,46 556,47 5,52 -15,50 6,33 2,87 2,87 1,10 23-APR-O0 MWD 647,99 7.69 159,60 90,89 646,62 9,56 -26,27 10,47 0,89 0,87 1,44 23-APR-00 MWD 736.43 7.65 156.99 88.44 734.27 13.55 -37.23 14.83 0.40 -0.05 -2,95 23-APR-00 MWD 826.96 7.39 151.86 90.53 824.02 16.80 -47.91 19.93 0.79 -0.29 -5.67 23-APR-00 MWD 917.36 7.23 148.71 90.40 913.69 19.15 -57..90 25.63 0.48 -0.18 -3.48 23-APR-00 MWD 1006.51 7.27 146.24 89.15 1002.13 20.90 -67.38 31.68 0.35 0,04 -2.77 23-APR-00 MWD 1100.04 7.04 145.84 93.53 1094.93 22.42 -77.05 38.19 0.25 -0.25 -0.43 7.04 145.72 96.36 1190.56 23.92 -86.81 44.83 0.02 0.00 -0.12 23-APR-O0 MWD 1 1 96.40 23-APR-00 MWD 1292.08 6.71 150.92 95.68 ' .1285.55 25.85 -96.54 50,85 0.74 -0.34 5.43 23-APR-00 MWD 1387.17 6.75 175.83 95.09 1380.01 30.43 -106.97 53.95 3.05 0.04 26.20 , 23-APR-00 MWD 1482,78 8.27 202.99 95,61 1474.83 40.05 -118.91 51.68 3.99 1.59 28.41 23-APR-00 MWD 1579.01 10.62 221.51 96.23 1569.77 55,10 -131,93 43.09 3.96 2.44 19.25 23-APR-00 MWD 1672.70 12.56 229.93 93.69 1661,55 73.85 -144.95 29.57 2.74 2.07 8.99 23-APR-00 MWD 1767.14 14,30 234.27 94.44 1753.40 95.73 -158.38 12.25 2.13 1.84 4.60 23-APR-00 MWD. 1863.96 16.95 236.51 96.82 1846,64 121,61 -173,15 -9.23 2.81 2.74 2.31 23-APR-O0 MWD 1958.49 19.79 238.02 94.53 1936.34 15i .04 -189,23 -34.31. 3.05 3.00 1.60 23-APR-O0 MWD 2053.28 22.69 239.39 94.79 2024.69 , 184.83 -207.04 -63.66 3.10 3.06 1.45 23-APR-00 MWD 2148.48 25.67 240.60 95.20 2111.52 223.03 -226.52 -97.43 3.17 3.13 1.27 ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00025 Sidetrack No. Page 2 of 5 · ~ [I [4 '- I =[.-1 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig #19 Field ALPINE FIELD Well Name & No. PAD CD#1/34 Survey Section Name Definitive Survey BHI Rep. NEWLON / GEHRES I~l~r~l~ WELL DATA Target TVD (~-r) Target Coord. N/S Slot Coord. N/S -459.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. ~ 2342.00 Magn. Declination 25.840 Calculation Method MINIMUM CURVATURE Target Direction (oD) Build\Walk\DL per: 100ft~ 30mQ lOmQ Vert. Sec. Azim. 228.52 Magn. to Map Corr. 25.840 Map North to: OTHER SURVEY DATA Storey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'rVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (OD) (OD) (FT) (FT) (F-r) (F--~ (Per lDO FT) Drop (-) Left (-) 23-APR-D0 MWD 2243.54 27.68 241.91 95.06 2196.46 264.65 -247.02 -134.85 2.20 2.11 1.38 24-APR-O0 MWD 2339.00 30.23 243.84 95.46 2279.98 309.40 -268.06 -175.99 2.84 2.67 2.02 · __ 24-APR-D0 MWD 2381.00 30.52 244.75 42.00 2316.22 329.84 -277.27 -195.13 1.30 0.69 2.17 25-APR-O0 MWD 2524.13 29.88 .. 243.21 143.13 2439.92 399.23 -308.85 -259.83 0.70 -0.45 -1.08 6 3/4" M1/XL 1.2 DEG AKO 26-APFI-O0 MWD 2713.65 29.27 242.46 189.72 2604.93 489.95 -351.59 -343.14 0.38 -0.32 -0.40 25-APR-O0 MWD 2903.60 30.72 241.87 189.75 2769.26 582.14 -395.89 -427.01 0.78 0.76 -0.31 25-APR-O0 MWD 3094.33 33.14 241.05 190.73 2931.12 680.44 -444.10 ' -515.61 1.29 1.27 -0.43 25-APR-O0 MWD 3282.66 32.92 239.92 188.33 3089.01 780.86 -494.67 -604.94 0.35 -0.12 -0.60 25-APR-O0 MWD 3472.18 32.33 238.79 189.52 3248.63 881.21 -546.75 -692.85 0.45 -0.31 -0.60 25-APR-O0 MWD 3567.86 33.25 242.95 95.68 3329.08 931.80 -571.94 -738.10 2.54 0.96 4.35 25-APR-O0 MWD 3759.88 32.48 241.91 192.02 3490.36 1032.94 -620:15 -830.47 0.50 -0.40 -0.54 25-APR-O0 MWD 3951.00 31.99 240.43 191.12 3652.03 1132.40 -669.30 -919.77 0.49 -0.26 -0.77 26-APR-O0 MWD 4141.48 31.88 240.27 190.48 3813.68 1231.01 -719.14 -1007.33 0.07 -0.06 -0.08 26-APR-.O0 MWD 4331.38 31.32 239.55 189.90 3975.42 1328.55 -769.03 -1093.43 0.36 -0.29 .0.38 (' 26-APR-O0 MWD 4521.66 32.48 241.63 190.28 ' 4136.97 1426.86 -818.37 -1 i 81.03 0.84 0.61 1.09 26-APR-O0 MWD 4712.24 32.44 243.09 190.58 4297.77 1526.17 -865.82 -1271.63 0.41 -0.02 0.77 ,, 26..APR-O0 MWD 4901.68 31.84 241.56 189.44 4458.18 1624.03 -912.61 -1360.88 0.53. -0.32 -0.81 26-APR-O0 MWD 5092.55 32.75 242.87 190.87 4619.53 1723.10 -960.13 -1451.1 0 0.60 0.48 0.69 ', 26-APR-O0 MWD 5282.87 32.29 241.81 190.32 4780.01 1822.45 -1007.62 -1541.72 0.38 -0.24 -0.56 26-APR-O0 MWD 5473.12 32.92 244.75 190.25 4940.28 1921.55 -1053.69 -1633.28 0.90 0.33 1.55 26-APR-O0 MWD 5664.00 32.58 . 244.39 190.88 5100.82 2020.78 -1098.02 -1726.53 0.21 -0.18 -0.19 26-APR-O0 MWD 5854.00 31.99 242.82 190.00 5261.45 2118.76 -1143.13 -1817.44 ' 0.54 -0.31 -0.83 26-APR-O0 MWD 6045.00~ '31.37 242.01 191.00 5423.99 2216.13 -1189.57 -1906.34 0.39 -0.32 -0.42 26-APR-O0 MWD 6235.00 31.16 241.79 190.00 5586.40 2312.06 -1236.02 -1993.33 O. 13 -0.11 -0.12 i --~ I . J I J i · i · I J I Il i J I J I · i J I J ill · Jl J ii · ii JI iii ~ ii J SURVEY CALCULATION AND FIELD WORKSHEET Jou No. 0450-00025 Sidetrack No. Page 3 of 5 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig #19 Field ALPINE FIELD Wall Name & No. PAD CD#1/34 Survey Section Name Definitive Survey BHI Rep. NEWLON / GEHRES I~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -459.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SS[" Target Description Target Coord. E/W Slot Coord. E/W 2342.00 Magn. Declination 25.840 Calculation Method MINIMUM CURVATURE Target Direction (oD) Build~Walk\DL per: 100ft[~ 30ml'~ 10m~ Vert. Sec. Azim. 228.52 Magn. to Map Corr. 25.840 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (OD) (DO) (FT) (F'r) (FT) (FT) (Per lO0 F~ Drop (-) Left (-) 26-APR-O0 MWD 6426.00 31.42 241.78 191.00 5749.62 2408.61 -1282.91 -2080.74 O. 14 0.14 -0.01 i' -- 27-APR-O0 MWD 6616.00 33.65 242.33 190.00 5909.79 2507.95 -1 330.78 -2171.01 1.18 1.17 0.29 27-APR-O0 MWD 6807.00 33.00 241.64 191.00 6069.38 2609.99 -1380.07 -2263.65 0.39 -0.34 -0.36 27-APR-O0 MWD 6997.00 33.17 240,45 190.00 6228.58 2711.24 -1430.28 -2354.40 0.35 0.09 -0.63 27-APR-O0 MWD 7188.00 32.46 239.50 191.00 6389.10 2812.68 -1482.06 -2444.02 0.46 -0.37 -0.50 27-APR-00 MWD 7282.00 31.80 238.68 94.00 6468.70 2861.82 -1507.74 -2486.91 0.84 -0.70 -0.87 27-APR-00 MWD 7344.00 31.96 237.77 62.00 6521.35 2894.10 -1524.98 '-2514.75 0.82 0.26 -1.47 6 3/4" MlX 1.45 DEG AKO 27-APR-O0 MWD 7371.00 32.73 233.43 27.00 6544.16 2908.43 -1533.14 -2526.66 9.06 2.85 -16.07 27-APR-O0 MWD 7403.91 34.88 228.31 32.91 6571.51 2926.71 -1544.71 -2540.83 10.84 6.53 -15.56 27-APR-00 MWD 7436.00 36.63 221.95 32.09 6597.56 2945.40 -1557.94 -2554.09 12.79 5.45 -19.82 27-APR-00 MWD 7466.00 38.18 217.19 30.00 6521.40 2963.39 -1571 ,.98 -2565.68 10.93 5.17 -15.87 , 27-APR-O0 MWD 7500.00 39.52 213.14 34.00 6847.88 2984.13 -1589.41 -2577.95 8.45 3.94 -11.91 27-APR-O0 MWD 7532.00 40.18 209.06 32.00 6872.45 3003.68 -1606.97 -2588.53 8.43 . 2.06-12.75 27-APR-00 MWD 7562.12 39.96 208.36 30.12 6895.50 3021.92 -1623.97 -2597.84 1.66 -0.73 -2.32 27-APR-O0 MWD 7595.00 40.12 208.57 32.88 6720.67 3041.79 -1642.57 -2607.93 0.64 0.49 0.64 27-APR-O0 MWD 7627.00 39.98 209.62 32.00 6745.17 3061.21 -1660.56 -2617.94 2.16 -0.44 3.28 28-APR-00 MWD 7658.00 39.92 208.60 31.00 6768.93 3079.98 -1677.95 -2627.62 2.12 -0.19 -3.29 28-APR-O0 MWD 7690.00 40.03 209.56 32.00 6793.43 3099.37 -1695.92 -2637.61 1.96 0.34 3.00 28-APR-O0 MWD 7722.00 41.47 206.93 32.00 '6817.70 3118.96 -1714.32 -2647.49 7.00 4.50 -8.22 . , 28-APR-O0 MWD 7753.00 43.41 204.00 31.00 6840.53 3138.20 -1733.20 -2656.47 8.93 6.26 -9.45 28-APR-00 MWD 7784.00 45.34 201.08 31.00 6862.74 3157.68 -1753.22 -2684.77 9.06 6.23 -9.42 28-APR-O0 MWD 7817.00 47.43 198.15 33.00 6885.50 3178.58 -1775.73 -2672.78' 9.02 6.33 -8.88 28'-APR-O0 MWD 7847.00 49.54 195.37 30.00 6905.39 , 3197.67 -1797.23 -2679.25 9.88 7.03 -9.27 28-APR-O0 MWD 7880.00 52.28 192.25 33.00 6926.20 3218.71 -1822.10 -2685.35 11.08 8.30 -9.45 SURVEY CALCULATION AND FIELD WORKSHEETJob No. 0450-00025 Sidetrack No.~ Page 4 of 5 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig #19 Field ALPINE FIELD Well Name & No. PAD CD#1/34 Survey Section Name Definitive Survey BHI Rep. NEWLON / GEHRES WELL DATA Target 'I'VD (FT) Target Coord. N/S Slot Coord. N/S -459.00 Grid Correction Target Description Target Coord. E/W Slot Coord. E/W 2342.00 Target Direction Build\Walk\DL per: lOOft[~ 30m~ lOm~ Vert. Sec. Azim. 0.000 Depths Measured From: RKB ~ MSL~ SS[- Date Survey Depth 28-APR-O0 7912.OO 7942.00 28-APR-O0 7975.OO 28-APR-O0 8007.01 28-APR-00 8038.00 28-APR-O0 8071.00 28-APR-O0 8103.00 28-APR-O0 8133.00 28-APR-O0 8164.00 28-APR-O0 .8197.00 28-APR-O0 8228.00 28-APR-O0 8260.00 28-APR-O0 8292.00 28-APR-O0 8324.00 26-APR-O0 8352.00 30-APR-O0 8485.66 30-APR-O0 8577.91 01-MAY-O0 8671.00 01 -MAY-O0 8764.00 01 -MAY-O0 8856.00 01-MAY-O0 8950.00 9041.00 01 9136.00 01 -MAYO0 9227.00 (DO) 228.52 SURVEY DATA Hole Course Vertical Total Coordinate Direction Length 'rVD Section N(+) / S(-) E(+) / W(-) (DO) (FT) iF'r) 189.73 32.00 6945.15 3239.15 -1 647.41 -2690.25 186.28 30.00 6961.74 3258.14 -1872.15 -2693.72 1 64.65 33.00 6978.87 3278.74 -1900.23 -2696.40 181.78 32.01 6994.66 3298.32 -1928.03 -2697.96 180.09 30.99 7009.21 3316.77 -1955.38 -2698.40 178.66 33.00 7023.68 3336.17 -1985.04 -2698.07 177.15 32.00 7036.65 3354.73 -2014.27 '-2697.00 173.99 30.00 7047.89 3371.48 -2041.99 -2694.85 172.72 31.00 7058.60 3388.09 -2070.89 -2691.48 33.00 7068.95 3405.14 -2101.87 -2686.84 31.00 7077.72 3420.14 -2131.04 -2681.07 165.71 32.00 7085.95 3434.66 -2161.11 -2673.88 162.28 32.00 7093.03 3448.08 -2191.10 -2665.27 160.77 32.00 7098.58 3460.39 -2220.98 -2655.28 157.48 28.00 ' 7101.95 3470.17 -2246.95 -2645.38 151.52 133.66 7108.31 3508.88 -2367.35 -2587.93 , 150.83 92.25 7109.47 3527.09 -2448.16 -2543.46 151.45 93.09 7112.86 3547.41 -2529.63 -2498.56 150.54 93.00 7116.53 3567~48 -261.0.90 -2453.50 150.15 92.00 7118.67 3586.33 -2690.83 -2408.00 150.49 94.00 7119.18 3605.55 -2772.49 -2361.45 152.11 91.00 7119.27 3625.68 -2852.31 -2317.75 150.28 95.00 7118.79 3646.53 -2935.55 -2271.98 149.94 91.00 7117.43 3664.81 -3014.43 -2226.64 Magn. Declination 25.840 Magn. to Map Corr. 25.840 Calculation Method MINIMUM CURVAT'URE Map North to: OTHER Build Rate Walk Rate Build (+) Right (+) Drop (-) Left (-) 8.72 -7.87 9.07 -11.50 5.73 -4.94 4.64 -8.97 4.94 -5.45 7.45 -4.33 5.44 -4.72 6.93 -10.53 4.87 -4.10 7.12 -7.45 4.23 -9.29 5.63 -5.22 7.50 -10.72 10.03 -4.72 Comment 10.46 -11.75 4.08 -4.46 -1.58 -0.75 -1.40 0.67 1.03 -0.98 0.97 -0.42 4 3/4" MIX 1.2 DEG AKO 1.23 0.36 -0.71 1.78 1.41 -1.93 -0.23 -0.37 ' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00025 Sidetrack No.~ Page 5 of 5 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig #19 Field ALPINE FIELD Well Name & No. PAD CD#1/34 Survey Section Name Definitive Survey BHI Rep. NEWLON / GEHRES ~ilrr~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -459.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS[- Target Description Target Coord. E/W Slot Coord. E/W 2342.00 Magn. Declination 25.840 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m[~ lOml-I Vert. Sec. Azim. 228.52 Magn. to Map Corr. 25.840 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Fq (DD) (OD) (FT) ~ (FT) (FT) (Per 100 F~ Drop (-) Left (-) 01-MAY-O0 MWD 9320.00 92.02 150.53 93.00 7115.18 3683.68 -3095.14 -2180.49 1.51 1.37 0.63 01 - MAY-O0 MWD 9414.44 91.23 151.02 94.44 7112.50 3703.72 -3177.52 -2134.40 0.98 -0.84 0.52 ( -- 01-MAY-00 MWD 9506.00 89.49 ..150.20 91.56 7111.93 3722.90 -3257.29 -2089.47 2.10 -1.90 -0.90 , 01-MAY-O0 MWD 9598.00 90.62 149.54 92.00 7111.84 3741.00 -3336.86 -2043.29 1.42 1.23 -0.72 01 -MAY-00 MWD 9691.00 91.23 150.13 93.00 7110.34 3759.25 -3417.26 -1996.56 0.91 0.66 0.63 01 -MAY-00 MWD 9782.00 90.31 149.34 91.00 7109.12 3776.94 -3495.84 -1950.70 1.33 -1.01 -0.87 02-MAY-O0 MWD 9874.00 91.40 149.34 92.00 7107.74 3794.21 -3574.97 -1903.79 1.18 1.18 0.00 02-MAY-00 MWD 9967.00 89~66 149.90 93.00 7106.88 3812.11 -3655.20 -1856.76 1.97 -1.87 0.60 02-MAY-O0 MWD 10057.00 90.93 150.62 90.00 7106.42 3830.43 -3733.34 -1812.12 1.62 1.41 0.80 02-MAY-O0 MWD 10149.00 91.4i 149.17 92.00 7104.54 3848.57 -3812.91 -1765.98 1.66 0.52 -1.58 02-MAY-00 MWD 10241.00 91.40 149.91 92.00 7102.29 3866.15 -3892.19 -1719.36 0.80 -0.01 0.80 02-MAY-O0 MWD 10334.00 90.86 149.80 93.00 7100.45 3884.42 -3972.60 -1672.67 0,59 -0.58 -0.12 02-MAY-O0 MWD 10425.00 90.55 150.39 91.00 7099.33 3902.68 -4051.47 -1627.30 0.73 -0.34 0.65 02-MAY-O0 MWD ' 10517.00 91.54 148.25 92.00 7097.65 3919.92 -4130.58 -i 580.37 2.56 1.08 -2.33 (' _ 02-MAY-00 MWD 10611.00 90.1,4 1 50.40 94.00 ,7096.28 3937.53 -4211.41 -1532.42 2.73 -1.49 2.29 02-MAY-O0 MWD 10704.00 91.06 148.81 93.00 7095.30 3955.41 -4291.62 -1485.37 1.98 0.99 -1.71 02-MAY-00 MWD 10796.00 91.27 148.51 92.00 7093.43 3971.61 -4370,18 -1437.53 0.40 0.23 -0.33 · 02-MAY-O0 . MWD 10886.57 90.31 151.77 90.57 7092.18 3989.85 -4448.71 -1392.45 3.75 -1.06 3.60 ., 03-MAY-O0 MWD 10982.00 91.58 151.56 95.43 7090.61 4011.54 -4532.69 '-1347.16 1.35 1,33 -0.22 03-MAY-00 MWD 11073.00 90.79 150.95 91.00 7088.73 4031.60 -4612.46 -1303.41 1.10 -0.87 -0.67 03-MAY-O0 MWD 11134.00 90.93 , 150.26 61.00 7087.81 4044.37 -4665.60 -1273.47 1.15 0.23 -1.13 03-MAY-O0 MWD 11190.00 90.93 150.26 56.00 7086.90 4055.76 -4714.22 -1245.70. 0.00 0,00 0.00 Projected Data - NO SURVEY ANADRILL SCHLUMBERGER Survey report Client ................... :. ARCO Alaska, Inc. Field .................... : Coville River Well ..................... : CD1-34 API number ............... : 50-103-20333-00 Engineer ................. : Dammeyer Rig: ..................... : Doyon 19 State: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 56.10 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point--- Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 151.93 degrees 3-May-2000 13:17:35 Page 1 of 5 OR!G NAL Spud date ................ : 22-Apr-00 Last survey date ....... ...: 03-May-00 Total accepted surveys...: 118 MD of first survey ....... : 0.00 ft MD of last survey ........ : 11190.00 ft Geomagnetic data -- Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 22-Apr-2000 Magnetic field strength..: 1144.65 HCNT Magnetic dec (+E/W-) ..... ,.: 25.84 degrees Magnetic dip ............. : 80.48 degrees MWD survey Reference Criteria Reference G ............ '..: 1002.68 mGal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G..; ........ : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.84 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.84 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N)...' ..... : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6_0C_07] ANADRILL SCHLUMBERGER Survey Report 3-May-2000 13:17:35 Page 2 of 5 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0.00 2 115.00 0.00 0.00 3 173.00 0.25 332.00 4 263.00 0.50 172.00 5 350.00 1.75 154.00 Course length (ft) 0.00 115.00 58.00 90.00 87.00 6 467.64 4.33 157.31 7 557.10 6.90 158.29 8 647.99 7.69 159.60 9 736.43 7.65 156.99 10 826.96 7.39 151.86 117.64 89.46 90.89 88.44 90.53 11 917.36 7.23 148.71 12 1006.51 7.27 146.24 13 1100.04 7.04 145.84 14 1196.40 7.04 145.72 15 1292.08 6.71 150.92 16 1387.17 6.75 175.83 17 1482..78 8.27 202.99 18 1579.01 10.62 221.51 19 1672.70 12.56 229.93 20 1767.14 14.30 234.27 90.40 89.15 93.53 96.36 95.68 95.09 95.61 96.23 9.3.69 94.44 21 1863.96 16.95 236.51 22 1958.49 19.79 238.02 23 2053.28 22.69 239.39 24 2148.48 25.67 240.60 25 2243.54 27.68 241.91 96.82 94.53 94.79 95.20 95.06 26 2339.00, 30.23 243.84 27 2381.00 30.52 244.75 28 2524.13 29.88 243.21 29 2713.85 29.27 242.46 30. 2903.60 30.72 241.87 95.46 42.00 143.13 189.72 189.75 TVD Vertical Displ Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 115.00 0.00 0.00 0.00 0.00 173.00 -0.13 0.11 -0.06 0.13 263.00 0.05 -0.10 -0.10 0.14 349.98 1.73 -1.67 0.54' 1.76 At Azim (deg) 0.00 0.00 332.00 223.04 162.17 467.45 7.95 -7.39 3.04 7.99 157.63 556.47 16.65 -15.50 6.33 16.74 157.78 646.62 28.11 -26.27 10.47 28.28 158.27 734.27 39.83 -37.23 14.83 40.08 158.28 824.02 51.66 -47.91 19.93 51.89 157.41 913.69 63.15 -57.90 25.63 63.32 156.12 1002.13 74.36 -67.38 31.68 74.46 154.82 1094.93 85.95 -77.05 38.19 85.99 153.64 1190.56 97.70 -86.81 44.83 97.70 152.69 1285.55 109.11 -96.54 50.85 109.11 152.23 1380.01 1474.83 1569.77 1661.55 1753.40 1846.64 1936.34 2024.69 2111.52 2196.46 119.78 -106.97 129.24 -118.91 136.69 -131.93 141.82 -144.95 145.51 -158.38 53.95 51.68 43.09 29.57 12.25 148.44 -173.15 -9.23 150.83 -189.23 -34.31 152.73 -207.04 '-63.66 154.03 -226.52 -97.43 154.51 -247.02 -134.85 119.81 129.66 138.79 147.94 158.85 2279.99 2316.22 2439.93 2604.93 2769.26 173.39 192.32 216.61 246.58 281.44 153.23 156.51 161.91 168.47 175.58 183.05 190.28 197.09 203.27 208.63 153.72 -268.06 -175.99 320.67 213.29 152.84 -277.27 -195.13 339.05 215.14 150.26 -308.85 -259.83 403.60 220.07 148.77 -351.59 -343.14 491.28 224.30 ,148.39 -395.89 -427.01 582.30 227.17 DLS (deg/ 100f) 0.00 0.00 0.43 0.82 1.48 2.20 2.87 0.89 0.40 0.79 0.48 0.35 0.25 0.02 0.74 3.05 3.99 3.96 2.74 2.13 2.81 3.05 3.10 3.17 2.20 2.84 1.30 0.70 0.38 0.78 Srvy tool type TIP MWD GYR GYR MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-.axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 3-May-2000 13:17:35 Page 3 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 3094.33 33.14 241.05 190.73 32 3282.66 32.92 239.92 188.33 33 3472.18 32.33 238.79 189.52 34 3567.86 33.25 242.95 95.68 35 3759.88 32.48 241.91 192.02 TVD depth (ft) 2931.12 3089.0~ 3248.63 3329.08 3490.36 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) (ft) 149.25 -444.10 -515.61 680.50 151.83 -494.67 -604.94 781.44 156'.41 -546.75 -692.85 882.59 157.35 -571.94 -738.10 933.75 156.43 -620.15 -830.47 1036.47 At DLS Srvy Azim (deg/ tool (deg) 100f) type 229.26 1.29 MWD 230.73 0.35 MWD 231.72 0.45 MWD 232.23 2.54 MWD 233.25 0.50 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 36 3951.00 31.99 240.43 191.12 3652.03 37 4141.48 31.88 240.27 190.48. 3813.68 38 4331.35 31.32 239.55 189.90 3975.42 39 4521.60 32.48 241.63 190.22 4136.91 40 4712.24 32.44 243.09 190.64 4297.77 157.77 160.55 164.05 166.37 165.61 -669.30 -919.77 -719.14 -1007.34 -769.02 -1093.43 -818.35 -1181.00 -865.82 -1271.63 1137.52 1237.70 1336.78 1436.82 1538.41 233.96 0.49 MWD 234.48 0.07 MWD 234.88 0.36 MWD 235.28 0.84 MWD 235.75 0.41 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 41 4901.68 31.84 241.56 189.44 42 5092.55 32.75 242.87 190.87 43 5282.87 32.29 241.81 190.32 44 5473.12 32.92 244..75 190.25 45 5664.00 32.58 244.39' 190.88 4458.18 4619.53 4780.01 4940.28 5100.82 164.90 -912.61 -1360.88 164.38 -960.13 -1451.10 163.64 -1007.62 -1541.73 161.20 -1053.68 -1633.28 156.45 -1098.02 -1726.54 1638.55 1739.99 1841.80 1943.67 2046.11 236.15 0.53 MWD 236.51 0.60 MWD 236.83 0.38 MWD 237.17 0.90 MWD 237.54 0.21 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 46 5854.00 31.99 242.82 190.00 5261.45 47 6045.00 31.37 242.01 191.00 5423.99 48 6235.00 31.16 241.79 190.00 5586.40 49 6426.00 31.42 241.78 191.00 5749.62 50 6616.00 33.65 242.33 190.00 5909.79 153.47 -1143.13 -1817.44 152.61 -1189.57 -1906.34 152.66 -1236.01 -1993.33 152.91 -1282.91 -2080.74 152.68 -1330.78 -2171.01 2147.05 2247.05 2345.44 2444.45 2546.43 237.83 0.54 MWD 238.04 0.39' MWD 238.20 0.13 MWD 238.34 0.14 MWD 238.49 1.18 MWD 6-axis 6-axis 6-axis 6-axis 6-axis' 51 6807.00 33.0'0 241.64 191.00 6069.38 52 6997.00 33.17 240.45 190.00 6228.58 53 7188.00 32.46 239.50 191.00 6389.10 54 7282.00 31.80 238.68 94.00 6468~70 55 7344.00 31.96 237.77 62.'00 '6521.35 152.57 -1380.06 -2263.65 154.17 -1430.28 -2354.40 157.70 -1482.06 -2444.02 160.1'7 -1507.74 -2486.91 162.29 -1524.98 -2514.75 2651.17 2754.79 2858.27 2908.27 2941.01 238.63 0.39 MWD 238.72 0.35 MWD. 238.77 0.46 MWD 238.77 0.84 MWD 238.77 0.82 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 56 7371.00 32.73 233.43 27.00 57 7403.91 34.88 228.31 32.91 58 7436.00 '36.63 221.95 32.09 59 7466.00 38.18 217.19 30.00 60 7500.00 39.52 213.14 34.00 6544.16 6571.51 6597.56 6621.40 6647.88 163.88 -1533.14 -2526.66 167.42 -1544.71 -2540.83 172.85 -1557.93 -2554.09 179.79 -1571.98 -2565.68 189.40 -1589.41 -2577.95 2955.42 238.75 9.06 2973.54 238.70 '10.84 2991.75 238.62 12.79 3008..96 238.50 10.93 3028.54 238.34 8.45 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 3-May-2000 13:17:35 Page 4 of 5 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 61 7532.00 40.18 209.06 62 7562.12 39.96 208.36 63 7595.00 40.12 208.57 64 7627.00 39.98 209.62 65 7658.00 39.92 208.60 66 7690.00 40.03 209.56 67 7722.00 41.47 206.93 68 7753.00 43.41 204.00 69 7784.00 45.34 201.08 70 7817.00 47.43 198.15 71 7847..00 49.54 195.37 72 7880.00 52.28 192.25 73 7912.00 55.07 189 73 74 7942.00 57.79 186.28 75 7975.00 59.68 184.65 76 8007.01 61.23 181.78 77 8038.00 62.76 180.09 78 8071,00 65.22 178.66 79 8103.00 66.96 177.15. 80 8133.00 69.04 173.99 81 8164,00 70.55 172.72 82, 8197.00 72.90 170.26 83 8228.00 74.21 167.38 84 8260.00 76.01 165.71 85 8292.00 78.41 162.28 86 8324.00 81.62 160,77 87 8352.00 84.55 157.48 88 8485.66 90.00 151.52 89 8577.91 88.56 150.83 90 8671.00 87.26 151.'45 32.00 30.12 32.88 32.00 31.00 32.00 32.00 31.00 31,00 33.00 30.00 33.00 32.00 30.00 33.00 32.01 30.99 33,00 32.00 30.00 31.00 33.00 31.00 32.00 32.00 32.00 28,00 133.66 92.25 93.09 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 6672.45 6695.50 6720.67 6745.17 6768.93 6793.46 6817.70 6840.58 6862.74 6885.50 6905'~39 6926.20 6945.16 6961.75 6978.87 6994.66 7009.21 7023.68 7036,65 7047.89 7058.60 7068.95 7077.73 7085.95 7093.03 7098.58 7101.95 7108.31 7109.47 7112.87 199.91 -1606.97 -2588.53 210.53 -1623.97 -2597.85 222.19 -1642.57 -2607.93 233.36 -1660.56 -2617.94 244.15 -1677.95 -2627.62 255.30 -1695.91 -2637.62 266.89 -1714.31 -2647.49 279.32 -i733.20 -2656.48 293.09 -1753.22 -2664.77 309.17 -1775.72 -2672.78 325.10 -1797.23 -2679.25 344,18 -1822.10 ~2685.35 364.20 -1847.40 -2690.25 384.40 -1872.15 -2693.72 407.91 -1900.22 -2696,40 431.71 -1928.02 -2697.96 455.64 -1955.38 -2698.40 481.96 -1985.03 -2698.07 508.2~'-2014.26 -2697.00 533.73 -2041.99 -2694.85 560.82 -2070.89 -2691.48 590~34 -2101.87 -2686.84 618.79 22131.03 -2681.07 648.71 -2161.1'1 -2673.88 679.22 -2191.09 -2665.27 710.29 -2220.98 -2655.28 737.86 -2246.94 -2645.'38 871.12 -2367.34 -2587.94 963.36 -2448.15 -2543.46 1056.37 -2529.62 -2498.56 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 3046.77 238.17 8.43 MWD 3063.67 237.99 1.66 MWD 3082.09 237.80 0.64 MWD 3100.17 237.61. 2.16 MWD 3117.68 237.44 2.12 MWD 3135.78 237.26 3154.06 237.08 3171.88 236.88 3189,80 236.66 3208.89 236.40 1.96 7.00 8.93 9.06 9.00 3226.21 236.15 9.90 3245.17 235.84 11.08 3263.49 235.52 10.78 3280.41 235.20 13,19 3298.70 234.83 7.12 3316.06 234.45 9.18 3332.40 234.07 6.90 3349.62 233.66 8.41 3366,17 233.25 6.94 3381,11 232.85 11.98 3395.97 232.42 6.21 3411.30 231.96 10.04 3424.83 231.52 9.86 3438.02 231.05 7.55 3450,30 230.58 12.86 3461,69 230.09 11.06 3470.85 229.66 15.67' 3507.38 227.55 6.04 3530,25 226.09 1.73 3555.53 224.65 1,55 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 3-May-2000 13:17:35 Page 5 of 5 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) '(ft) TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 91 8764.00 88.22 150.54 93.00 7116.53 92 8856.00 89.11 150.15 92'.00 7118.68 93 8950.00 90.27 150.49 94.00 7119.19 94 9041.00 89.62 152.11 91.00 7119.27 95 9136.00 90.96 150.28 95.00 7118.79 96 9227.00 90.75 149.94 91.00 7117.43 97 9320.00 92.02 150.53 93.00 7115.19 98 9414.44 91.23 151.02 94.44 7112.51 99 9506.00 89.49 150.20 91.56 7111.93 100 9598.00 90.62 149.54 92.00 7111.84 101 9691.00 91.23 150.13 93.00 102 9782.00 90.31 149.34 91.00 103 '9874.00 91.40 149.34 92.00 104 9967.00 89.66 149.90 93.00 105 10057.00 90.93 150162 90.00 92.00 92.00 93.00 91.00 92.00 106 10149.00 91.41 149.17 107 10241.00 91.40 149.91 108 10334.00 90.86 149.80 109 10425.00 90.55 150.39 110 10517.00 91.54 148.25 94.00 93.00 92.00 90.57 95.43 111 10611.00 90.14 150.40 112 .10704.00 91.06' 148.81 113 10796.00 91.27 148.51 114 10886.57 90.31 151.77 115 10982.00 91.58 151.56 91.00 61.00 116 11073.00 90.79 150.95 117 11134.00 90.93 150.26 56.00 Last Survey Projected to TD 118 11190.00 90.93 150.26 7110.34 7109.12 7107.75 7106.89 7106.42 7104.55 7102.29 7100.46 7099.34 7097.66 7096.28 7095.31 7093.43 7092~19 7090.61 7088.73 7087.81 7086.91 1149.29 -2610.89 -2453.50 1241.23 -2690.82 -2408.00 1335.18 -2772.49 -2361.45 1426.18 -2852.30 -2317.76 1521.16 -2935.54 -2271.99 1612.10 -3014.43 -2226.64 1705.03 -3095.13 -2180.49 1799.42 -3177.52 -2134.40 1890.95 -3257.29 -2089.47 1982.88 -3336.86 -2043.29 2075.81 -3417.25 -1996.56 2166.73 -3495.84 -1950.70 2258.63 -3574.97 -1903.79 2351.54 -3655.19 -1856.76 2441.50 -3733.34 -1812.12 2533.42 -3812.91 -1765.99 2625.31 -3892.18 -1719.36 2718.23'-3972.59 -1672.67 2809.18 -4051.47 -1627.30 2901.06 -4130.57 -1580.37 2994.95 -4211.40 -1532.42 3087.86 -4291.61 -1485.37 3179.69 -4370.17 -1437.53 3270.20 -4448.70 -1392.45 3365.61 -4532.69 -1347.17 3456.58 -4612.45 -1303.41 3517.56 -4665.59 -1273.48 3573.53 -4714.21 -124'5.70 DLS (deg/ i00f) 3582.80 223.22 1.42 3610.95 221.83 1.06 3641.86 220.42 1.29 3675.27 219.10 1.92 3712.05 217.74 2.39 3747.63 216.45 3786.08 215.16 3827.83 213.89 3869.86 212.68 3912.75 211.48 3957.76 210.30 4003.27 209.16 4050.29 208.04 4099.76 206.93 4149.89 205'.89 4202.02 204.85 4255.03 203.83 4310.37 202.83 4366.06 201.88 4422.58 200.94 0.44 1.51 0.98 2.10 1.42 0.91 1.33 1.18 1.97 1.62 1.66 0.80 0.59 0.73 2.56 4481.54 200.00 2.73 4541.40 199.09 1.98 4600.54 198.21 0.40 46~1.53 197.38 3.75 4728.65 196.55 1.35 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 4793.08 195.78 1.10 MWD 4836.27 195.27 1.15 MWD 4876.02 194.80 0.00 MWD T0ol qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2000 Anadrill IDEAL ID6 0C' 07] 5/3 ]/00 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 203 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-34 ~j[ 20215 M10, CDI~ & IMPULSE 000503 1 CD1-34 20215 ARRAY RES. MD 000503 I 1 CD1-34 20215 ARRAY RES. TVD 000503 I 1 CD1-19A 20177 USlT 000421 . 1 I~r ('~1~! dUN 0 1 2000 SIGNED: ' DATE: Alaska 0ii & Gas Cons. Commissio~ Anchorage Please sign and return one coPy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 12, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well: CD1-34 Dear Sirs: Phillips Alaska, Inc. hereby requests that CD1-34 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Please find attached form 10-403 and other pertinent information-as follows: . 2. 3. 4. 5. 6. 7. Form 10-403 Surface Casing Description Surface Casing Cementing Report Copy of the Daily Drilling Report covering surface casing cementing. Casing and Formation Test Integrity Report (LOT at surface casing shoe). Formation LOT on 9-5/8" x 7" casing annulus. CD1-34 Well Completion Schematic. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, ,, , _, Brian Robertson Senior Drilling Engineer CC. CD1-34 Well File Alpine Files Doug Chester Gracie Stefanescu ANO-382 Anadarko RECEIVED MAY 1 5 001). Alaska Oil & ~s Cons, Anc~h0~'age STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter s~'pended well _ Alter casing _ Repair well _ Plugging _ Time extansion _ Stimulate _ Other_ Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Injection - X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 56' feet 3. Address Exploratonj_ 7. Unit or Property name P. O. Box 100360 Stratigraphlc_ Anchorage, AK 99510-0360 Service__ Colville River Unit 4. Location of well at surface 8. Well number 459' FNL, 2342' FWL, Sec.5, T11 N, RSE, UM CD1-34 At target (7" casing point in Alpine)) 9. Permit number / approval number 2555' FSL, 231' FEL, Sec 6, T11 N, RSE, UM .... per APD 200-43 !At effective depth 10. APl number 50-103-20333-00 At total deplh 11. Field ! Pool 1103' FSL, 1068' FWL, Sec.5, T11 N, RSE, UM ...... per APD Colville River Field/Alpine Oil Pool 12. Present well condition summary Total dapth: measured 11190 feet true vertical 7086 feet Effective depth: measured 11190 feet true vertical 7086 feet Casing Length Size Cemented Measured Depth True verl]oal Depth Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114 Surface 2397' 9.625' 390 sx ASL3, 217 sx Class G 2433' 2365' Production 8376' 7' 137 sx Class G 8410' 7109' CD1-34 is as an open hole production well. It was suspended after being completed wilh 4-1/2' tubing. ~-~ ~ It is intended that the 9-5/8' x 7" annulus be used for injection of associated drilling waste as per the previously applied for [i~ '.~_..; ..?~., ~ %~?' ~= [.~,~ annular waste disposal permit application. MAY 1 § 200 ORIGINAL^jss~a 0ii & Gas Cc--.ns. Commiss~n .Anchorage 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: May 31, 2000 ~6. If proposal was verbally approved Oil ~ Gas ~ Suspended Name of approver Date approved Service ~ i17. I hereby certify that the foregoing Is true and correct to the best of my knowledge. iSigned ,~~~7~ -~V' ]~)' ~-"~'~ ~'4~ Title: Drilling Team Leader Date FOR COMMISSION USE ONLY iConditions of approval: Notify Commission so representative maywitness JAppro~.~,~ I Plug Integrity_ BOP Test__ Location clearance_i .,~,,,-t,~ Mechanical Integrity Test_ Subsequent form required 10- ~._I~.~Ci~ ~')O~-- ' ;'~iGiI~I~L ~/~N~LJ ~ '~ Commissioner Date !Approved by o.rd..er of the...Com.m.!.s..sion ...~ .~ ........... ;~";,~,' Seamount. o~o,~e6 Form 10-403 Rev 06/15/88 o SUBMIT IN TRIPLICATE Casing Detail Well: CD1-34 9 5/8" Sur[ace Casin.q Date: 4/24/00 ARCO Alaska, Inc. Subsidiary of Alla~ Subsidiary of AlJanlJc Richfield Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS 'Doyon 19 RKB to LDS 36.60 FMC Gen V Hanger 2.60 36.60 Jts 3 to 57 55 Jts 9-5/8" 36# J-55 BTC Csg 2314.77 39.20 Davis Lynch Float Collar 1.50 2353.97 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 76.18 2355.47 Davis Lynch Float Shoe 1.80 2431.65 2433.45' TD 12 1/4" Surface Hole 2443.45 RUN TOTAL 33 BOWSPRING CENTRALIZERS - I per jt on Jt #1 - ~ 2 (On stop rings of Jt #1 & #2) #14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40 42, 44, 46, 48, 50, 52, 54 7 Jts left in pipe shed #58 - #64 Use Best-o-Life 2000 pipe dope Remarks: Up Wt - k Dn Wt - k Block Wt - 70 Supervisoc S. Reynolds/P. Reilly ,dl IP' ARCO Alaska, Inc. Cementing Details Well Name: CD1-34 Report Date: 04/24/2000 Report Number: 1 Ri~l Name: Doyen 19 AFC No.: 953C06 Field: Alpine Centralizers State type used, inten/als covered and spacing Comments: Used 33 9-5/8" bow spring I per jt on Jt #1 - #12 & 1 every other Joint to surface. centralizers. Mud Weight: PV(prior cofld): PV(after cond): I YP(prior cond}: YP(after cofld): Comments: 9.6 14 12I 36 18 Gels before: Gels after: Total Volume Cimulated: 40-48-51 7-26-34 838 bbl8 Wash ' 0 Type: Volume: Weight: Comments: GELH20 40 bbls 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 50 bbls 10.5 Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III LiteI 70 390 10.6 4.44 Additives: 30% D53, 0.6% D46,1.5% D79,1.5% S1, 50% D-124, 9% D44 Additives: 0.2% D46, 0.3% D65,1% 51 Dieplecement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 8 bpm 7.1 bpm 160k Reciprocation length: Reciprocation speed: Str. Wt. Down: 40' 10 fpm 145k Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 162 bbls 163 bbls 74739 lbs Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:4-24-00 yes yes Time:IT:21 Remarks:Nut plug In spacer showed up O surfaco 53 bbls over estimated pumping volumo (for gauge hole}. Washout calculated to bo 33% over gauge bolo. Started to get good 10.S ppg cement back 132 bbls Into rig displacement; therefore, asfimatod good cement returns O 30 bbls. Hsd full roturne throughout cement Job. Cement Company: I Rig Contractor: IApproved By: DS IDOYON J Scott Reynolds Daily Drilling Report ARCO Alaska, Inc. AFC No. I Date Rpt No I Rig Accept - hrs Days Since Accept/Est: 2.364 / 2.6 998C06 ~ 04/24/2000 3 104/22/2000 03:30:00 Rig Relase - hrs: I IPM Well: C01-34 Depth (MD/'rVD) 2443/2369 Prev Depth MD: 2389 Progress: 54 Contractor: DOYON Daily Cost $ 203819 Cum Cost $ 507385 Est Cost To Date $ 450000 RI~I Name: Doyen 19 Last Cs~l: none Next Cs~: 9 5/8 5436'. Shoe Test: Operation At 0030: RIH with BHA #2. Upcoming Operations: Casing tesS - drill out shoe & 20' new hole - LOT MUD DATA DRILLING DATA BIT DATA EH&S ' DRILLS/BOP DATA :, "" ,,,., MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVER~ LAST BOP/DRILL SPUD 2443 I N TST 04/1712030 04/25/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6ppg 12 114 04/1712000 04/13/2000 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 88sqc STC Y SPACE 04/09/2000 03/0Ti2000 PV/YP SO Wl' TYPE TYPE TYPE -. :?~ '. ?':¥ ;:' ;i:.~;-~:-' ';..i~.~ i.'FUE~i~W~TE R!i~!~:i:'~-:?i: :i'i' '7:!"i.: :-~ '::::::': 7"~ 12 / 18 Lubetex , GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 4893 ? / 26 / 34 LR9568 503 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1625 10.4 2443 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN -' 'i' ;'"":' : -' '"i':-:' ::./.'..-i:::i"!."'??i:."~:?.:. POTABLE WATER 110 mi/30 min 116 : ' · '.. IN;JE~TION~ii~ '/:;~:'.¥:!' USED - BBLS .,, : SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL " .. WEATHER &'.:. ' 9.5% 2328 CD1-23 'PERSONNEL:DATA :' ', · : HOLE VOLUME PUMP PRES I ADT/AST ADT/AST SOURCE WELL TEMP oF 0 179bbl 1700 ~ 2000 1 J 21.2 / 9.1 / CD1-54 MBT PUMP NO WeB 2 WeB 2 RATE (bpm) WIND SPEED 0 26 ,1121 I s-~s- 3.s ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION ° 8 8.s 16.01 I 208- 278 1200 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F 0.03 7.8% 8o 1801 I 0.546 Water Base Muds 1463 PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 1 670 28813391 I 101121121191 I IIIII 6o Other 125 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 28 $12114 III o .PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL $ $26666 I I I s 141 RG I A I I I 1648 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 14 Mi 9.61 I I E 11 I WTI TD I I I 19848 PERSONNEL TOTAL 46 BHA DESCRIPTION 112 114 STC FGSTC bit, Nevsdrill M1 1.4, DCSNM, stab NM, mwd, UBHO sub, DCNM*2, stab NM, xo, HWDP*3, Jars, HWDP*26. DRILLPIPE DATA .... REA NO 1 OD ID WEIGHT GRADE' CONNECTION cLASs 2 LENGTH BHA LENGTH 1170.49 5 4.26 19.5 G105 4-112 IF PREM DATE LAST 5 3.00 49.3 HWDP 4-112 IF PREM 860.33 INSPECTED: HOURS ON JARS: 247OUJ - 21.2 TIME J END I HOURS ePS CODE I HOLE SECT I PHASE ePS I .:. OPERATIONS FROM 0000 ~".0000 ..... .. 12:00 AM 01:00 AM 1.00 DRIL SURF Meldng Hole Drill f/2389' t/2445'. ART=0.7 hrs; AST=0.0 hrs. 01:00 AM 02:00 AM 1.03 CIRC SURF Casing and Pump sweep and circulate hole clean. Cementing 02:00 AM 03:00 AM 1.03 WIPERTRP SURF Casing and Short trip f/2443' t/1070'. No Problems. Cementing 03:00 AM 04:00 AM 1.03 CIRC SURF Casing and Pump sweep and circulate hole clean. Monitor well - static. Cementing Pump dry job. 04:00 AM 05:30 AM 1.$0 TRIP_OUT SURF Casing and POOH to BHA. A little tight ~ 800' Cementing 05:30 AM 07:00 AM 1.50 BHA SURF Casing and LD BHA. Cementing 07:00 AM 08:30 AM 1.50 PREP SURF Casing and RU casing slips - elevators & casing tonga. Cementing Daily Drilling Report: C01-34 04/24/2000 Page I 08:30 AM 12:00 PM 3.80 RUN_COG 12:00 PM 02:30 PM 2.50 CIRC 02:30 PM 03:00 PM 0.50 OTHER 03:00 PM 03:30 PM 0.50 CIRC 03:30 PM 05:30 PM 2.00 CEMENT 0S:30 PM 07:30 PM 2.00 OTHER 07:30 PM 08:30 PM 1.00 BOPE 08:30 PM 09:30 PM 1.00 OTHER 09:30 PM 10:30 PM 1.00 BOPE 10:30 PM 11:00 PM 0.S0 PREP 11:00 PM 12:00 AM 1.00 BOPE 24.00 SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF Casing end Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Other Other Other Other RIH w/9-S/8" casing. Wash through fight spot f/984' t/1024'. MU casing hanger and land hangar. Circulate and condition mud for camont Job. LD franks flllup tool and blow down top drivo. RU cement head. Circulata while holding PJSM. Pump 40 bus pre-flush & 2 bbls water to fill lines. Dowell pressure test cement lines. Drop btm plug - pump $0 bbla spacer with nut plug - pump 310 bbla lead. Drop top plug pump 48 bbls tail. Wash up with 20 bbls water and hand over to rig for displacement. Rig displaced with 163 bbls mud. Plug bumped and floats held. CIP O 17:21 hrs. LD canmnt head - landing Joint- and rig down casing equipment. Flush stack. ND riesr - flow lines - and Hydril. MU FMC Uni Head. Test to 1000 psi. NU BOPE. MU double valve on lower annulus. RU to test BOPE. Install test plug - fill choke and stack. Test BOPE. All equipment end choke manifold to 250/3800 psi except annular preventer which was tested to 250/2500 psi. Supewisor. SCOTT REYNOLDS Daily Drilling Report: CD1-34 04/24/2000 Page 2 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-34 Reason(s) for test: Date: 4/25100 Supervisor: S. D. Reynolds [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 518" 36# J-55 BTC CSG Casing Setting Depth: 2,433' TMD Hole Depth: 2,365' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 2,463' TMD 2,387' TVD 30' EMW = Leak-off Press. + Mud Weight = 790 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,365' EMW for open hole section = 16.0 ppg Used cement unit NO Pump output -- 0.0997 bps Fluid Pumped = 1.1 bbls Rig pump used # 2 Fluid Bled Back = 1.0 bbls 2,800 pd I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I i--I--IT i i i I--I--r-i--r-,l~l"l /..1' I.~%,,._ I I'1-1-'1-'1"1'-I i i i i /'"'-= ' '_--i;~ .'~ -.. iTiME LiNE [ONE MINUTE TICKS ] ...... : ._ ~ LEAK-OFF TEST --a--CASING TEST -~- LOT SHUT IN TIME ~! TIMECASINGLINETEST SHUT IN TIME 2,700 2,~0 pa 2,500 psi 2,400 PSI 2,300 psi 2,200 psi 2,100 PSi 2,000 psi 1,900 mi 1,800 PSI 1,700 psi 1,600 psi 1,500 psi 1,:~0 PSI 1,1ilo PSI 800 ps1 700 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 10 20 30 40 50 60 STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE I' o o psi .............. 1 "~ .... ...... l~D'~i ............... ..... ........ , 100 , 700 psi , SHUT IN TIME I SHUT IN PRESSURE 1.0min I : 750 psi 2.0min I ~ 750 psi 3.0min , , 740 psi 4.0min , , 730 psi 50min , , 710psi 6.0min ~ : 690 psi 9.0 mini i 650 psi 10.0 m~n , , 640 ps, CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE I 0 stks 0 psi ............... i....5...s.t k._s. ..... _6..9..0.p_s.i._. ~ 10 stks 1,160 psi ............... ..... ................ i...1..4, st._.k_.s ..... .1.,.5..2_o_p..s.L ................ '. .....( ................ ..... SHUT IN TIME [ SHUT IN PRESSURE 0.0 min lOmin ~ : 2,480 psi ~ 2.0 min ; : 2,480 psi ~/ 50min ~ ~ 2.480nsi ~ 6 0 min ~ ~ 2,480 psi ~ 7 0 min , , 2,460 psi ~ 8.0 rain· , 2,480 psi , ..... - .......... ~ ............. f ................ o .......... 20.0 min ~ ~ 2,430 psi ~ 30.0 mln , , 2,42o DSl , ................ ~ j. r NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Modified by Scoff Reynolds CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-34 Date: 4/30/00 Supervisor: Donald Lutrick Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 518" 36# J-55 BTC CSG X · Casing Setting Depth: 2,433' TMD 2,365' TVD 7" 26# L-80 BTCM CSG TOC Hole Depth: 7,650' TMD 6,764' TVD Mud Weight: 9.8 ppg Length of Open Hole: 4,388' Press 535 psi EMW = .052 X TVD + Mud Weight = 0.052 x 2,365' + 9.8 ppg EMW = 14.2 ppg Pump output = .020 BPS Fluid Pumped = 11.0 bbl *****Used cement unit BLED BACK = 6OO 400 psi / 200 psi / ~ LEAK-OFF TEST '-~- LOT SHUT IN TIME loo~ / o p~l 0.0bbls 1.0bbls 2,0bbl$ 3,0bbls 4.0bbls 5.0bbls 6.0bbls 7.0bbls 8.0bbls 9.0bbls 10,0bbls ll.0bbls 12.0bbls 13.0bbls 14.0bbls 15.0bbls BBLS LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE ............... 0.0 bbls ..... ..5...p..s.i. .... 0.5 bbls 101 psi ................. .L._O..b..b.!.s. ..... ]..3.1...p_s.! .... ................. j...Eb.bJ.s_ ..... ].ET..p..sj__., ................. ._.2...O..b.b. Ls' .... .2.]..7..p..s.!... .................. .2.-..s.~Ls. ..... .2..7..3..p..s.L.. ................. ~:..O..b..b.!.s. ..... E3..8_p.~!... ................... .3....Eb_b. Ls. ..... .4..1..4_p..s.L. ................. _.4.._O..b_b. Ls- ..... .4..s..~..p..s.!_ 4.5 bbls 500 psi ................. ..S...O...b..b.!~.i_..S.]..S..P.~!... ................. ~...S..~.~..s. ..... .s..3..o_p_s.L' 6.0 bbls 535 psi ,_ ............... .S.._S..b..b.I..s. ..... .S..3..0..p_~!... 7.0 bbls 5.3.5 psi .................. .7....s..~..s. ..... .s..~..s_p_s.! .... 8.0 bbls 530 psi i ............................... I . ............................. ., ................. ............. ' ............. 11-'' .............. I I i SHUT IN TIME SHUT IN PRESSURE · 'I ,...o.:.o...m. ~_n. ....................... .3..1..8..p_s.L..; 1.0 min .................................. .3..o..3..e~L.! 2.0 min | 303 psi i · ! ! · 3.0m~n ; ~ 303 ps, ; 40 min ; 312 psi ~ .... -' ........ ! ................................. ,...s.:.o...n.j.,...: .................. ~]..2..p..s.!...i .................. I .............. -!- ............ -I- ............... .I i i . ..... m ..... .d- ............. ~.. ......... 4 i i i i i i i i ~. ............. d.. ............. d... ........ .....A i i i ! L .............. ~. ............. J--..M.......m... , , ! , ! ! , ! , p ..... ...... ............. . ..... ~.......... ....... i I I I I i i i , ! , ! P .............. t- ..............+ ............... I i I i i I i -- .............. i i i i I I I I i i i i r ...... --------'r- ............. II'--- ....... -----.~ i i I i i i i I I I i I- .......... -----i- ........... ----I-- ....... i i I i i I i i I..... ..... .....d... ............ dl ................ I i I I i i I I I I I ....... '"''"'"1' ...... "'''''"~' ......... i i I I i i I i , ! r--......m .... q-..........M..~. ......... .......~ I I I i I i I i I I I I ~..............~.... ........... ~.....m..~ ..... ... I I . , , I kII .... .lliil~llllil. ..... ~ ........... I I I i i i I I I ", I I I i i i I i r ............ T .............................. ~ I I i i i I I ~--~M----------d'-- ........... .--~......... ....... 4 I I I i I I I I i I i L .............. ~ .............. ~. .... . .......... i I I i i i I i I I i I I I I i i I I i I I I ~--- ..... ...~-d...... ........ .~. ..... ----------4 7.0 min~ 307 psi i ~ , i i ....... ~ .... , ............... ~ ................. I ............... . ............. ,"t ................ J 8 I ' ' ' .Om[n = 302 psi , I , , , .............. { ............... .~ ................ ! ............... & .............. + ............... ~ , 0.0 min ~ ' 3O2 psi [ .... ,, ,, ,, ,, .......... ' ................... ~-''----' ..... -- ~ ....... -------'r- ............ -q- ..... --- .... ----~ i i i i ..1..0..O_.m.i.n. i 302 psi ! , , . ~' .. ........ I I I , NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KE' Colville River Field CD1-34 Production Well Completion - As Built il Ii I IltllI~l~ 16" Conductor to 114' Completed 05/04/00 ~II i i l~ 4 1/2" Camco BAL O SSSV N,pple (3 812" ID) at 1710' MD @ 2433' MD / 2365' TVD WRDP-2 SSSV (2.125"1D) w/DB-6 cemented to surface No-Go Lock (3.812" OD) - to be installed later Camco KBG-2 GLM (3.909' ID) E Dummy with 1" BK-2 Latch Packer Fluid mix: 9.6 ~)Do KCI Brine . . - with 2000' TVD diesel cad 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet lube pipe dope Camco KBG-2 GLM (3.909" ID) E Dummy with 1" BK-2 Latch \ \ \ \ & 1' Camco DCK-2 Shear Valve ~~~ ~..,. (sheared out) · at 7949' TOC calculated at 7650' MD Tubing Supended with diesel to lowest GLM Completion MD Tubing Hanger 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1710' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" lB) 3645' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" lB) 5767' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 7828' 4-1/2" tubing joints (2) HES "X" (3.813" lB) 7907' 4-1/2" tubing joint (1) Baker S3 Packer 7949' 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 8024' 4-1/2" 10' pup joint WEG (+/- 63 deg) 8037' Note: thermal break centralizers installed between joints 98 and 162 (total of 65) Well TD at 11190' MD / 7086' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8410' MD / 7109' TVD @ 89 deg ALASILA OIL AND GAS CONSERVATION TONY I~NOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7642 Doug Chester Drilling Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Colville River Unit CD1-34 ARCO Alaska, Inc. Permit No: 200-043 Sur Loc: 459'FNL? 2342'FWL. See. 5, TI 1N, R5E, UM Btmhole Loc. 103'FSL. 1068:FWL, Sec. 5: TllN, R5E, UM Dear Mr. Chester: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by, a valid Formation Integrity Test (FIT). Cementing records, FIT data,, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a ~vell approved for annular disposal on Drill Site CD l must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35:000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one )'ear. The permit to drill does not exempt you from obtaining additional permits required bx' law from other governmental agencies, mad does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF TH~ COMMISSION DATED this [6 '~--' day of April, 2000 dlf/Enclosttrcs cc: Department of Fish & Game I htbitat Section w/o I)eparunent of Em'iromnental Consen'ation w/o encl. ARCO Alaska, Inc.. Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 16, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-34 Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is April 17, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-34 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting field start up. 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: 10. 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Updated conductor 'as built' drawing showing the surface position of CD1-34. Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robe~~on~ Senior Drilling Engineer RECEIVED MAR 2 0 2000 Alaska ~ & ~ Cons. C0mm~i0n An~01age ARCO A~as,~a. ;nc. ~5 a Sdbs,cliary of Atlam~cR~chheidCompany Attachments CC: CD1-34 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~ lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen[ Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559 4. Location of well at surface 7. Unit or properly Name 11. Type Bond (see 20 AAC 25.025) 459' FNL, 2342' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 2555' FSL, 231' FEL, Sec. 6, T11 N, R5E, UM CD1-34 #U-630610 At total depth 9. Approximate spud date Amount 103' FSL, 1068' FWL, Sec. 5, T11 N, R5E, UM 04/17/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properbj 15. Proposed depth (MD and TVD) Property line Alpine CD1- 35 11,214' MD Crosses Sec. 5 to feet 9.9' @ 100' Feet 2560 7,083' TVD feet Sec 6 T11 N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 91 o Maximum surface 2506 psig At total depth ('rVD) 3215 at psig 7000' TVD.SS 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD TVD MD TVD (include sta~le data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pro-installed 12.25" 9.625" 36# J-55 BTC 2431' 37' 37' 2468' 2400' 484 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 8398' 37' 37' 8435' 7111' 137 sx Class G N/A 4.5" 12.6# L-80 I BT-M 7942' 32' 32' 7974' 6980' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural RECEIVED Conductor Surface Intermediate LPinr°eCfrUCti°n ~AP~ ~0 2000ORIGINAL Perforation depth: t~eeaSv~t~cda, j[~l~(a u,, · Cons. Commission 20. Attachments Filing fee X Property plat BOP Sketch - ° ...... ~[-verter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby cert/~//that the foregoing is true and correct to the best of mY knowledge Signed ~--~I/~'.L.~ ~(~'-'~- 3~~ .... Title Drilling Team Leader Date 5 " ' Commission Use Only Permit Number I~/ number ..~__~ - ~-~',~,7 IAPI5o./~_J ~-- .~.~,~3 ._~._3_~' , 4j~O/O'G Iseec°ver'etterf°r I Approval date ~ Other requirements Conditions of approval Samples required Yes ~ Mud log required Yes Hydrogen sulfide measures Yes ~ Directional survey required ~ No Required working pressure forBOPE 2M 3M '~ 10M 15M "~Or,~ '~(~'~'~"~-'~r' Other: Approved by Rob ll: N. Christenson Commissioner the commission Date .................. Form 10-401 Rev. 7-24-89 Submit in triplicate Alpine: CD1-34 Procedure 1. 2. 3. 4. 5. 6. 7. 8. , 11. 12. 13. 14. 15. 16. 17. 18. 19. Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8-1/2" hole to the intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 ½, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus Set BPV and secure well. Move rig off. Well Proximity Risks: ~-~' ~ Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-35 will be the closest well to CD1-34 (9.9' at 100' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 8.9' at 200' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: A large fault is predicted to approximately 100' away from the 7" casing point. There is therefore some potential for lost circulation in the Alpine sand. If losses are encountered, conventional LCM treatments will be used. 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 CD1-34 will be injected into the annulus of a permitted well. The CD1-34 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-34 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi 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: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi CD1-34 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 ½" Section - 6 1/8" point- 12 1~,, Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 rain (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at + 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost cimulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. "'" Colville River Field CD1-34 Production Well Completion liIlliIll I I I Surface Casing @ 2468' MD / 2400' TVD cemented to surface 16" Conductor to 114' Plan Updated 03/16/00 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1700' TVB = 1710' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" s/s control lines Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch WRDP-2 SSSV (2.125"1D) w/BB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 p.~g KCl Brine with 2000' TVD diesel ca.~ 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet lube pipe dope Completion Tubing Su.oended with diesel to lowest GLM MD TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ +/- 2000 psi set 2 joints above the X landing nipple ~;~.. Baker't~'S3 Packer at +/- 7974' TOC @ +/- 7650' MD (500' MD above top Alpine) Top Alpine at 8150' MD / 7061' TVD Tubing 4-1/2", Camco 4-1/2", Camco 4-1/2", Camco 4-1/2", Hanger 12.6#/ft, IBT-Mod Tubing BAL-O SSSV Nipple 12.6#/ft, IBT-Mod Tubing KBG-2 GLM (3.909" ID) 12.6#/ft, IBT-Mod Tubing KBG-2 GLM (3.909" ID) 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2" tubing joints (2) HES "X" (3.813" ID) 4-1/2" tubing joint (1) Baker S3 Packer 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 4-1/2" 10' pup joint WEG (+/- 63 deg) 32' 32' 1710' 1700' 3680' 3400' 5794' 5200' 7873' 6920' 7942' 6962' 7974' 6980' 8039' 7014' 8050' 7019' Note:thermal break centralizers installed between 2400' TVD (=2468') and 4500' TVD (=4963') Well TD at 11214' MD I 7083' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8435' MD / 7111' TVD @ 91 deg Colville River Field CD1-34 Production Well Completion Plan Formation Isolation Contingency Options I!itI!fl I i lall~ ! I IItIIIi!4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), liiil!~l I "'!~": I Ii~l~ii! WRDP-2 SSSV (2.25" ID) lillIl!lIr=-I Ililiiii! and DB-6 No-Go Lock (3.812" OD) IiIlI!!l I I I I IilIlll! w.h dual 1/4"x 0.049" sis control line I!1~1 I I I I litIllI! @ 1700' TVD = 1710' MD I I Surface Casing @ 2468' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2000 psi ~X~set 2 joints above the X landing nipple ,.~~; I~I~'~-,~ Baker S3 Packer set at +/- 7974' TOC @ +/- 7650' MD (500' MD above top Alpine) (~) Updated 03/16/00 (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (C) Open Hole Brid;le Plu~l Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Well TD at 11214' MD / 7083' TVD ! V ' ! 7" 26 ppf L-80 BTC Mod Production Casing @ 8435' MD / 7111' TVD @ 91 deg CD1-34 "'--" PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114/114 10.9 52 53 9 5/8 2468 / 2400 14.2 1086 1532 7" 8435 / 7111 16.0 3217 2506 N/A 11214 / 7083 16.0 3204 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 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 lb./gal 0.052 = Conversion from lb./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 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) -0.1} D = [(10.9 x 0.052) -0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) -0.1} D = [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3217 - (0.1 x 7111') = 2506 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3217 - (0.1 x 7111') = 2506 psi Alpine CD1-34 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 -500 -1500 -2500 ¢3 -3500 PR -4500 -5500 -6500 -7500 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT Alpin'e~, CD1-34 Well Cementincl Requiretnents 9 5/8" Surface Casing run to 2468 MD / 2400' TVD. Cement from 2468' MD to 1968' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1968' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (1968'-1564') X 0.3132 ft~/ft X 1.5 (50% excess) = 189.8 ft= below permafrost 1564' X 0.3132 ft3/ft X 4 (300% excess) = 1959.4 ft3 above permafrost Total volume = 189.8 + 1959.4 = 2149.2 ft3 => 484 Sx @ 4.44 ft3/sk System: 484 sx AmticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fta => 230 Sx @ 1.17 ft~/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft~/sk 7" Intermediate Casing run to 8435 MD/7111' TVD Cement from 8435' MD to +/- 7650' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (8435' - 7650')oX 0.1268 ft3/ft X 1.4 (40% excess) = 139.4 ft~ annular volume 80' X 0.2148 fto/ft = 17.2 ft3 shoe joint volume Total volume = 139.4 + 17.2 = 156.6 ft3 => 137 Sx @ 1.15 ft3/sk System: 137 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersa~nt, 0.25% D800 retarder and 0.18 Yo D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft/sk I By Weight Of mix Water, all other additives are BWOCement I RCO A1 aska, In Structure: CD#I Well: 34 Field : Alpine Field Location : North Slope, AlaskaI 40O 800 1200 1600 2000 ~-~ 2400 ~.~ 2800 3200 3600 4o00 I~ 44o0 I 4800 5200 5600 6000 6400 68OO 7200 i 4O0 RKB ELEVATION: 56' Begin Nudge 2.00 4.00 DIS: 2.00 deg per 100 6'OOEnd Nudge West: Sak 6.82 Begin Build/Turn 7.45 Permafrost: 9.07 11.27 15.78 DLS: 5.00 deg per 100 fl: 16.44 19.21 22.05 24.89 C40 27.79 50.70 EOC g 5/8 Casing C50 C20 228.52 AZIMUTH 34~3' (TO TARGET) ***Plane of Proposal*** AVERAGE ANGLE 32.66 DEG K-5 K-2 RECEIVED MAR Zo ZO'O0 Alaska Oil & Bas Cons. Ca3mmission ~ch0rage Albion-g7 Albian-96 Begin Rnal Bu;Id HRZ K-1 45.41 LCU Miluveach A 58..~9 AIp{n.e .D /~p,ne Torgel:-E:OC-Csg Pt. i i i ! i i i ii i ii i i i 600 1200 1600 2000 2400 2800 3200 3600 Vertical Section (feet) -> Azimuth 228.52 with reference 0.00 S, 0.00 E from slot 33.23 55.78 DLS: 9.00 deg per 100 ft i i 4000 4400 TARGET ANGLE 90.58 DEG ARCO Alaska, Inc. Stru~lure: CD~I Well: 54 Field: Alpine Fleld Loooflon: North Slope, Alaska AVERAGE ANGLE 32.66 DEG 151.93 AZIMUTH 3571' (TO TARGET) ***Plone of Proposol*** 6080 6240 6400 6560 6720 6880 7040 7200 TARGET ANGLE 90.58 DEG ! i i i i i i i i i i i i ! i i i i i [ i i i ii i ii i i i i i ! i ! i i i i i ! i i ! i i .0 160 520 480 640 800 960 1120 1280 1440 1600 1760 1920 2080 2240 2400 2560 2720 2880 3040 ,]200 3360 3520 `]680 Verficol Section (feet) -> Azimuth 151.95 wHh reference 0.00 S, 0.00 E from slot #54 250 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 5000 5250 5500 3750 4000 4250 4500 ructure: CD#I Well : 34 Field ; Alpine Field Location ; North Slope, <- West (feet) ;000 2750 2500 2250 2000 1750 1500 1250 1000 750 500 250 0 250 I I I I I I I I I I I I I I I ! ! I I I I I I I I 4750 Albian-97 Albian-g6 in Final Build LCU Miluveach A Alpine D Alpine Target-EOC-Csg Pt. SURFACE LOCATION: 459' F-NL, 2542' FWL SEC. 5, T11N, RSE Beqin E-nd 9 5/8 Casi~ C20c50 K-2 TARGET LOCATION: 2555' F~L, 251' FEL SEC. 6, T11N, RSE TD LOCATION: I 105' FSI_, 1068' FWL SEC, 5, T11N, R5E - Csg Pt. ;000 2750 25~ 2250 20~ 1750 1 ~0 1250 1~0 750 ~0 250 0 250 <- West (feet) 250 250 500 750 1000 1250 1500 1750 2000 0 c- 2250 2500 .-i- I 2750 V 5000 5250 5500 3750 40OO 4-250 45OO 4750 5000 ARCO Alaska, Inc. StruaJure: CD#I Field: Alpine Fleld Well: 34 koootlon: Norfh Slope, Alaska Horizontal Section Point Begin Nudge End Nudge West Sok Begin Build/Turn Permofrost C40 EOC g 5/8 Cosing Pt C50 C20 K-5 K-2 Albion-97 Albion-96 Begin Final Build HRZ K-1 LCU Miluveach A Alpine D Alpine Target-EOC-Csg Pt. iTD - Csq Pt. PROFILE COMMENT DATA MD 500.00 650.00 1049.85 1547.00 1565.80 2217.82 2467.29 2468.49 2469.68 2897.50 4150.45 4411.78 6472.66 7048.75 7427,15 7470,46 7724,57 7882.22 8042,81 8089.17 8150.49 8435.38 11215.84 Inc Dir TVD North 0.00 150.00 300.00 0.00 7.00 150.00 649.13 - 18.49 7.00 150.00 1046.00 -60.69 7.00 150.00 1540.95 -92.06 8.40 199.07 1556.00 - 118.49 25.41 258.58 2181.00 -257.94 52.66 242.41 2598.99 -297.11 52.66 242.41 2400.00 -297.41 52.66 242.41 2401.00 -297.71 52.66 242.41 2761.00 -404.60 52.66 242.41 5816.00 -717.87 52.66 242.41 4056.00 -785.19 52.66 242.41 5771.00 -1298.57 52.66 242.41 6256.00 - 1442.58 52.66 242.41 6574.54 - 1556.96 52.86 255.20 6611.00 - 1549.09 41.25 199.50 681 6.00 - 1 669.07 50.48 184.22 6926.00 - 1779.51 61.40 172.75 7016.00 -1911.72 64.75 1 69.92 7057.00 - 1952.57 69.19 1 66.40 7061.00 -2007.76 90.58 151.95 7111.00 -2267.21 90.58 151.95 7085.00 -4718.70 Eost 0.00 10.68 55.04 53.15 54.58 -82.09 -187.57 -188.15 -188.72 -393.24 -992.61 -1117.60 -2103.30 -2578.84 -2559.81 -2579.83 -2665.27 -2687.03 -2682.67 -2676.45 -2664.83 -2564.81 -1257.42 V. Sect 0.00 21.54 70.04 106.24 130.23 171.55 175.90 175.90 175.89 171.97 166.35 165 18 155 94 155 55 151 66 152 94 218 60 505 64 424 52 463 5O 517 66 793 66 5571 98 Deg/lO0 0.00 0.00 0.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 l. O0 0.00 0.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 0.00 ARCO Alaska, Inc. CD#1 34 slot #34 A1Dine Field North SloDe, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ RECEIVED } AR 20 2000 Your ref : CD1-34 Version #7 Our re f : prop3538 Alaska 01i & GSSCons. CommJ~on License : ~~ Date printed : 15-Mar-2000 Date created : il-Aug-1999 Last revised : 15-Mar-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 32.595,w150 55 37.584 Slot Grid coordinates are N 5975671.878, E 385766.528 Slot local coordinates are 457.70 S 2343.35 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PGMS <0-10255'>,,WD2,CD#l PMSS <0-10796'>,,24,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <0-12055'>,,40,CD#1 PMSS <384 - 14477'>,,23,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <0-10224'>,,39PH1,CD#l PMSS <0-11067'>,,32PH1,CD#l PMSS <10016 - 11136'>,,32,CD#1 PMSS <472 - 1545'>,,36PH1,CD#l PMSS <763 - 7440'>,,36PH2,CD#l PMSS <6600 - 10654'>,,36,CD#1 PMSS <0-10897'>,,3,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <0-9357'>,,16PHi,CD#1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <0-11300'>,,13,CD#1 PMSS <0-9236'>,,22,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <0-7331'>,,1PHi,CD#1 PMSS <7755-11134'>,,26,CD#1 PMSS <0-8350'>,,26PH1,CD#l PMSS <0-10548'>,,19,CD~1 PMSS <0-8844'>,,45PH1,CD~l PMSS <7950-11950'>,,45,CD~1 PMSS <174 - 777'>,,27,CD#1 PMSS <654 - 10956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD#1 PMSS <0-10504'>,,5PHi,CD#1 PMSS <9499 - 14515'>,,5,CD#1 PMSS <832 - 12147'>,,25,CD#1 Closest approach with 3-D Last revised Distance 28-Jun-1999 28-Jun-1999 28-Jun-1999 28-Jun-1999 18-Aug-1999 26-Aug-1999 22-SED-1999 4-Jan-2000 4-Jan-2000 23-Dec-1999 4-Jan-2000 4-Jan-2000 22-Dec-1999 4-Jan-2000 23-Dec-1999 4-Jan-2000 25-0ct-1999 15-Ju1-1999 28-Jun-1999 27-Jun-1999 29-Feb-2000 1-Nov-1999 6-Mar-2000 28-Jun-1999 4-Jan-2000 16-Nov-1999 28-Feb-2000 13-Feb-2000 14-Feb-2000 23-Jan-2000 23-Jan-2000 15-Mar-2000 1261 2 99 7 9 9 60 1 109 9 30 1 48 5 48 5 19 9 19 9 20 1 20 1 20 1 309 7 80 1 180 0 180 0 209 8 119 3 329 5 329 5 78 2 78 2 149 3 109 9 109 9 34 1 39 6 39.6 288.9 288.9 90.0 Minimum Distance method M.D. 400 0 337 5 100 0 100 0 100 0 0 0 612 5 612 5 100 0 100 0 100 0 100 0 100 0 260 0 100 0 100 0 100 0 100 0 312 5 220 0 220 0 400 0 400 0 337 5 200 0 200 0 900 0 180 0 180 0 312 5 312 5 100 0 Diverging from M.D. 400.0 337.5 1955.6 10560.0 8480.0 11213.8 11100.0 11100.0 100.0 100.0 100.0 2820.0 2820.0 11080.0 100.0 8980.0 8980.0 100.0 312.5 220.0 220.0 11100.0 11100.0 337.5 200.0 11213.8 11213.8 11213.8 11213.8 312.5 312.5 10260.0 f~ar-lS-O0 13:16 Free.ALPINE TELEf" 90T-656-1703 T-IT6 P.03/06 F-04O ~h/~o/ogl~n~l^~RI I P~_~^oooo~^cs I Zl~/~z/UUl/~. ,~-,/ !-~ · , i I~ - i I ~I~T7 ~ ~T T~ / ~e2 70~5 tlo® ~0 ~ ~ ,3 ~012 . 17 eel6 29~28 / ~loe~O 000 3~0~2 ~--- · ,e%o - LEGENd.. 43ee42 / · EXISTING CONDUCTORS 45e044 + NEW CONDUCTOR LOCA~ON ~ ~ o ~N CONOUCTO~ ~ / ~ LOUNSBURY I I I III ARCO Alaeka, Inc. ~ ~.E P.O~CT ~ CD1 ~ ~HDUC~R~ Sub~idiory of Atl=ntic Rl~ld Compo~ A~--BUILT LO~A~ON~ LKS63q1 3/5/99 CE-CD10-663DJ . ,, 1 ~'--3 2 Mar-13-O0 13:16 I:rmn-.~LPlllE TELEC" 007-656-1703 T-S?8 P.04/06 F-046 · · ~ Line Well 'Y' 'X' Lon, F'NL Grid Pad :D1-7 ,33, 50' 150' CD1 CD1-42 * CD1-22 CONDUCTOR WAS AS-BUILT 2/11/gB. ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company LK663ql ,_ 3[,5/9,9 .~ LOUNSBURY &. ASSOC~, INC. %gll~.m~ PL&N~ ~o~ ALPINE:' PROJECT- CD1 WELL CONDUCTORS AS-BUILT LOCATIONS i - CE-CDlO-663D1 I'% Mar-13-O0 13:19 From-ALPINE ,,, h/,o/...I,,,,.T! I, 90T-656-IT03 Mr~lJ J :,' I,VIz/UUl ~, ,_.,~ T-:IT6 P.06/05 F-049 NOTES 1. ALL COORDINATI.S ARE ALASKA STATE: PLANE:, ZONE 4., NAD 27: 2. E:LE:VATIONS ARE: BRITISH PETROLEUM MEAN SI.A L£VE:L ORIGINAL GROUND ELEVATIONS ARE INTE:RPOLATED FROM MICHAEL BAKE:R dR. DWG. CE-CDIO-102, SHT 1, R£V. 0. 5. BASIS OF LOCATION AND ELEYATION ARE TEMPORARY ALPINE: MONUMENTS' ,:3 & 4- BY LOUNSBURY & ASSOCIATES. 4. DATE OF SURVEY: WELL CONDUCTORS 10. 15, 14., & 16-19 WERE AS~-BUILT 5/10/99. RE:F. FIELD BOOK L99-20, PAGES 5-11. CONDUCTORS 1-5 WERE AS-BUILT 3/25/99, RI'F: FIELD BOOK L99-24, PG. 2B-51, CONDUCTORS 4-6,' 9.- 20, 21, 23-50. & 3,5 WE:RE: AS-BUILT 3/29/99, REF: FIELD BOOK L99-25, PG, 65, 67-73, CONDUCTORS 56-4.5, & 4.5 WERE AS-BUILT 4./6, 4./9/99, REF: FIELD BOOK L99-26, PC, 35-58, & 48, WELL CONDUCTOR 34. AS-BUILT 5/11/00, REF: FIELD BOOK LO0-09. PAGES 2 & 4. RECEIVED MAR 2 0 2000 Alaska Oil & Gas Cons. Commission An~omge ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company CAOD FILE NO. LK663DI SURVEYOR°S C£R TIFICA TE . · _ -illI ...... I HEREBY CERTIFY THAT ! AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE. STATE OF' ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF $/12/00.. i ..... i i il i iiii , -- .~ LOUNSBURY & A,~SOCIATES, INC. ALPINE. PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCATIONS' . .C.E-CD.t 0-~,663D! Is~r:3 '- I"~' ...... or 3 2 ,... ~ka;4'~.~..;... '...::i ..........:' ": "ii~.: . o.~,~ '.,' ,.. ~~o,,,A~ . ' ' · .... · ~'"" ~' .:,.~ .... ~,.~, ............~..........~............'......,:i. ':":'.":"'."'~'.". c, 3' ~"~":'~' "' '"'"' i"i'~:PO. Bd~r:.:l',02'7~0 ''':~`~ '":":' "'""' ''~' :" ".'..,~':'~'i "~'" "':~:'""'":".'"" ''~' "." =,~!.,i.~i~hoi~l,e; AK :',i: 99~.',';1'0'-2~'76' ,,.,,,.:, ,,':. :'.' ,'~ :'""".,/.'...:.::i,",,,:,?:::!.!.!.i~''' '%, .,....::,,.,,, , . PT~'Y~E OF STA'~(~I~'L~''s(~:I::I~O''N~T!y0N C0~MI?¥i :i:!i'!' ':".:~'i?i:,~;?:':.'i~:~!'i:'~~':90 DA'~S...'~'$* ...'?. :.. ".: :... ':":"::~... 'i..':'i ..... .."'. !...:i':.. '.'i...:'.. ~RD ........ """ AL~."" :" :'": !'''' '~' D~i~/~'"' ;""':;"~ ' '"'"":"":" "'~ ~ :":"'"':: "'":" '''''? "":"' '":'"'":' '"'!~i. !":.'. '.::.:...'i'... '.! i" .!::'. i.'.'?. ;'~.~'~':i~00~.'":"'.'i".'.~'~':'. .:.; ..:...'.:.'..: .... .'.!~":'""..::::."~n~.'~.p~RCUpINE .... ' '.'. :.::...'. "i:."'.... '....i ::::..: ..:..... :.i.i;...'.i :.;?.".'. ....'.:.'..: .i~i.' '.?: ~'~., '~'~:'.~iT..'~".~'~~ : ....... '. .'..~/...'...'.. · ' ~ e ....... II' '"'" ' ' '" : ' ' '":' "'r)... '::'i:..!'. :i".'::.:~:',' :::::i' ...::'..~'.."::.v ...... '.' ""'.:'.' "" ! i~, ": ." " ?:"...~: ..:.i'...:.:'! ii..'.: "....:!?... '..~.:::.i.:;:.~i.~i.~'~:..~..i:~..'.AN~' u~ ~,,~". :.¥...'. '". !':.."..:."....:.:....~r.. ' ~,:~x~/_y.. ,~,,,,~,~,~:~i~,~:. ,-'--.~....--.:::."'....:~..'..' ' ': ' .' .... "' : '": .."::'. ...::"" : :....".: '.'.""." ".:.' . . , .... : ';;',;;;:.;':!,"" ... . ':'""".'.""" '.;~"'~,~i, ~ ,,,;.;.,.' ' ~ ..'~r~,..~:;..... .: ~"..::' :' " " i:.' .:. .."' ~ " '/~'.~' "'"'" !, payable Through RepubliC Bank . . . i .. '' ..' .' Shetbyvit!~, k~ntuckY ' ':' " " ' : ~R~CE NU ~B ~R: ~0~I0~37 ~0 mill ' ~I I I ' ,"aOSOct ~ ? t'O~" i~06 ~ciOt, E~ i~i: O WELL PERMIT CHECKLIST FIELD & POOL / .9.,~)/C:;~ COMPANY ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11. .R D~TE~ 12. ENGINEERING WELL NAME~',Z)/".,~ ~/PROGRAM: exp ~ Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .. ......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~L.~ psig. dev .'~ redrll ~ serv wellbore seg ann. disposal para req ~ GEOL AREA c~' q,,~:~ UNIT# ~ ~"~) '~ ~ ~ ON/OFF SHORE N DATE II GEOLOGY 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. 32. 33. 34. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Permit can be issued wlo hydrogen sulfide measures ..... ~Y N Data presented on potential overpressure zones ....... Y ' Seismic analysis of shallow gas zones ............ ~,,,y N .~,,/~~_~.~r: Seabed condition survey (if off-shore) ............. Y N Contact name/phone for weekly progress reports [explo~ only] (~)N Comments/Instructions: GEOLQGY: ENGINEERING: UlCIAnnular COMMISSION: 0 Z 0 c:~nsoffice\wordian\diana\checklist (rev. 02/17100)
