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Home My WebLink About201-160 • 41111 201160 WELL LOG TRANSMITTAL#903873852 2 9 3 8 0 To: Alaska Oil and Gas Conservation Comm. June 11, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 202018 RE: Packer Set Record: CD2-39 AOGCC Run Date: 3/8/2017 V The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-39 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20387-00 Packer Set Record 1 Color Log 50-103-20387-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 SCANNED JUN 2 5 nit Office: 907-275-2605 FRS_ANC@halliburton.com do, o Date: Signed: ' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil E • Gas❑ SPLUG ❑ Other, ❑ Abandoned 2 . Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL El No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 2/7/2017 201-160/316-632 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 9/2/2001 50-103-20387 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 1954'FNL, 1516'FEL,Sec 2,T11N, R4E,UM 9/17/2001 CRU CD2-39 .• Top of Productive Interval: 9.Ref Elevations: KB: 52.9 17. Field/Pool(s): 623'FNL, 1407'FWL,Sec 12,T11N, R4E, UM GL: 15.9 BF: Colville River Field,Alpine Oil Pool - Total Depth: 10.Plug Back Depth MD/TVD: 18.Property Designation: 1368'FSL,2031'FEL,Sec 12,T11N,R4E, UM 12651 /7228 ADL 380075 ' 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 371722 y- 5974403 Zone- 4 12651 /7228 932034000 TPI: x- 374580 y- 5970406 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 376369 y- 5967087 Zone- 4 2206/2019 1702/1628 5.Directional or Inclination Survey: Yes ❑(attached) No ❑✓ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A O�E� ?� 2 5 rai- RECEIVED % MAR 2 9 2017 23. CASING,LINER AND CEMENTING RECORD AOGCC WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 62.5 H-40 Surface 117' Surface 117' 42" 10 cu yds Portland Type 3 9-5/8" 36 J-55 Surface 2654' Surface 2370' 12.25" 405 sx AS III Lite,230 sx Class G 7" 26 L-80 Surface 9123' Surface 7227' 8.5" 145 sx Class G 24.Open to production or injection? Yes ❑ No Q 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 8774' 8673'/7074' Cement Retainer at 9006'MD. At3RNooNsv Capped with 16bbl of 16.5 ppg Class G cement 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. // /= Was hydraulic fracturing used during completion? Yes ❑ No 0 Z! ( 11- Per 20 AAC 25.283(i)(2)attach electronic and printed information - DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED -_ -_.1-5- Cement retainer©9006' 16 bbls of 16.5 ppg Class G Cement PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .11. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate _ Form 10-407 RA ed 11/2015 vrL 4124 1 t- -CONTI UEDO P9GE 2 RBDMS Vi AFR - 3 2017 Submit ORIGINIAL onlyt 28.CORE DATA Conventional Coo: Yes ❑ No Q Sidewall Cores:•s ❑ No ❑✓ 'If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑I Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1702 1628 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information,including reports,per 20 AAC 25.071. Formation at total depth: N/A N/A 31. List of Attachments: Daily Operations Summary,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike C lahan @ —3-4180 Ale_ Email: Mike.Callahan©conocophillips.com Printed Name: G.Elle Title: Lead CTD Engineer Signature: , ,` Phone: 263-4172 Date: 3"2%- �1 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only 0 CD2-39 • DTTMSTART JOBTYP SUMMARYOPS 02/07/17 DRILLING SUPPORT- RIH w/2.50"Baker ICR and setting BHA. Condition well by pumping 150 bbls of 140 F diesel. With CAPITAL ICR at 9006'(mid element), pump ball on seat to set ICR. Ball seat sheared at 2317 psi. Set 5K down and pressure tested to 700 psi over WHP,good test. Sheared off ICR w/22.5K CT Wt. Pumped 16 bbls of 16.5 ppg Class G cement. Layed in cement with 1:1 returns to 8200'. Contaminated cement top down to 8660'with ProVis. Washed GLM and SSV while POOH.Job in progress. 02/08/17 DRILLING SIDETRACK Mob to Alpine 2CD-39 Leave Drill sub,shop,and halfway house at 2A-Pad. Mobilize pits to 10 Acre pad Alpine-Cross Colville River ice bridge @ 15:30. Stage at 10 acre pad 02/08/17 DRILLING SUPPORT- TAGGED TOP OF CEMENT @ 8647'SLM(8677' RKB)w/2.48"CENT, SAMPLE BAILER. CAPITAL COMPLETE . 0 M CD2-39 Final CTD Schematic Modified by MSC 3/2/17 16"62.58#H- 40 shoe @ 117 'LC, 4-1/2 x 3-1/2 XO @ 124'RKB MD O 9 °' 3-1/2"9.3#tubing from 8774'RKB to surface Camco TRM-4E SSSV X-Profile @ 2207'RKB(min ID 2.813") open Camco KBUG-M GLM @ 3985',6903',and 8560'RKB 9-5/8"36#J-55 3-1/2"HES X Nipple @ 8640'RKB(min ID 2.813") DshOe @ 2654' — — Baker SAB-3 packer @ 8673'RKB(3.25"ID) air 3-1/2"HES XN Nipple @ 8762'RKB(min ID 2.75") Baker Wireline Entry Guide @ 8773'RKB(2.992"ID) I I CD2-39A South wp02 TD @ 12,296'MD Billet @ 8991'MD Bottom of Liner @ 9500'MD \\ yY• KOP @ 8900'MD J ,s I -'..-.,::::::.,\ a:.;,%;', .,„ CD2-39AL1 North wp01 *< u TD @ 11,571'MD `7/ '� lk m Top of Liner @ 8660'MD a r\ 440 � a _= in Bottom of Liner @ 9422'MD al 6-1/8"OH @ 12651'MD 7"26#L-80 shoe @ 9123'MD 0 WNS PROD • CD2-39 ConocoPhillips /4 I Well Attributes Max Angle&MD TD Alaska,It 14. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act atm(ftKB) rmoo&i.,..Pr 501032038700 ALPINE PROD 91.06 11,699.02 12,561.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CO2-39,3/29/201783357 AM SSSV:WRDP Last WO: 43.21 9/20/2001 Vertical schematic(actual) Annotation Depth(R1(13) End Date Annotation Last Mod By End Date Last Tag.SLM 8,864.0 5/18/2013 Rev Reason'SIDETRACK pproven 3/17/2017 HANGER:332- 1 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread OPEN HOLE 61/8 6.125 9,122.5 12,651.0 TUBING PUP;344 Perforations&Slots 11'-111[ �I Shot JI Dens rep(TVD) Bbn(TVD) �I, Top(ftKB) atm(ftKB) (ftKB) (RKB) Zone Date (aholen t) Type Com 8,705.0 8,708.0 7,092.6 7,094.3 2/3/2017 3.0 APERF 120 degree phase Stimulations&Treatments TUBING',38.2 -"-l Proppant Designed(Ib) Proppant In Formation(Ib) Date CONDUCTOR:37.0-117.0 2/10/2008 Stimulations&Treatments XO Reducing;124.2 Vol Clean Pump Stg# Top(RKB)122.5 Btrn OMB)) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) 1 9, 12,651.0 2/10/2008 iii Proppanl Designed(Ib) Proppanl In Formation(Ib) Dale 3/18/2013 SAFETY VLV;2 206 8 Stimulations&Treatments ISO SLEEVE;2,207.0, Vol Clean Pump Stg# Top(MB) atm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) 1 9,122.5 12,651.0 3/18/2013 Notes:General&Safety End Dale Annotation 9/1/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1/17/2017 NOTE:-12'.125"WIRE STILL IN HOLE'^ SURFACE:36.8-2,654.1—tea GAS LIFT;3,985.1 GAS LIFT;6,903.1 ri II PATCH-Upper;8,554 0 GAS LIFT:8,5603 ', � PATCH-Lower85710 / 'F i NIPPLE;8,6398 tr7 1 ii1 AL1 Lateral,7,897.9 8,660.0 CMT PLUG;8,660.0 PACKER;8.672.7 APERF:8,705.0-8,708.0 NIPPLE,8,761.8 WLEG:8,7728 6 A LATERAL:8,479.6-8,990.0 I ICR,9,0050 Vd PRODUCTION;35.1-9,122 5 RE-FRAC;9,122 '+ FRAC,9,122.5 OPEN HOLE;9,122.5-12,651.0 WELD. LOG 2_`60 TRANSMITTAL 2%0 \ 1 ,I• DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. RECEIVED 3/2/201-7 mK.BENDER MAR 01 2017 To: AOGCC AOGCC Makana Bender /-1 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907)245-8952 SCANNED MAY 2017, 1) Leak Detection - STP 30-Jan-17 CD2-39 Color Log/CD 50-029-20387-00 2) Caliper Report 30-Jan-17 CD2-39 1 Report /CD 50-029-20387-00 Signed : / , ✓LG L..Ytov - / ' • Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE(C MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFi les\Templates\Di stribution\TransmittalSheets\ConocoPhill ips_Transmit.docx • LO\- 'CO litCEIVED2_%0 146 PI MAR 0 1 2017 Memory Multi-Finger Caliper 0Log Results Summary AOGCC Company: ConocoPhillips Alaska, Inc. Well: CD2-39 Log Date: January 30, 2017 Field: Alpine Log No.: 14248 State: Alaska Run No.: 1 API No. 50-103-20387-00 Pipe Description: 3.5 inch 9.3 lb. L-80 8RD-MOD Top Log Interval: 8,474 Ft. (MD) Pipe Use: Tubing Bottom Log Interval: 8,723 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the X Nipple at 8,640 feet(Driller's Depth). The joint numbers used in this report are an approximation based on average joint length and depth logged. This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. A 3-D log plot of the caliper recordings across the interval of 3.5 inch tubing logged is included in this report. The caliper recordings indicate the interval of 3.5 inch tubing logged appears to be in good to poor condition, with wall penetrations ranging from 22%to 81%wall thickness in 4 of the 10 joints logged. Recorded damage appears as a line of corrosion and general corrosion. Maximum recorded cross-sectional wall loss of 15% metal volume is recorded in an area of general corrosion in joint 261 (8,539 ft). No other significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. MAXIMUM RECORDED WALL PENETRATIONS : 1:-scriptiuri Percent\A/tall Petaetraticirf ,i;,inl. !!;,p$1, Corrosion 81 261 8,535 Ft. (MD) Corrosion 63 260 8,503 Ft. (MD) Corrosion 53 259 8,485 Ft. (MD) Line Corrosion 22 261.3 8,570 Ft. (MD) No other significant wall penetrations(> 18%)are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Description PCrcent Wali Loss ,oirt [:eteth Corrosion 15 261 8,539 Ft. (MD) No other significant areas of cross-sectional wall loss (> 14%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. C. Goerdt C. Waldrop B. Boehme Field E_ng neettsi Analyst(s) titneccr s) ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford,TX 77497 Phone: (281)431-7100 or(888) 565-9085 Fax: (281)431-7125 E-mail: PDSAnalysis(amemorylog.com Prudhoe Bay Field Office Phone: (907)659-2307 Fax: (907)659-2314 • • 1141. PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Alpine Well : CD2-39 Date : January 30, 2017 Description : Detail of Caliper Recordings Across 3.5 Inch Tubing Logged. Comments Depth Maximum Penetration Maximum I.D. 3-D Log Image Map I 1 1 1ft:240ft0 % 1002.5 inches 3.5 0° 0° 90° 180° 270° 0° Minimum I.D. 1 1 2.5 inches 3.5 Nominal I.D. I : 2.5 inches 3.5 Joint 259 MO Corrosion 8480 lii 53%Wall �� Penetration i 8490 -__ imp-- t Joint 260 ilW Corrosion 8500 63%Wall Si Penetration 15%Wall Loss 8510 in MC Mr 8520 as,1116 — AIL_ Joint 261 8530 = E Corrosion /� 81%Wall {MF. Penetration 8540 = itr_ L 8550 :MI ''= A,` Pup Joint /! , 8560 GLM 2 r Pup Joint 8570 [� Line Corrosion s 1 ir 8580 f I 8590 Joint 262 8600 F lF • • 8610 ', , p r 8620 1 3 Joint 263 1 I a 8630IFI rI EL I / 3.5"HES X 8640 - t. 4 Nipple Joint - 1 8650 1 Joint 264 8660 , 1 >f 8670 i 1 a Baker SAB-3 8680 1 I1 ---mm.... � Packer Joint � ii 8690 j :i Pup Joint #I - 8700 f 8710 3 # Joint 265 i 3 8720 3 i , i Nominal I.D. 2.5 inches 3.5 Minimum I.D. I 2.5 inches 3.5 Comments Depth Maximum Penetration Maximum I.D. 3-D Log Image Map 1ft:240ft 0 % 100 2.5 inches 3.5 ____ 0° 0° 90° 180° 270° 0°1 • • PDS Report Overview � .. Body Region Analysis Well: CD2-39 Survey Date: January 30,2017 Field: Alpine Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 8RD-MOD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD-MOD 2.992 in. 8,474 ft. 8,723 ft. Penetration (%wall) Damage Profile(%wall) 10 MI Penetration body mm Metal loss body 0 50 100 259 8 6 260 4 261 2 0 261.1 0 to 20 to 40 to over 20% 40% 85% 85% , Number of joints analyzed(total= 10) GLM 3 (6:30) 261.3 6 1 3 0 262 Damage Configuration(body) 10 ' ■ 263 8 6 264 4 2 .rte ■■■ 264.2 pi 0 265 • Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=8) 4 3 1 0 0 Bottom of Survey= 265 ! • PDS Report Joint Tabulation Sheet Well: CD2-39 Survey Date: January 30, 2017 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 8RD-MOD Tubing 2.992 in. 0.254 in. 8,474 ft. 8,723 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 259 8474 0.07 0.13 53 13 2.81 Corrosion.Lt. Deposits. mum 260 8487 0.05 0.16 63 15 2.83 Corrosion.Lt. Deposits. ■um 261 8519 0.06 0.21 81 14 2.86 Corrosion.Lt. Deposits. 261.1 8550 0 0.05 18 4 2.88 Pup Shallow Pitting. Lt.Deposits. 261.2 8561 0 0 0 0 2.84 GLM 3(LATCH @ 6:30) 261.3 8567 0.05 0.06 22 7 2.96 Pup Line Corrosion. 262 8577 0 0.04 16 4 2.90 Shallow Pitting. Lt Deposits. ■ 263 8609 0.04 0.04 16 5 2.92 Shallow Pitting. Lt Deposits. 263.1 8640 0 0 0 0 2.84 3.5" HES X NIPPLE 264 8642 0 0.04 15 3 2.93 Shallow Pitting. Lt Deposits. 264.1 8673 0 0 0 0 2.92 BAKER SAB-3 PACKER 264.2 8688 0 0.03 13 4 2.92 Pup Lt. Deposits. ■ 265 8700 0 0.04 14 2 2.89 Lt.Deposits. IPenetration Body Metal Loss Body Page 1 • daS PDS Report Cross Sections Well: CD2-39 Survey Date: January 30,2017 Field: Alpine Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 8RD-MOD Analyst: C.Waldrop r Cross Section for Joint 261 at depth 8,535.190 ft. Tool speed=49 Nominal ID=2.992 • Nominal OD=3.5 Remaining wall area=91% Tool deviation=43° 1 Finger=9 Penetration=0.205 in. Corrosion 0.20 in.=81%Wall Penetration HIGH SIDE=UP • • CFR.S. PDS Report Cross Sections Well: CD2-39 Survey Date: January 30,2017 Field: Alpine Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 8RD-MOD Analyst: C.Waldrop Cross Section for Joint 260 at depth 8,503.230 ft. Tool speed= 50 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=93% Tool deviation=43° 1 Finger= 7 Penetration=0.161 in. Corrosion 0.16 in.=63%Wall Penetration HIGH SIDE=UP • • PDS Report Cross Sections Well: CD2-39 Survey Date: January 30,2017 Field: Alpine Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 8RD-MOD Analyst: C.Waldrop Cross Section for Joint 261 at depth 8,538.710 ft. Tool speed=51 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=85% Tool deviation=42° \ / 1 \i„ / Finger= 11 Penetration=0.112 in. Corrosion 15%Cross-Sectional Wall Loss HIGH SIDE=UP tillIllrillIIIIIIIIIIIIIIIIPW''' - JNS PROD CD2-39 ConocophiIIips t L.'• .�Aro. ..,,,..r. 'WNM1 w1Neme 1 L.5H3.111C, 501032038700 ALPINE PRO Nu 'n91,00 •II ' 1'm 1•, 11,099,02ilticaMt{L12 681.0"' •.• Comment Hes(ppm) One Gotta-Lt/`9„ou TL;Sw SSSV.WRDP Mna.11on in.Ona fie 1 �r.+cn xmmn<nn,,. LSI WO: 9 Ia . a1F Annotation bplh VMS) End bla Mnetnbn 0720/2001 Leal Tog:SLM 0,661.0 En I .nd•:: tV2013 Rev It OnSon:RCSCT WRDP 8.OLV C(O 9+ornn Y -- 102'9/2016 HANGED,]].:� as rig .1 ' Cooing b+cnPt 00 ) 0 I b CONDUCTOR 00(In)16'01115,062 Top(n 1370 pih(,1O MI Dole h 11VD)•••WilLen(I.,. army bacnpt on 0D n 117,0 117.0 62.68EM op MFW Din °P n•: iiiii SURFACE 9518 8.921 348 -el eapn • . M �•... „1 00 WELD rvwNGwP,]eF cooing O.cnptlat 013(In) ID In Top11602,654,1 2,3697 30.00 OTC 1e PRODUCTION 1 1 l 1 3.1 Depth 0,181 d•1 Depth(VD)...WULen(L..1.60 op- hie i 1 7 6.276 35.1 9,122.5 Cooing beenppon O0(In) ID pn) Top(OHO) so b 7,227.2 2400 L•EO bTMC OPEN IIOLC 6 Va 6.125 9,122.5 P1n 9,121 s•1..,,,,,,7,;202,,7)..,2 eplh 1100).,, ,,,..2.0 Lan 17..,�� Tubing Strings 12,651,0 Tubing Deocnptlon Shing a.,.ID(In) Top(11613 Sol•pet L.Sal••pih)Nit). ' I I) a rade op onn•al on TUBING 4.5"X3.5' 3112 2.992 33.2 8.774.1 Completion Details 7.128,3 a30 L.110 and-Mod . T Top MKS) I Top(TVU)(,12) Top Incl(•) Item Deo Nominal ID 33.2 39.2- 0.00 HANGER PAC c"" In ruslNc]81 fro CO3YDI7CTOR,N.0117.0-4. 124.2 124.2 0.06 k lnp CROSSOVER 4.5",12.00,107 TO 3.5' '2,205.8 2.019.7' 35.05 SAFETYVLV CAMEOTRM-0G SSSVRILOCKEDOPEN)NOTE:USG 3606 2.85"PACKING ON YJRDP-1;001 NOT TO EXCGED J X0 R•0.cay:124 845' 8,639.8 7,053.6 49.93 NIPPLE 11E9 X NIPPLE 8,572.7 7,074.2 53.59 PACKER DAHER SA0,3 PACKER 3.213 8,761.8 7,122.1 59,69 NIPPLE 11E8 XN NIPPLE J'j� 3.260 bb .�-V _.2260 8,772.6 7,127) 59.94 WLCO WIRELINE GUIDE 2,020 WRDP,2 258 5 2.920 SAFETY V.V.2,208.8 v Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TM) Top Incl t._ Top(f11B) OHS) try Dee Com 2,206.8 2,019.7 3205 WHOP 2.81"TRM-4E WHOP(S./RI-ITS-820)W/2.53" 4.41.458 ORO PACKING. fvtlek Stimulations&Treatments /.i(1 n, Mln TOP MOO 81.1 `� Depth Depth Top(TVD) 2,n(TVD) MKS) (fIK2) ((1121 MKS) TYP+ Dale Com 9,1225 12,651.0 7,227.2 FRAC 2/102008 C•SANO FHAC 490,000 0,101300ADGER SAND 110 9,1225 12,651.0 7,227.2 • RE-FRAC 3/18/2013 C-SAND FRAC 300 Ileum I X•Ilnkud put plulpg SURFACE 38s2,654 - 320,0000 of 16/20 proppam Into formation(all sand on Iecallnn pumped).Cu14115ta5o strut and o8londod 70 8(960.Flushod to complolbn. I Mandrel Inserts SI a AS LIFT.3915.1 pil op N Top otKO T(118) Valve Latch Pon Ste+ TPO Run Meet Feodel 0010i) UM(,KB) Type Typa (in) t) Run Dab Com III 1 6,903.1 5,702.. AMCO KOUG• 1 GAS LIFT_ r.T;reRi M 2 6,903.1 5,7023 CAMEO KOUG• i GAS LIFT Fa 11111EI •7}21777 IM 3 9,560.3 6,998.5 CAMEO )(BUG- SLI �� F t moi] t iii M Notes:General&Safety GAS LIFT.69e].1r End Date M" " 1 1 0 , 9/177010 NOTE:VIEW SCHEMATIC wOAlaska Schomal 12/x/ ' ,Sri iso SLervC e 2c' ( t..,mSII) GAS LIFT.a.s6o.a i/ID//� 19 u ff e e (.Sc) JL-r'-f{if (� U r Ke ' 1-- i)-16 &lie/ GLV U &"I0'.3( k'c NIPPLE5.639.8 / '-;-r-/7 sed bi 61°3 ka - )- 1-1 ) j9s ,exj Q� }(YLPACKER.8872.1 ipr, rt 7 ! \ r NIPPLE 5.761.8 /.I bli (•�t /v 3 211:3 I , WL EG.8.712.8, , PRODUCTION;Ss.1.8 aAC.9,1212232.5 -I f REFRAC.9.1225 OPEN HOLE 8.122552.551.0 • • OF Thr, THE STATE Alaska Oil and Gas Of�T AsKA Conservation Commission 1;7411-16177-- _l 333 West Seventh Avenue *ti., GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov James Ohlinger Staff CTD Engineer %AWMAP, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD2-39 Permit to Drill Number: 201-160 Sundry Number: 316-632 Dear Mr. Ohlinger: 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, P Cathy P oerster y�� Chair DATED this Pl_ay of January, 2017. RBDMS L'-- JAN 2 5 2017 r • RECEIVED STATE OF ALASKA DEC 2 0 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION / X646 APPLICATION FOR SUNDRY APPROVALS `!JJ 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations❑ Fracture Stimulate❑ Repair Well ❑ Operations shutdown❑ Suspend LI Perforate LI Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 I Perforate New Pool J Re-enter Susp Well ❑ Alter Casing ❑ Other: LI 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory D Development Q, 201-160v 3.Address: Stratigraphic 1J Service ❑ 6.API Number: PO Box 100360,Anchorage AK 99510 50-103-20387 i 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? flCgu CD2-39 i Will planned perforations require a spacing exception? Yes ❑ No E / 9.Property Designation(Lease Number): 04 10.Field/Pool(s): ADL 4)4621 310(17S— Colville River Field/Alpine Oil Pool y 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12651' < 7227' ! 9123' % 7227' 4087 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 117' 117' 1640 670 Surface 2654' 9-5/8" 2654' 2370' 3620 2020 Intermediate Production 9123' 7" 9123' 7227' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 3-1/2" L-80 8774' Packers and SSSV Type: Baker SAB-3 Packer Packers and SSSV MD(ft)and TVD(ft): 8673'MD/7074'TVD Camco TRM-43 SSSV 2207 MD/2020'TVD 12.Attachments: Proposal Summary 0 Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic 13 Development 0" Service ❑ 14. Estimated Date for 15.Well Status after proposed work: e Commencing Operations: 1/15/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Li 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. CMike Callahan , Contact Email mike.callahan(c�cop.com Printed Name es Ohlinger // Title Staff CTD Engineer /ter/ Signature !� 7 •715*-//1.ne 265 1102 /D�te /1` es/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3 \(..e — Le S2_. Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance 0 1-V5 E t4 1' Other: J30P I}-c-5/- pi-- 5,5 VrC 00 /7 1 ✓tvJ a r pre" vwi�c✓' res Z-5O° p5 9 �"l fcnc�v -c p l�,j plaGr -c. �►� a�J. v'tlJ Post Initial Injection MIT Req'd? Yes 1:1 No C✓�G _c z5. `12C, Spacing Exception Required? Yes 1:1 No Subsequent Form Required: /0 "— -0 7 p APPROVED BY RBDIVIS L�--JAI 2 5 2017 Approved by:alfegi7 9„; ., COMMISSIONER THE COMMISSION Date: i—¢—/7 11412..! /� (%. v 4 117--Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ORIGINAL • • )11 ConocoPhillips Alaska ECEIVED P.O. BOX 100360 °' ANCHORAGE,ALASKA 99510-0360 DEC 2 0 2016 December 20, 2016 AOGCC Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits and application to plug the CD2-39 (201-160) by cementing off the production lateral. This will be in preparation for CTD operations to drill a dual lateral out of CD2-39 using the coiled tubing drilling rig, Nabors CDR3-AC. A sundry application is attached to plug the CD2-39. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the existing production lateral in CD2-39. Attached to this application are the following documents: — 10-403 Sundry Application to Abandon CD2-39 (201-160) — Operations Summary in support of the 10-403 sundry application — Proposed CTD Schematic — Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-263-4180. Sincerely, Mike Callahan ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • CRU CD2-39 CTD Summary for Plugging Sundry (10-403) Summary of Operations: CRU well CD2-39 is an Alpine C-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C sand to the south and north of CD2-39. Prior to CTD operations, slickline will dummy off the GLV's, pressure test the tubing, and obtain a BHP measurement. Coil will run a Gamma/CCL and perforate the tubing tail at 8705', then mill out the XN-nipple at 8762' to 2.80" ID. An inflatable cement retainer will be set at 9,000' RKB and cement will be laid in up to 8600' (173' inside tubing tail) to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to abandon the original C Sand wellbore. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole to 8950' MD and set a mechanical whip-stock in the 2.80" pilot hole to kick off at 8900' MD. Both laterals will be completed with 2-3/8" slotted liner from TD with the second lateral liner top located inside the 3-1/2" tubing tail. Using the maximum anticipated formation pressure in the area of 4800 psi, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 4100 psi. CTD Drill and Complete CD2-39 Laterals: February 2017 Pre-CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU Coil: Run Gamma/CCL down to 9100' MD. 3. Punch 2' of holes in the 3'/2" tubing tail at 8705' MD. 4. Mill XN-nipple at 8762' RKB to 2.80" ID and clean out well. 5. Set inflatable cement retainer at 9,000' MD and lay in cement from 9,000' — 8,600' MD. 6. RU Slick-line: Tag top of cement and pressure test cement. 7. Prep site for Nabors CDR3-AC and set BPV. Riq Work -1/113 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. ,vki cll.1 2. CD2-39A Sidetrack (C sand - South) a. Drill 2.80" high-side pilot hole through cement to 8950' MD b. Caliper pilot hole c. Set top of whip-stock at 8900' MD d. Mill 2.80"window at 8900' MD. e. Drill 3" bi-center lateral to TD of 12600' MD (no liner, barefoot completion) 3. CD2-39AL1 Lateral (C sand - North) gg a. Kick off of aluminum billet at 8991' MD. C LA) PT-D b. Drill 3" bi-center lateral to TD of 11900' MD (no liner, barefoot completion) 4. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD3-AC. IVb rox'i 1gJ re v,`e✓ lir ceuI'�,y. Per CPIt prglo.E�o 4/cc /5 / // (Dt11`r n UC TD d ve/� (`P5 ver C vs��e/ �. ��'� �f��f rr�YG� Ep l/ " wen Page 1 of 2 `L/ 12/19/2016 • Post-Riq Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Page 2 of 2 12/19/2016 . . . 00. ci. 0 0 ,4 _. 2 2 _c a o o o o a) (nco � z > U T J o Qr co UH00 a0 co N0 1— N o CO _ c _ o E O Co (17 N = co co co r a O _ N U Y co NE Q N III i . e all E0 (0 Ct -0 a — — III III 7 t` (Q c O Y III III (1,cn ON III III 0 (N op E -m (h III III m g cD co m Y r III m (13 Y Y Y IY ti lc m a) EO IX N //a) III III mb co co O Co (fl '' III III Coa) O (n J a) a y�i N �� U` Q a c c<ca,ct ��- a) O C W 2 N Z W X .fl V O Z O �c �- 4sk m co m (( N 22 } cn co H Y W Q W t. N N C N " (V O a Y o- J i (6 a (6 (6 /�.1 0 0 c6 co c6 on ''''..1;14111:-:74." :'... 03 cu = 1a"4 V 'V^ VJ , msa d c o 0 a 0 L 0_ a) M N 0 0 ti Lo (nv Lo N Lo w N O CO© co.c 50 a) 0 20 Y .i WNS PROD 111 CD2-39 ConocoPhillips & Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore API/LAM Field Name Wellbore Status Inel(°) MD(ftKB) Act Rim(ftKB) c r,gpiytps 501032038700 ALPINE PROD 91.06 11,699.02 12561.0 ••• Continent 6/25(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date CD2-39.102920157:5625 AM SSSV:WRDP Last WO: 43.21 9/20/2001 Vertical schematic(actual) -- AnnotationI Depth(ftKB) End Date Annotation Last Mod By rid Date Last Tag:SLM 8,864.0 5/18/2013 Rev Reason:RESET WRDP 8 GLV C/O pproven 10/29/2015 HANGER:33.2 l IL- Casing Strings Casing Description OD(In) ID(In) Top(#813) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 37.0 117.0 117.0 62.58 H-40 WELD Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 36.8 2,654.1 2,369.7 36.00 J-55 BTC TUBING PUP;34.4 Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...W1ILen(I...Grade Top Thread PRODUCTION 7 6.276 35.1 9,122.5 7,227.2 26.00 L-80 BTMC I` Casing Description OD in ID(In) Top(ftKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread OPEN HOLE 6 1/8 6.125 9.122.5 12,651.0 Tubing Strings Tubing Description TUBING 4.5"x3.5" (Siring 3Ma.112..IID(In)2.992(Top(11103) (Set Depth(ft...lSee Depth(TVD)(...Wt(Ib/It) (Grade (Top Connection 33.2 8.774.1 7,128.3 9.30 L-80 81d-Mod Completion Details • Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Intl(°) Item Des Com (In) ` 41 33.2 33.2 0.00'HANGER FMC TUBING HANGER 3.500 TUBING'.38.2 CONDUCTOR;370-117.0 -, 1 124.2 124.2 0.06 XO Reducing CROSSOVER 4,5",12.66,IBT TO 3.5" 3.500 • 2,206.8 2,019.7 39.05 SAFETY VLV CAMCO TRM-4E SSSV(LOCKED OPEN)NOTE:USE 2.875 2.85"PACKING ON WRDP-1;OAL NOT TO EXCEED • 89.5' XO Reducing 124.2 8,639.8 7,053.8 49.93 NIPPLE HESX NIPPLE 2.813 • 8,672.7 7,074.2 53.59 PACKER BAKER SAB-3 PACKER 3.250 III 8,761.8 7,122.1 59.69 NIPPLE HES XN NIPPLE 2.750 8,772.8 7,127.7 5V/14 WLEG -WIRELINE GUIDE 2.920 WR DP;2,206.8 SAFETYVLV;2,206.11 r f>. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) r Top(TVD( Top Incl I Top(61413) (RNB) (') Des Com Run Date ID(in) 2,206.8 2,019.7 39.05 WRDP 2.81"TRM4E WRDP(S/N;HTS-620)W/2.83" 10/14/2015 1.562 PACKING. Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Bim(TVD) (RKB) (ftKB) (ftKB) INK BI Type Date Com 9,122.5 12,651.0 7,227.2 FRAC 2/10/2008 C-SAND FRAC 490,000#,16/30 BADGER SAND 11# 9,122.5 12,651.0 7,227.2 RE-FRAC 3/18/2013 C-SAND FRAC 30#linear I X-linked gel placing SURFACE;36.1.2,654.1 • 320.00041 of 16/20 proppant Into formation(all sand on location pumped).Cut 46 stage short and extended 75 stage.Flushed to compieBon. Mandrel Inserts St 11 N. GAS LIFT;3,985.1 Top(TVD) Valva Latch Pon Size TRO Run N Top(ftKB) IHKB) Make Model OD lin) Sem Type Type (In) (psi) Run Date Com ir1 3,985.1 3,414.6 CAMCO KBUG- 1 GAS LIFT GLV BK-5 0.188 1,996.0 3/25/2013 I M . 2 6,903.1 5,702.5 CAMCO KBUG• 1 GAS LIFT GLV BK-5 0.188 2,025.0 3/24/2013 M . 3 8,560.3 8,998.5 CAMCO KBUG- - 1 GAS LIFT OV BTM 0.250 0.0 10/14/2015 M Notes:General&Safety GAS LIFT;8,903.1 End Date Annotation 9/1/2010 NOTE;VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT.8.560.3 I K_ 1 NIPPLE;8,839.8 ' PACKER;8,672.7 �al® NIPPLE;8.761.8 - WLEG;8.772.8Ul PRODUCTION;35.1-9,122.5 FRAC;9,122.5 I (j RE-FRAC;9,122.5 AEt OPEN HOLE;9,122.5-12.651.0 • Loepp, Victoria T (DOA) From: Herring, Keith E <Keith.E.Herring@conocophillips.com> Sent: Tuesday,January 03,2017 10:50 AM To: Loepp,Victoria T(DOA);Callahan, Mike S Subject: RE:CRU CD2-39(PTD 201-160)and KRU 1E-20(PTD 183-005)Plug for Redrills Good morning Victoria, CRU CD2-39 BOP test pressure=4500 psi KRU 1E-20 BOP test pressure= 3500 psi Thanks, Keith Herring CTD Engineer 907.263.4321(Office) 907.570.2410(Mobile) 700 G Street,ATO—664 Keith.E.I-Ierring(ci conocophillips.com ConocoPhillips Alaska From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,January 03,2017 10:21 AM To:Callahan, Mike S<Mike.Callahan@conocophillips.com>; Herring, Keith E<Keith.E.Herring@conocophillips.com> Subject: [EXTERNAL]CRU CD2-39(PTD 201-160)and KRU 1E-20(PTD 183-005)Plug for Redrills Please provide BOP test pressures. 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(a 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.Loem@alaska.gov 1 • • Roby, David S (DOA) From: Ohlinger,James J <James.J.Ohlinger@conocophillips.com> Sent: Tuesday,January 03, 2017 3:27 PM To: Roby, David S (DOA); keith.herring@cop.com Cc: Callahan, Mike S Subject: RE: Sundry application for CRU CD2-39 well (PTD 201-160) Mike, I have a few questions about the sundry application to plug the subject well for redrill. 1) Why was this well selected for redrill? According to the AOGCC's records the well is producing about 700 BOPD with a water cut of about 40%,which is less than the—50%average for CD2 as a whole. It is believed that the wellbore (unlined—openhole completion) partially collapsed at the heel during a past frac job. The laterals are to increase throughput. 2) Will the proposed laterals be able to capture the reserves that are currently being captured by this well? Yes 3) In the Summary of Operations section of your application it states that"both laterals will be completed with 2- 3/8" slotted liner from TD with the second lateral liner top located inside the 3-1/2" tubing tail." But, under the Rig Work section it shows the completion of both laterals will be "no liner, barefoot completion". Which completion method is correct? The laterals will be unlined (barefoot). Thanks in advance, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 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 Dave Roby at(907)793-1232 or dave.robv@alaska.gov. 1 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geo gist in the upper left corner of Form 10-403 is checked. If the "Abandon" or 7 "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed 'ologist work)the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. STATE OF ALASKA AJOKA OIL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well rOther:Scale Inhibitor Treatment Si 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ws, Exploratory r 201-160 3.Address: 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service r 50-103-20387-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075 CRU 2-39 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 12651 feet Plugs(measured) none true vertical 7228 feet Junk(measured) none Effective Depth measured 12651 feet Packer(measured) 8673 true vertical 7228 feet (true vertical) 7074 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 117 117 SURFACE 2617 9.625 2654 2370 PRODUCTION 9087 7 9123 7227 RECEIVED OCT 152015 Perforation depth: Measured depth: open hole completion 9123'-12651' True Vertical Depth: 7227'-7228' SCANNED NOV 2 32015 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 8774 MD,7128 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER SAB-3 PACKER @ 8673 MD and 7074 TVD SAFETY VLV-CAMCO TRM-4E SSSV @ 2207 MD and 2020 TVD, locked open/WRDP installed. 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9123-12651' 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 679 1001 261 774 217 Subsequent to operation 717 923 287 700 211 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations P Exploratory r Development 17 Service r Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil t Gas r WDSPL E 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.O.Exempt: none Contact Kerry Freedman (a,265-6579 Email Kerry.C.Freedman(a�conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature /Lk) ./Lie.e..141.te.—____ Phone:265-6579 Date © 'y, Z J 15— VTC 10/7415 y' (0/'//9 RBDMS OCT 212015 Form 10-404 Revised 5/2015 Submit Original Only • • • CD2-39 Scale Inhibition Treatment 9/19/15 Hybrid Scale Inhibitor Squeeze Job pumped 9/19/15 from 08:36 to 16:22. LRS= Little Red Services - Initial pressure TBG/IA/OA-403/670/598 - LRS pumped 128 bbls Diesel/M209/WAW5206 pre-flush at 1.5- 1.7 bpm,TBG/IA/OA- 0/937/624 - LRS pumped 129 bbls Seawater/SCW3001WC scale inhibitor main treatment at 1.7 bpm, TBG/IA/OA—0/1280/592 - LRS pumped 247 bbls Crude Oil/M209 over-flush at 1—3.4 bpm,TBG/IA/OA—1121/1797/572 Interval treated: 9,123'—12,651' WNS PROD • CD2-39 ConoCoPhillips well attributes Max Anglia s MD TD Alaska(no ' Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) "c,xx ,1+,tipn,', 501032038700 ALPINE PROD ' 91.06 11,699.02 12,561.0 -•- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CD2-39.3/3120154:56:24 PM SSSV:WRDP Last WO: 43.21 9/20/2001 Vertical schematic{actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,864.0 5/18/2013 Rev Reason:RESET WRDP lehallf 3/31/2015 HANGER;33.2_ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 37.0 117.0 117.0 62.58 H-40 WELD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)...Wt/Len(I...Grade Top Thread r SURFACE 95/8 8.921 36.8 2,654.1 2,369.7 36.00 J-55 BTC TUBING PUP;34.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ii PRODUCTION 7 6.276 35.1 9,122.5 7,227.2 26.00 L-80 BTMC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WSLen(I...Grade Top Thread OPEN HOLE 61/8 6.125 9,122.5 12,651.0_ Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Iblft) Grade Top Connection TUBING 4.5"x3.5" 31/2 2992 33.2 8,774.1 7,128.3 9.30 L-80 8rd-Mod Completion Details Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com Nominal ID n) !b' --8PY 33.2 33.2 0.00 HANGER FMC TUBING HANGER (3.500 TUBING,38.2 CONDUCTOR;37.0-117.0 .. 124.2 124.2 0.06 XO Reducing CROSSOVER 4.5",12.68,IBT TO 3.5" 3.500 2,206.8 2,019.7 39.05 SAFETY VLV CAMCO TRM-4E SSSV(LOCKED OPEN)NOTE:USE 2.875 2.85"PACKING ON WRDP-1,OAL NOT TO EXCEED 89.5' XO Reducing.124.2 a 8,639.8 7,053.8 49.93 NIPPLE HES X NIPPLE 2,813 8,672.7 7,074.2 53.59 PACKER BAKER SAB-3 PACKER 3.250 8,761.8 7,122.1 59.69 NIPPLE HES XN NIPPLE 2.750 8,772.8 7,127,7 59.94 WLEG WIRELINE GUIDE 2.920 WRDP;2,2068 SAFETY VLV;2,206:8 ±} Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) C) Des Com Run Date ID(in) 2206.8 2,019.7 39.05 WRDP 2.81"TRM-4E WRDP(S/N:HTS-620)W/2.83" 3/29/2015 1.562 PACKING. Stimulations&Treatments `;, Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 9,122.5 12,651.0 7,227.2 FRAC 2/10/2008 C-SAND FRAC 490,000 8,16/30 BADGER SAND : :3 11# 9,122.5 12,651.0 7,227.2 RE-FRAC 3/18/2013 C-SAND FRAC 30#linear/X-linked gel placing SURFACE;368-2,654.1-a 320,000#of 1620 proppant into formation(all sand on location pumped).Cut 4#stage short and extended 78 stage.Flushed to completion. Mandrel Inserts St ati GAS LIFT;3.985.1 on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com i3,985.1 3,414.6 CAMCO KBUG- 1 GAS LIFT GLV BK-5 0.188 1,996.0 3/25/2013 M 2 6,903.1 5,702.5 CAMCO KBUG- 1 GAS LIFT GLV BK-5 0.188 2,025.0 3/24/2013 M 3 8,560.3 6,998.5 CAMCO KBUG- 1 GAS LIFT OV BK 0.250 0.0 3/24/2013 M GAS LIFT;6903 1 -. General&Safety :� End Date Annotation 9/1/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT;8.560.3. NIPPLE;8639.8 . .ri:• PACKER;8,672.7 1 NIPPLE,8,761 8 i, WLEG,8,772.8 , PRODUCTION;35.1-9,122 5 FRAC,9,122 5 RE-FRAC;9,122.5 'I OPEN HOLE;9,122.5-12651.0 Imag( '~roject 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. Well History File Identifier RES DIGITAL DATA ~/"' Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: R~~escanNeeded BY; BEVER~tNCENT SHERYL MARIA WINDY Project Proofing BY: BEVERL~NCENT SHERYL MARIA WINDY Scanning Preparation x30= + OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVE~n-Scannable) ~ Logs of various kinds {,,~~~ [] Other " TOTAL PAGES i r"')Z~') BY: BEVERL~CENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ._~ YES BY: BEVERL~~VINCENT SHERYL MARIA WINDY DATE:/6'~_~/~S/~%~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERLY~INCENT SHERYL MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAY$CALE OR COLOR IMAGES ) NO NO RESCANNED Bt: BEVERLY ROBIN, VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/10/02Rev3NOTScanned.wpd STATE OF ALASKA ALA OIL AND GAS CONSERVATION CO.SION REPORT OF SUNDRY WELL OPERATIONS t. Operations Performed: Abandon j Repair w ell 1 Rug Perforations j""" Perforate E Other i v Alter Casing r Pull Tubing E Stimulate - Frac pi Waiver 1 Time Extension E Change Approved Program EOperat. Shutdow n E Stimulate - Other E Re -enter Suspended Well f 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development (;i Exploratory E " 201 -160 3. Address: 6. API Number: Stratigraphic j`°' Service r P. O. Box 100360, Anchorage, Alaska 99510 50 103 20387 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075 V CD2 -39 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): w none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 12651 feet Plugs (measured) none true vertical 7228 feet Junk (measured) none Effective Depth measured 12651 feet Packer (measured) 8673 true vertical 7228 feet (true vertical) 7075 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 117 117 SURFACE 2617 9.625 2654 2369 PRODUCTION 9087 7 9122 7227 • Perforation depth: Measured depth: open hole completion from 9122'- 12651' True Vertical Depth: 7227' -7228' SCANNED APR 2 2 2013 Tubing (size, grade, MD, and TVD) 3.5, L - 80, 8774 MD, 7128 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER SAB -3 PACKER @ 8673 MD and 7075 TVD SSSV - CAMCO TRM -4E SSSV @ 2207 MD and 2020 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 912312651' • Treatment descriptions including volumes used and final pressure: ... 320000# of 16/20 proppant e.,cc P5/ 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 1745 3691 239 — 244 Subsequent to operation 563 2930 501 -- 279 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory j Development fii r Service E Stratigraphic j 16. Well Status after work: e Oil r7 Gas i WDSPL E Daily Report of Well Operations )00( GSTOR fl WNJ r WAG j GINJ ("- SUSP I SPLUG I 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: 313 -062 Contact Robert Blakney a 265 -6417 Email Robert.G.Blaknevaconocophillips.com Printed Name Robert Blaknev Title Completions Engineer Signature Phone: 265 -6417 Date /n e l 3 ROOMS APR 0 4 201 el" Form 10-404 Revised 10/2012 ` Submit Original Only CD2 -39 Well Work Summary DATE SUMMARY 3/9/2013 DRIFT TBG. TO 2.84" TO 2206' RKB, PULL 3.5" WRDP (CZS -0317) @ 2206' RKB, SET 2.81" CAT SV @ 8,761' RKB, PULLED OV @ 8560' RKB, READY FOR CIRC OUT. 3/10/2013 CIRCULATED 304 BBLS SEA WATER FREEZE PROTECTED 90 BBLS CRUDE IA & TBG. SET 1" DV @ 8560' RKB, MITT TO 3500 PSI PASS, MITIA TO 3500 PSI PASS, ATTEMPT TO PULL CAT SV , BAILED ABOUT 10' SCALE OFF CAT SV @ 8761' RKB, IN PROGRESS. 3/11/2013 BAILED SCALE OFF CAT SV, PULL CAT SV @ 8761' RKB, GAUGE TREE TO 3.86 ", SET FRAC SLEEVE @ 2206' RKB 2.3" ID. COMPLETE. 3/16/2013 Attempted C -sand fracture treatment. Pressured out 56 bbls into breakdown stage; suspect fill plugging well. Well left loaded with 30# linear gel, able to squeeze in —8 bbls of diesel. Pulled treesaver and rigged down treating iron from in front of well to allow slickline and CTU access. 3/16/2013 GAUGE TBG TO 2.85" TO 2207' RKB. PULLED FRAC SLEEVE @ 2207' RKB. GAUGE TBG TO 2.77" TO 8762' RKB. NO OBSTRUCTION TO XN -NIP. READY FOR COIL. 3/17/2013 PERFORMED FCO TO TAG AT 9045' CTMD, WASHED DOWN TO 9107' CTMD LOST RETURNS AND STARTED INJECTIVITY TEST. PUMPED 70 BBLS TOTAL AT 5.2 BPM WHP = 0 PSI. PERFORMED MIT ON THE IA TO 3000 PSI FOR 30 MINUTES. 3/17/2013 SET 2.81" FRAC SLEEVE (OAL= 55 1/2 ") @ 2207' RKB. READY FOR FRAC. 3/18/2013 Performed C -sand fracture treatment using 30# linear / X- linked gel placin320,000# of 16/20 proppant into - formation (all sand on location pumped). Cut 4# stage short and extended 7# stage. Flushed to completion, 30 bbls of diesel freeze protect in hole. Broke standpipe at the ground and capped; will return tomorrow to finiith rig down" &move to well #42 — 3/24/2013 PULLED FRAC SLEEVE @ 2206' RKB. BRUSH & GAUGE TBG TO 2.77" TO 8762' RKB. SET AVA CATCHER (OAL= 36 ") @ SAME. PULLED DV @ 8560'. REPLACED WITH 1/4" OV. PULLED DV 6903' RKB. REPLACED WITH 3/16" GLV (TRO= 2025). IN PROGRESS. 3/25/2013 PULLED DV @ 3985' RKB. REPLACED WITH 3/16" GLV (TRO= 1996). PULLED CATCHER @ 8762' RKB. SET FRAC SLEEVE (OAL= 56 ") © 2206' RKB. READY FOR FLOW BACK. WNS 40 CD2 -39 ConocoPIillip$ ` llit Well Attributes Max Angle & MD TD Alaska, 111C. T :e 2i Wellbore APUUWI Field Name Well Status Inc( ( °) MD (ftKB) Act Btm (ftKB) LO /oitrd0pc 'r, 501032038700 ALPINE PROD 91.06 11,699.02 12,561.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date ' SSSV: WRDP Last WO: 43.21 9/20/2001 Well Canna - CD2 -39, 3/27/20'. '. Schematic -Actual 139 53 07 AM Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: GLV C/O osborl 3/27/2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd CONDUCTOR 16 15062 37.0 117.0 117.0 62.58 H WELD HANGER. 33 j r Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd ^ - -" SURFACE 95/8 8.921 36.8 2,654.1 2,369.3 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd PRODUCT 7 6.276 35.1 9,122.5 7,227.2 26.00 L - 80 BTMC Casing Des String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd TUBING PUP, 34 OPEN HOLE 61/8 6.125 9,122.5 12,651.0 a Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) .. String Wt... Stnng ... String Top Thrd TUBING 4.5"x3.5" 3 1/2 I 2.992 I 33.2 8,774.1 J 7,128.0 I 9.30 L-80 8rd -Mod Completion Details Top Depth � . -... (TVD) Top Intl Nomi... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 33.2 33.2 -0.50 HANGER FMC TUBING HANGER 3.500 TUBING, 38 124.2 124.2 0.06 X0 Reducing CROSSOVER 4.5 ", 12.6#, IBT TO 3.5" 3.500 CONDUCTOR, 2,206.8 2,019.7 39.05 SAFETY VLV CAMCO TRM-4E SSSV (LOCKED OPEN) ON 2.81 X -LOCK (S/N 1.562 C25 -0317) 1.562" ID. NOTE: USE 2.875" PACKING ON WRDP -1 00 Reducing, 8,639.8 7,053.4 50.42 NIPPLE HES X NIPPLE 2.813 124 8,672.7 7,075.3 57.69 PACKER BAKER SAB -3 PACKER 3.250 Or 8,761.8 7,121.1 57.92 NIPPLE HES XN NIPPLE 2.750 I I I 8,772.8 7,127.2 58.79 WLEG WIRELINE GUIDE 2.920 SAFETY VLV, Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) 2207 N Top Depth (TVD) Top Intl ir Top (ftKB) (ftKB) (3 Description Comment Run Date ID (in) 8,759.0 7,119.6 57.70 CATCHER CATCHER 3/24/2013 Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (ND) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 9,122.5 12,651.0 7,227.3 FRAC 2/10 /2008 C -SAND FRAC 490,000 8, 16/30 BADGER SAND 11# 9,122.5 12,651.0 7,227.3 RE -FRAC 3/18/2013 C -SAND FRAC 30# linear / X- linked gel placing SURFACE, _.4 , 320,000# of 16/20 proppant into formation (all sand 37 - 2,654 on location pumped). Cut 4# stage short and extended 7# stage. Flushed to completion. IN Notes: General & Safety End Date Annotation GAS LIFT, 9/1/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 g 3.985 1 GAS LIFT, 6,903 GAS LIFT, it 8,560 ll NIPPLE. 8,640 PACKER. 8.673 CATCHER, 8.759 { NIPPLE, 8,762 II I Mandrel Details Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Run WLEG, 8,773 1 N... Top (ftKB) (MO) (°) Make Model (in) Sery Type Type (le) (psi) Run Date Com... 1 3,985.1 3,414.6 38.79 CAMCO KBUG -M 1 GAS LIFT GLV BK -5 0.188 1,996.0 3/25/2013 2 6,903.1 5,702.6 39.50 CAMCO KBUG -M 1 GAS LIFT GLV BK -5 0.188 2,025.0 3/24/2013 3 8,560.3 6,998.4 43.07 CAMCO KBUG -M 1 GAS LIFT OV BK 0.250 0.0 3/24/2013 PRODUCTION, 35 -9,122 FRAC, 9,123 RE -FRAC, 9,123 TD (C D2 12,5 -39) 61 H /, yyp 41, ` OPEN HOLE, �.�� 9,123- 12,651 OF TFj 1 I � � � �,, s THE STATE Alaska i Gas �� \\ / /i ,, f LAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue 11100Z&._ Anchorage, Alaska 99501 -3572 ALAS* Main: 907.279.1433 Fax: 907.276.7542 Robert Blakney N8) LI 0 6 2013 Completion Engineer ConocoPhillips Alaska, Inc. /64° P.O. Box 100360 i Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -39 Sundry Number: 313 -062 Dear Mr. Blakney: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair 4 DATED this day of February, 2013. Encl. III STATE OF ALASKA RECEIVED FEB 7 ALASKA OIL AND GAS CONSERVATION COMMISSION 07 3 0 2 1 1 1 1 '1 1 3 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1. Type of Request: Abandon r Plug for Redrll E Perforate New Fboi [ Repair wef IT Change Approved Rogram I -_ Suspend r" Plug Perforations r Perforate I - ` Pull Tubing r Tkne Extension r' Operational Shutdown r Re -enter Susp. Well (- Stimulate NW. Aker casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drin Number: ConocoPhillips Alaska, Inc. Development p . Exploratory r 201.160 • 3. Address: 6. API Number: Stratigraphic r Service f" P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20387 - 00 • 7. if perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require sparing exception? Yes r No Imo' CD2 - 39 - 9. Property Designation (Lease Number): 10. Field/Pool(s): ACC 380075 • Colville River Field / Alpine Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12651 - 7228 12651' • 7228' none nor* Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 117' 117' SURFACE 2617 9.625 2654' 2369' PRODUCTION 9087 7 9122' 7227' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open tole completion from 9122'42651' 7227' -7228' 3.5 L-80 8774 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER SAB-3 PACKER • MD= 6673 TVO= 7074 SSSV - CAMCO TRM-4E • MD= 2207 TVD=2010 12. Attachments: Description Summery of Proposal • ,W 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch J- Exploratory r Stratigraphic r Development p • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2013 Oil d . Gas r V DSPL r Suspended l 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: Robert Blakney 265-6417 Email: RRobelt.G.BlaIMInconoroDh1I s.com Printed Name : f ! ' t : _ . W.1 Title: Completions Engineer Signature 1 // > Phone: 265.6417 Date 2 f3 / J Commission Use Only Sundry Numbers k3� `� `� /1Z Conditions of approval: Notify Commission so that a representative may witness ✓✓ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other. RBDMS FEB 15 2013 Spacing Exception Required? Yes ❑ No (i Subsequent Form Required: /0 , 4 0 L- APPROVED BY Approved b y : pr ¢ app 'cation is va 1.1 ig#hs from #h � +a1. Date: 2 ^ 1 - / 3 Form 10-403 (Revised 10/2012) vi_ f Submit Form and Attachments In Duplicate ORIGINAL ,2/j3//3 ,, �� 63 5 • • • �, 1� WNS CD2-39 Conoca'hillips I 1 1' Well Attributes Max Angle & MD TO L ;; Welibore APIIUWI FNid Name Well Status Intl(') 190(9K8) Alt Blm(11KB) NBSka. kw: 501032038700 ALPINE PROD 91.06 11,699.02 12651.0 Laneofhltps `e " Comment 1-129 (ppm) Oahe Annctation End Dale K9.Ord (fl) Rlg Release Dale or Was Conan - GD239, IO.d0.2010e Pxl SSSV: WROP LasI WO. 43.21 9/20/2001 Schematic - AMA Annotation Depth OMB) End Date Annotation Lest Nod.., End Dale Last Tag. Rev Reason: Lock out SSSV, Set WROP Imosbor 10/29/2010 - .. -- Casing Strings Casing Description - String 0... String ID ... Top OMB) Set Depth (1., Set Depth (TVD)... String Wt-. String... String Top Thrd CONDUCTOR 16 15.062 37.0 117.0 117.0 62.58 11 WELD HANGER, 33 --, ...r Casing Description String 0... String 10... Top OMB) Sal Depth (1... Set Depth CND)... Siring LYI... String ... Siring Top Thrd SURFACE 95/8 8.921 36.8 2,654.1 2,3603 36.00 J - 55 BTC Casing Description String O. Stria 112..Top (fIKB Set Depth 1... Sel Depth VD ... Slrin VW_ String String Top Thrd String ) ( R I D 0 �� n9 L; PRODUCTION 7 6.151 35.1 9,122.5 7,227.2 26.00 L - 80 BTMC Casing Description String O... String 10 ... Top (1165) Sat Depth (I... Set Depth (TVD)... (OO Slring... Siring Top Thrd 105410 PUP , ( ! OPEN HOLE 61/8 6.125 9,122.0 12,651.0 ■ 11 < Tubing Strings Tubing Description String 0... 511108 l0 ... Top ((MB) Set Depth (1... Set Depth (TVD) ... Slring .. 51r1n5... Slring 10p T TUBING 4.5'x3.5" I 312 I 2.992 33.2 8.714.1 7,128.0 8.30 Wt. I L - 00 Brd - d Completion Details Top Depth (TVD) Top Mct Nom I.,. Top (RKB) MRS) 1') Item Description Comment ID (10) ti• 33.2 33.2 -0.50 HANGER FMC TUBING HANGER 3.500 I 124.2 124.2 0.06 XO Reducing CROSSOVER 4.5 12.69, I87 TO 3.5" 3.500 ruer:c, 30 1 2206.8 2.019.7 39.05 SAFETY VLV CAMCO TRM4E SSSV (LOCKED OPEN) ON 2.81 X LOCK (S/N 1.562 cono 37 1 n C25 -0317) 1.562" 1D. NOTE: USE 2.875" PACKING ON WRDP -1 8,639.8 7,053.4 50.42 NIPPLE HES X NIPPLE 2.813 xO Retlurf2T. 124 8.672.7 7,075.3 57.69 PACKER BAKER SAB PACKER 3.250 124 8,761.8 7,121.1 57.92 NIPPLE HES XN NIPPLE 2.750 8,772.8 7,127.2 58.79 WLEG WIRELINE GUIDE 2.920 Stimulations & Treatments SAFETY VLV, TAM TAM Top Max Wm Top Depth Depth th 2.207 eon Depth Depth gyp) (TVD) (11K8) OMB) (11K8) OMB) Type Date Comment 9,122.0 12,651.0 7,227.2 FRAC 2/10 /2008 C -SAND FRAC 490,000 9, 16/30 BADGER SAND 114 . 1:3 : :_i .. L Notes: General & Safety End Date Annotation 9/1/2010 NOTE. VIEW SCHEMATIC w /Alaska Schemahc9.0 SURFACE, __A 37 -2,631 CAS 11FT- 5985 GAS LIFT, 6 e03 C.0611111, 1 8 560 O PPLE, 8 610 PACKER, 8673 - -- - - -- 1 a NIPPLE, 8.762 Mandrel Details Top Depth Top Port SYLEG.8773 - - (TVD) Intl 00 Valve Latch She TRO Run Sin Top (11KB) (fIKB) P) 11elte Model (In) Sery TYpe TYPe On) (PM) Run Date Com „- 1 3,985.1 3,414.6 38.79 CAMCO KBUG -M 1 GAS LIFT DMY 8K -5 0.000 0.0 1/26/2000 2 6,903.1 5,702.6I39.50 CAMCO KBUG -M 1 GAS LIFT DMY BK -5 0.000 0.0 128/2008 3 8,560.3 8,990.4 43,07 CAMCO KBUG-M 1 GAS LIFT OV BK 0.250 0.0 2/112008 P900602109. 35-9 122 ® o ■ FRAC, 9.122 OPEN HOLE, TT or 8,122.11651 o 70)002.39), \ 12,851 • • CD2 - 39 Sundry Application Drilling for CD2 -39 was completed in September of 2001 targeting the C Sand formation and was completed with 3.5" tubing. It was initially hydraulically fractured in 2008, placing —490,000#'s of 16/30 Badger Sand. We intend to re- stimulate the C Sand formation with a single stage treatment placing — 320,000#'s of 16/20 CarboLite. If the stimulation is successful we anticipate an increased production of 416 bpd in 2013. Proposed Procedure: Schlumberger Pumping Services: (C Sand) 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. 2700 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 8,000 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 180 bbl breakdown stage (25# linear gel, WF130) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus 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 @ 20bpm with a maximum expected treating pressure of 3900 psi. Stage 1 • 680 bbls YF130FX -D Pad • 239 bbls YF130FX -D w/ 2 ppa 16/20 Carbolite • 442 bbls YF130FX -D w/ 4 ppa 16/20 Carbolite • 408 bbls YF130FX -D w/ 4 ppa 16/20 Carbolite • 535 bbls YF130FX -D w/ 7 ppa 16/20 Carbolite • Flush with 100 bbls of linear fluid (WF130) and freeze protect • Total Sand: Approx. 320,000 lbs 16/20 Carbolite 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). RB • 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) Cement Evaluation of CD2 -39 and wells within 1 /4 mile of CD2 -39 CD2 - 39: 7" Casing cement job was pumped on 9/13/2001 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by mud at 8 bpm. The plug was bumped at 1000 psi and the floats held. The casing was pressure tested to 3500 psi and held for 30 minutes. CD2 - 35: 7" Casing cement for an injection well was pumped on 2/30/1998 as designed, indicating competent cement operations. The plug was bumped and floats held. The casing was pressure tested to 3500 and held. CD2 - 27: 7" Casing cement job was pumped on 11/8/2003 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by mud at 5 bpm. The plug was bumped at 1500 psi and the floats held. CD2 - 38: 7" Casing cement job was pumped on 9/2/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.65 ppg mud. The plug was bumped at 1400 psi and the floats held. CD2 - 53: 7" Casing cement job was pumped on 7/12/2004 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped at 1130 psi and the floats held. The casing was pressure tested to 3500 psi and held for 30 minutes. CD2 -57: 7" Casing cement job was pumped on 5/26/2004 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.8 ppg mud. The plug was bumped to 1100 psi and floats held. 10% returns were observed during the job. A pressure test was performed to 3500 psi and held for 30 minutes. Alpine 1B: 7" Casing cement job was pumped on 3/12/1995 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 10.6 ppg brine. The plug was bumped to 1800 psi and floats held. A pressure test was performed to 3000 psi and held for 30 minutes. 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' /4 mile radius or any other nearby well. RB • Stimulation Surface Rig -Up Pler Taft Tale Tank 1 +t. + ' p. Fs a :A / LL o ' • Minimum pressure rating on all surface treating lines 10,000 psi t +l . '. • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi — • Frac pump trip pressure setting are staggered and 3 set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. a,y '11r% l H � y r III 7 0. J V &Ind 0 Pup -Off Tare 5 Purip Tru do P•Jp -C Turk ch rd _ . r u e• Frac Pump - rte{- - i r'1 Hat F'irp Frac Pump h."! N + ' I4 Frac PLrlp Frac Pump 1'.41 yx . • r'..1 Frac F'rk rp RB • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION ERAS / ON ((AIME; X 5 * 4 -.,. P x. x : ! o, �, ., V � : 4 k., uwvw. c S , „ a * nt ,.F RE MOTE OPERATE Cr .3' - ,��i ; �i�e , ;'' ?AMIER WQ VE t i '�•s`f , MANUAL OPERATED "'` MASTER VALVE f ry Stinger \ , Stinger \ a m ' .. "AIL ,mm VALVL n .. ePEt { tog o, ti � 1 _ E'i£}LYr TEE AND lif "f; t r VENT VALVE' WE RLHEAD . W. OPEN 1 ._ .. vALVrS OtIAG PACKOEF s 1 '4 ASS£ MM. Y IN ' PEALE 04 7t,7ONG ;-r i c. t 1 • 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 RB • CD2 -39 Alpine C Frac Model 1 stage stimulation • F rac Design Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl /min) (gal) (Ib /mgal) (PPA) • Pad 20.0 YF130FIexD 28560 30.0 0.00 2.0 PPA 20.0 YF130FIexD 10039 30.0 16/20 C -Lite 2.00 4.0 PPA 20.0 YF130FIexD 18578 30.0 16/20 C -Lite 4.00 4.0 PPA 20.0 YF130FIexD 17149 30.0 16/20 C -Lite 4.00 7.0 PPA 20.0 YF130FIexD 22490 30.0 16/20 C -Lite 7.00 Flush 20.0 YF130FIexD 4025 30.0 0.00 Fluid Totals • 100,842 gal of YF125FIexD 9000 gal of WF130 Proppant Totals 320,400 lb of CarboLite 16/20 Model Results Initial Fracture Top TVD 7172.0 ft Initial Fracture Bottom TVD 7232.0 ft Propped Fracture Half- Length 433.0 ft • EOJ Hyd Height at Well 131.5 ft Average Propped Width 0.382 in • Disclaimer Notice: — This model was generated using vendor supplied modeling • software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. s • c 6?�1 „ '4' a -6P62 ': . cm-1:13v 41 •..... -..-- -.-.'-. • "...:.. ........ • . ( ' \../ ...• i !•• ..-.....:-. • :. ' ` ' ". ' . , , . ''{ i i':..'' "••. 13 z .44PB1 CD B1 `P �� % •.• '.+ %t$ '' x : .;:.. •" •••., CD2 -29 •'/ • �'Q, 0 '.;%;:.'•. - 50PB}': ';! « lyD�2, 34 1 T �• ' ALPINE 1 CD2 -19 Ck71 -33 • CD • • A \ ••• _ . ail -34 • • • • CD2 -39PB1 CD145 • • • 111( ri y \ CD2 -35 CD1 =43 _ 1 -39PB1 • C ©2-49 DQ -50 ` • CD2 -44 T A ALPINE 1B•, CD1 -38PB1 • CD2 -45 T, • C ®2 -42 CD2 -35A 4 , Legend • Well t Suspended • CD2- 467PB1 D2 -4° • T P + + Service CD2 41 Producer NEVE 1 � '. • Observation • • '•GD2�67 CD2 4B ♦ Injection: SW . '. -51 ♦ Injection: SAPW ' ♦ ,' t • Injection: PW •• ' CD2 -52 Injection: MWAG • C.2-47 ;•CD2 -58L1 A CTIVE, • INJ, MG S CFS2 -55 •; • ACTIVE, INJ, IWAG I - * • ACTIVE, INJ, GAS • CD2 -60PB1 • ACTIVE, INJ, DG • ACTIVE, INJ, <Null> CD4 -16 Disposal • • ` 1/4 Mile Radius v. CD2 -36PB1 v CD2 -53 CD2 -27 :- CD4 208 CD2 -57 • L f '' CD2 58 ConocoPhillips T'•,CDir08PB1 CD4 -210 T -+ CD2 -39 Fracture Radius % 0� CD4 -3 ll �••. : CD2 -37 • CD2 -36 ' 1 Atli CONFIDENTIAL azs of miles FracProgram2013.mcd CSR 1 -10 -2012 _ _ __ `~~lfEC~ • STATE OF ALASKA • ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~3 ~~ ~~~ ~ ~~ ~ •~~ REPORT OF SUNDRY WELL OPERATtON~ `'`'' ~omm~ssi~r4 ,4rr~i"~n-~f.~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^/ vscale squeeze . 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: COnOCOPhilllps Alaska, InC. Development ~ ' Exploratory ^ 201-160 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20387-00' 7. KB Elevation (ft): 9. Well Name and Number: RKB 36.8' CD2-39 8. Property Designation: 10. Field/Pool(s): ADL 380075 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 12651' feet true vertical 7228' feet Plugs (measured) Effective Depth measured 12651' feet Junk (measured) true vertical 7228' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 114' 114' SURFACE 2617' 9-5/8" 2654' 2370' PRODUCTION 9085' 7" 9122' 7227' Perforation depth: Measured depth: open hole completion from 9122'-12651' true vertical depth: 7227'-7228' Tubing (size, grade, and measured depth) 4.5" / 3.5", L-80, 125' / 8774' MD. Packers &SSSV (type & measured depth) Baker SAB-3 pkr @ ss82' Camco TRM-4E SSSV @ 2206' 12. Stimulation or cement squeeze summary: Intervals treated (measured) see 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 2558 3033 167 -- 259 Subsequent to operation 2521 3223 141 - 285 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 NIA if C.O. Exempt: none Contact Tim Schneider @ 265-6859 Printed Name Tim S Heider Title Alpine Staff Engineer ~ Signature ~ Phone: 265-6859 Date ~ ~ ~'~ ! Pre a h ron Allsu -Dr ke 263-4612 V Form 10-404 Revised 04/2006 ORIGINAL Submit Origi O/nly ~l 1J Cc~n©~c~~'hillips Alas~Ca, Ir-~= _ ~ ~~ D2-39 TUBING (1258774, OD:3.500, ID:2.992) SURFACE (0.2654, OD:9.625, W 1:36.00) PRODUCTION (o-s122, OD:7.000, Wt:26.00) Gas Lift andrel/Dummy valve 2 (6903-6904, OD:5.390) Gas Lift MandrelNalve 3 (8560.8561, NIP (8639-8640, OD:3.500) PACKER (8682-8683, OD:5.950) NIP (8761-8762, OD:3.500) FRAC -~ ~ (9122-12651) `' , ' OPEN HOLE ~ • , (9122-12651, ~ 1 ~ ~ • ~ i ~ • ~,, / • • ALPINE CD2-39 Tubing String -TUBING Size Top Bottom TVD Wt Grade Thread 4.500 0 125 125 12.60 L-80 8RD 3.500 125 °774 7120 9.30 L-80 EUE Stimulations $ Treatments Interval ~ -- Date Type Comment ~9122 - 12651 2/10/2008 i FRAC i C-SAND Ff2AC 490.000 #. 1630 BADGER SAND 11# !Gas Lift Mand rels/Valve s St MD TVD Man Mfr Man T pe y V Mfr V Type V OD I I Latch PoR TRO ~ Date Run 1 Vlv l ~ I Cmnt I 1 3985 3414 CAMCO KBG-M I DMY 1.0 BK 0.000 0 1~0~ ~ Other (plugs, equip., etc.) - WSR -Well Service Report Well Service Report Page 1 of 1 Weil Job Scope CPAI Rep CD2-39 Scale Inhibition Shirtliffe, Ryan Date Daily Work Unit Number 5/17/2009 32 Initial & Final TIA Initial - 675/1100/500 Field: ALPINE Pressures: Final -VAC/1150/350 Pumped anon-aqueous scale squeeze into well. Pumped a 64bb1 pre-flush pill of 24 hr. crude+M209, then 12.7 bbls Crude+5206, 83.2bbls MEG+3001, 12.7 bbls Summary crude+5206 and flushed with 540.2bbls crude. Pumped the job at 4bpm, and pressure varied from 600 psi down to 250. End of job well was on vac. STARTTIME OPE.RAT.ION 01:00 PM Rig in and pressure test lines to 2000psi. 02:00 PM Pump 64bb1 pill of crude/M209 chemical at 4bpm, 600psi. 02:15 PM Pump 12.7bbls crude+5206, 83.2bbls MEG+3001, and 12.7bbls crude+5206 at 4bpr. 700psi. 02:45 PM Pump crude flush volume of 540.2bbls. Started pumping at 4bpm, 650psi. Gradually reduced rate to 2 bpm. 05:45 PM Rig out and release equipment. Fluid Type To Well From Well Non- recoverable Nate OIL 629 COMPLETION 83 MEG+3001 FLUID http://akapps. conocophillips.net/alaskawelleventquery/worklog.aspx?ID=6BAC2C6... 6/5/2009 • FEB 2 1 200& STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Ail & Gas C, ons. Gammission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^/ Other ^ Alter Casing ^ Pull Tubing ^ Pertorate 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: COnOCOPhIII1pS Alaska, Inc. Development ^~ Exploratory ^ 201-160 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20387-00 7. KB Elevation (tt): 9. Well Name and Number: RKB 52' CD2-39 ` 8. Property Designation: 10. FieldlPool(s): ADL 414843 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 12651' feet true vertical 7228' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 117' 16" 117' SURFACE 2602' 9-5/8" 2654' PRODUCTION 9070' 7" 9122' OPEN HOLE 3529' 6-1/8" 12651' ~~ ~~B ~ g zoa~ Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 3-1 /2" , L-80, 8774' MD. '' Packers &SSSV (type & measured depth) packer=Baker SA63 Packer= 8682' SSSV= Camco TRM-4E SSSV= 2206' 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 2671 4193 24 828 293 Subsequent to operation 3470 5776 70 1240 312 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^~ ~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-374 Contact Tim Schneider Printed Name Ti c Ider Title Production Engineer Signature ` G.~ Phone 265-6859 Date Z-~ ~~ Form 10-404 Revised 04/2004 '~y~_,i~t Fp ((~~ ({~j 4, t,/ ~ ~~~'r~ ~~~ Submit Original Onl~~ .~ z .z7. • • CD2-39 Stimulation results: Summary of stimulation job: 2-10-08: Pump frac in two stages: The first frac ramped from 2-11 ppa; 1343 bbls slurry for the first stage and ramped 2-7 ppa for the 2"d stage, 1347 bbls slurry 37 bbls diesel for freeze protect and 60 bbls SW flush. First Frac: AIR-25 BPM, AIP-4450 psi, ISIP-1510 psi., 300,000 Ibs.16/30 Badger sand in perfs. Second Frac: AIR - 25 BPM, AIP - 4810 psi, ISIP -1450 psi, 206,000 lbs. 16/30 Badger sand in perfs. Well test: 2/17/08: 3470 bopd, 70 bwpd, 5.8 mmcfpd, 312 WHP • (~ s ARAH PAL/N, GOVERNOR CO~T~~~- ~~.0 n ~~ 333 W 7th AVENUE, SUITE 100 1~ li l~o~~`~~,~~~111~~'iiiiii---777 0l` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Schneider Production Engineer Conoco Phillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2-39 Sundry Number: 307-374 ~~ d~~ ~ ~. ~~Q~ Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field- inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ,.,day of December, 2007 Encl. (~-~fa~ Sincerely, STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~EC ~ ~ ~(~(~'~ APPLICATION FOR SUNDRY APPRO~ ~i~ ~ GaW Gs~l=I~ ~,~~~~~~~~~ 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^/ Time Extension ^ Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^/ Exploratory ^ 201-160 3. Address: Stratigraphic ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20387-00 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 ^~ CD2-39 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 414843 RKB 52' Colville River Field /Alpine Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12651' 7228' Casing Length Size MD TVD Burst Collapse CONDUCTOR 117' 16" 117' SURFACE 2602' 9-5/8" 2654' PRODUCTION 9070' 7" 9122' OPEN HOLE 3529' 6-1/8" 12651' Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1 /2" L-80 8774' Packers and SSSV Type: Packers and SSSV MD (ft) Packer=Baker SA63 Packer= 8682' SSSV= Camco TRM-4E SSSV= 2206' 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 1, 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: Tim Schneider Printed Name Tlm SC Heider Title: Production Engineer Signature '~~ Phone 265-6859 Date `L _/ 3 -/~~ Commission Use Onl Sundry~~11 tuber: Conditions of approval: Notify Commission so that a representative may witness ~V ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. Subsequent Form Required: j APPROVED BY ~~ ~/~,~Q y Approved by: MISSIONER THE COMMISSION Date: / i Form 10-403 Revised 06/2006 "~ ~-.. ~„ r ; ~ ;3 Et ~Q~( Submit in Duplicate ~~`~~d> • Overview: CD2-39: 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 25 BPM with a maximum pressure of 9000 psi, add breaker as per lab results. Maintain 2000-3000 psi on the IA during the treatment. • 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. ''----.- 0/ }7 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 6~NED APR 2 7 7001 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ~O\- tWO Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~.¿:~---_/ ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft Qal CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-109 6" na 6" na 2.5 2/18/2007 CD2-404 206-054 6" na 6" na 1.8 3/22/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 CD2-12 203-073 16" na 16" na 7.5 2/17/2007 CD2-14 201-177 4" na 4" na 2 2/17/2007 CD2-15 201-159 12" na 12" na 5.7 2/17/2007 CD2-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 CD2-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 CD2-18 203-151 36" na 36" na 17 2/17/2007 CD2-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 CD2-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 CD2~ 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CD2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 sC,t\NNED AP1K 0 9 2007 Dear Mr. Maunder: . aC\-( bD Ò,P :P~ "..;¡ Enclosed please find a spreadsheet with a list of wells fTom 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 fTom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 CO2-3D 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 10~3~2003 Permit to Drill 20'1'1600 Well Name/No. COLVILLE RIV UNIT CD2-39 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-103-20387-00-00 MD 12651 TVD 7228 -~ Completion Date 9/19/2001 -~ Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N__~o Samples N_9 Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number ED C ,-'1~t06 D ED T ~-0~47 Rpt ED C ..,J~0347 Rpt Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 1-9695--brS-Verification ............................ --"- .-~: ~._..~F _._~_:.~:_(. ,/_ .............. ~' Best DT 2 2/5 2/5 2/5 2/5 ED C ~d~0387 TVD Resistivity , i~;':i;!?:i.i ii:!::~..:~i:,~:ili:i:i?!.:i!?i!ii~'i.:i!~!~i:'!~!'i'.::i~ii:'i ,,~I'D Resistivity Density Neutron 2/5 2/5 2/5 2/5 2/5 1 2650 12651 Open ..... . '--'--~'":-T.: ............. . ...... FINAL 2400 9100 Case 9/28/2001 2650 9112 FINAL FINAL 2650 9112 FINAL 2650 9113 FINAL 2650 9113 FINAL 2650 9113 FINAL 2650 9113 FINAL Open 03en 03en 03eh 03en 03en 03en 03en 9/28/2001 9/26/2001 9/28/2001 9/28/2001 9/28/2001 9/28/2001 9/28/2001 10/10/2001 10/16/2001 10/16/2001 10/16/2001 10/16/2001 10/26/2001 10/26/2001 FINAL 2373 9112 Open FINAL 2500 9064 Case FINAL 2500 9064 Case FINAL 2500 9064 Case 5 9122 12651 Case 2-5 2640 12651 Case 240~0-9100 Color Prints. 2650-9112 Directional Survey 2650-9112 Digital Data 2650-9113 BL, Sepia 2650-9113 BL, Sepia 2650-9113 BL, Sepia 2650-9113 BL, Sepia Directional Survey Paper Copy 2373-9112 Digital Data 2500-9064 BL, Sepia 2500-9064 BL, Sepia 2500-9064 BL, Sepia 9122-12651 BL, Sepia 2640-12651 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Sent Received Sample Set Number Comments Permit to Drill 2011600 DATA SUBMITTAL COMPLIANCE REPORT '10/312003 Well Name/No. COLVlLLE RIV UNIT CD2-39 Operator CONOCOPHILLIPS ALASKA INC MD 12651 TVD 7228 ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis Received? Completion Date 9/19/2001 Completion Status 1-OIL Current Status 1-OIL Daily History Received? ~)/N Formation Tops (~/N APl No. 50-'103-20387-00-00 UIC N Comments: Compliance Reviewed By: ConocoPhillips Greater Kuparuk Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RLThomas @ ppco.com January 10, 2003 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal, Fourth Quarter, 2002 Dear Commissioner: Please find attached the fourth quarter 2002 annular disPosal for the Kuparuk, Alpine and Cook Inlet Fields. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2002, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2O02. Please call me at 265-6830 should you have any questions. Sincerely, R.. Thomas Greater'Kuparuk Team Leader RT/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord " Kuparuk Environmental B. MOrrison / R. Overstreet Sharon AIIsup-Drake Well Files RE,CEIVED ~aska 0il & Gas Cons. Oomrnissio~ Anchorage Annular Disposal durin the fourth quarter o[2002: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-26 15244 100 0 15344 380 13902 29626 September October CD2-38, CD2-44, CD2-29, 2002 2002 CD2-13 CD2-34 22895 100 0 22995 372 0 23367 Oct 2002 Dec 2002 CD2-13, CD2-37, CD2-35 CD2-48 11281 100 0 11381 375 0 11756 Dec 2002 Dec 2002 CD2-28, CD2-45 3S-07 18155 100 0 18255 216 0 18471 Dec2002 Dec 2002 3S-09, 3S-14, 3S,-10 3S-18 206 100 0 306 0 0 306 Dec 2002 Dec 2002 3S- 18 Total Volumes into Annuli for which Dis ~osal Authorization Expired during the fourth q'uarter 2002: ~ ~ Freeze P;otect To~al V~lume ' Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume VolUme Status of Annulus CD2-39 29466 100 0 379 29945 Open, Freeze Protected October Sept 2002 CD2-15, CD2-47, CD2- 2001 44 CD2-14 30597 100 0 376 31073 Open, Freeze Protected NOvember March CD2-45, CD2-47, CD2- 2001 2002 32, 1C-14 32115 100 0 0 32215 Open, Freeze Protected October January 1C-109, 1R-36, 1C-24 2001 2002 2P-438 30331 100 0 212 30643 Open, Freeze Protected October December 2P-420, 2P-415, 2P-429 2001 2001 CD2-15 31181 100 0 371 31652 Open, Freeze Protected March 2002 September, CD2-50, CD2-25, CD2- 2002 44 CD2-47 26874 100 0 375 27349 Open, Freeze Protected December January . CD2-34, CD2-26 2001 2002 CD2-45 22514 100 0 377 22991 Open, Freeze Protected January February CD2-49, CD2-17 2002 2002 , Cook Inlet Annular Disposal during the fourth quarter 2002: h(1) h(2) h(3) Total for Freeze PrevioUs New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 472 100 0 572 0 67224 67796 January October Hansen #1 2002 2002 Kuparuk and Alpine Annular Disposal during the third quarter of 2002: h(1) h(2)' h(3) ~ Total f~r Fr~eze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-32 12701 100 0 12801 379 18636 31816 June 2002 July 2002 CD2-19, CD2-23, CD2-41 CD2-50 31530 100 0 31630 370 0 32000 July 2002 Sept2002 CD2-41, CD2-19, CD2-16, CD2-38 1C-18 27969 100 0 28069 379 4276 32724 June 2002 July 2002 1C-104 CD2-39 1966 100 0 2066 379 27500 29945 Oct. 2001 Sept 2002 CD2-15, CD2-47, CD2-44 CD2-15 10459 100 0 10559 371 20722 31652 March Sept 2002 CD2-50, CD2-25, CD2-44 2002 CD2-26 13802 100 0 13902 380 0 14282 Sept 2002 Sept2002 CD2-38, CD2-44, CD2-29 cootc ~ntet ~nnutar ldlSpOSal aurtng rne rntra ~,uarter oj zuuz: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 52255 100 0 52355 0 14869 67224 January Sept 2002 Hansen #1 2002 Total Volumes into Annuli for which Disposal Authorization Expired during the third quarter 2002: ~ ' Freeze P~otect To~al Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-24 33524 100 0 375 33999 Open, Freeze Protected July 2001 Oct 2001 CD2-33, CD2-39, CD2- 14, CD2-15 1C-26 34160 100 0 0 34260 Open, Freeze Protected August September 1C-123, 1C-119, 1C-102 2001 2001 2N-332 31453 100 0 325 31878 Open, Freeze Protected August 2001 Sept 2001 2N-348, 2N-350 1C-16 32017 100 0 0 32117 Open, Freeze Protected Sept 2001 Oct 2001 1C-102, 1C-131, 1C-125 ECEIVED OCT 2 4 2002 Alas~ Oi~ & G'~ ~ns. Commission Anchorage P.HILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Fourth Quarter, 2001 ,, Dear Commissioner: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2001. Please call me at 265-6830 should you have any questions. Sincerely, R. Thomas Greater Kupamk Team Leader RT/skad CC.' Marty, LemOn Mike Mooney Paul Mazzolini Chip Alvord Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Annular Dis :al durin ruarter ~2001: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0 19679 32117 Sept 2001 October 1C-131, 1C-125, 1C-102 ~ 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 CD2-14 14359 100 0 ' 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 1C-14 22389 100 0 22489 0 0 22489 oct 2OOl Nov 2ool 1C-109 2P-438 30331 100 0 30431 212 0 30643 Oct 2001 Dee 2001 2P-420, 2P-415, 2P-429 CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only ~ CD2-47 10315 100 0 10415 375 0 10790 Dec 2001 Dec 2001 CD2-34 'l'otal Volumes tnto Annutt for wntcn LItsposat Autnortzanon /zxptrea aurtng tne fourrn truarter ~uuz : Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec 2000 2L-317, 2L-307 J' 1D-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, 1D-34 CD1-31 6698 100 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 " 2N-305 0 0 0 380 380 Open, Freeze Protected iNA** NA** ** freeze protect ~ volumes only 1D-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec 2000 1D-32, 1D-40A 2N-349A 0 0 0 0 0 Open, Freeze Protected ...... 1D-42 32040 I00 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 Annutar vtsposat aurtng me mtra t~,uarter o7 zuu~ : 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-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, 1C-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May2001 July2001 CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June 2001 Sept 2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 CD2:14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli ~or which Disposal Authorization Expired during the third 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 CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 ' Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 , 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141, ( 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1D-36, 1D-34 2N-318 ' 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 , 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 · 2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219)in August 2001. The volumes for the expired permit applies just to that permit. Annular Dis ~osal durin the fourth quarter of 2001: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0 19679 32117 Sept 2001 October .1C-131, 1C-125, 1C-102 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December CD245, CD2-47 2001 2001 1C-14 22389 100 0 22489 0 0 22489 Oct2001 Nov2001 1C-109 -" 2P-438 30331 100 0 30431 212 0 30643 oct 20Ol Dec 2001 2P-420, 2P-415, 2P-429 CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only CD2-47 10315 100 0 10415 375 0 10790 Dec 2001 Dec 2001 CD2-34 ' '10tal Volumes mto Annult,lor wtztcn l_JtSl~OSal ~qutnortzatton tzxptrea aurtng tne fourtn ~'uarter zoo~ : Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec 2000 2L-317, 2L-307 1,1)-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, 1D-34 ,, , CDI-31 6698 100 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 --2'N'-305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect volumes only ID-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec 2000 1D-32, ID-40A 2 N-349A 0 0 0 0 0 Open, Freeze Protected ...... I I)-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 m PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100350 Anchorage, Alaska 9951 {)-0360 G. C. Alvord Phone (90,7) 265-6120 Fax: (907) 265-62:2.4 January 3,200,2 ...o'mmlssloner Cm:nmy Oechsli Taylor l~olllmlSsloner S ta~.e of Alaska Alaska Oil & Gas Conser'v ation C. ommis:.~,ion 33':!. West 7th Avenue '~'' ' -'. o al~:(.. 100 Anchorage, Alaska 0%0.:L SUbject: Co. repletion R.e[.,o:rt for CD2-39 and CE)2--39PB 1 (~01-160) De:ar Commissioner: Pihillips A]taska, Inc. s'uSrn:its the'. attached Completion Report for the drilling operations on the Alpine well CD2-39 and the plug:back of CD2--39PB 1 Jif you have any questions, regarCling this matter, p.l¢a~,e, conlact me at 265-6120 ,or' Vern Johnson at 265-6081. Sincerely, o'. t... Alvorct Alpine Drilling Team Le~ader I?.AI Drillirtg J. CA/skad RECEIVED JAN 0 8 2002 A~aska 0il & Gas Co~s. Comn~issioD Anchorage ORIGINAL 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 [-'] Suspended [] Abandoned r~ Service [~ 2. Name of Operator j LOCA~'~;~ .',, 7. Permit Number Phillips Alaska, Inc.. _- ,~_~ .V~PI;~D 201-160 / 3. Address ~ !~t~,~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~:~ ' '~ ,~. f~,,3r/- ;, 50-103-20387-00/50-103-20387-70 4. Location of well at surface ,~..~,-~-,~.. ....... ~ 9. Unit or Lease Name ¢'"'t~' ','.-. ;..'_..:, -;~-~;-:-'-~ 1954' FNL, 1516' FEL, Sec. 2, T11N, R4E, UM (ASP: 371722, 5974403) i; ~.-';;'-~-:: '!:~..','~ ;, Colville River Unit At Top Producing Interval ':' i:J','."!~ ~ 10. Well Numbe~ 623' FNL, 1407' FWL, Sec. 12, T11N, R4E, UM (ASP: 374580, 5970406) ~ ~ CD2-39 & CD2-39 PB1 At Total Depth ii ~..~..:.~__ ~ 11. Field and Pool 1368' FSL, 2031' FEL, Sec. 12, T11 N, R4E, UM (ASP: 376369, 5967087) 1~.; ~:Z;Zi Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 36.8' feetI ADL380075 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions ! September 2, 2001 September 17, 2001 September 19, 2001 I 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 12651' MD/7228'TVD 12651' MD/7228'TVD YES ['~ No []I 2206' feetMD 1702' MD 22. Type Electric or Other Logs Run GR/Res/Neut/Dens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2654' 12.25" 405 sx AS III Lite, 230 sx Class G 7" 26# L-80 Surface 9122' 8.5" 145 sx Class G CD2-39 PB1 cement plug dressed off to 8425' to start CD2-39 sidetrack 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) 3.5" 8774' 8682' open hole completion from 9122' - 12651' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9113'-8517' Plug #1:235 sx 15.7 ppg Class G 8519'-8105' Plug #2:34 bbls 17 ppg Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) November 5, 2001 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I 12/14/2001 7- 3/4 hours Test Period > 921.6 571.6 0.02 100% I 785 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 489 psi 1253 24-Hour Rate > 2649 2080 0 39° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A JAN 0 ZOOZ Alaska Oil & Gas Cons. Commissio~ -.. Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 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. CD2-39 PB1 Top Alpine D 8752' 7158' Top Alpine C 8773' 7175' Base Alpine 8873' 7255' CD2-39 Top Alpine D 8831' 7156' Top Alpine C 8873' 7173' TD 12651' 7228' RECEIVED Alaska Oil &.Gas,,. , C'o~s. Commisain. 31. LIST OF A~ACHMENTS ~"c"~e ...... Summa~ of Daily Operations, Directional Su~ey 32. I hereby ceAi~ that the following is true and correct to the best of my knowledge. Questions? Call Vem Johnson 265-6081 Signed ~_~ ~_ T,tlo ~l~ineDrillinqTeam[oader Date '/~J~ ~ ~ C~ip AIvor~ Prepared by Sharon A//sup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (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 ORI6/NAL Legal Well Name: OD2-89 Oommon Well Name: OD2-39 Spud Date: 8/31/2001 Event Name: ROT- DRILLING Start: 8/29/2001 End: 9/20/2001 Oontractor Name: doyonl @ppco.com Rig Release: 9/20/2001 Group: Rig Name: Doyon 19 Rig Number: 19 : ........ : · . . ................ : .... Date Fr°m-To Hours Oode SUb .. · · · · .... : · · Oode Ph'ase' ' . DeScription. of operations .... .. .. · : ..... 9/2/2001 00:00 - 10:00 10.00 MOVE MOVE MOBMIR Moved rig from OD2-33 to CD2-39, highline power on @ 0800 hfs, accepted rig @ 1000 hrs. 10:00 - 11:30 1.50 MOVE RURD MOBMIR NU riser and flowline, take on mud in pits. 11:30 - 13:30 2.00 MOVE RURD MOBMIR PU HWDP and 8" NMDC and standback in derrick, Gel up mud in pits. 13:30- 14:00 0.50 MOVE RURD MOBMIR PU bitand motor. i14:00- 15:00 1.00 DRILL PULD SURFAC MU MWD and I stand 8" DC's. 15:00- 15:30 0.50 DRILL SFTY SURFAC Held Prespud meeting with Rig Team. 15:30 - 16:15 0.75 WELCTL BOPE SURFAC Performed Divertor test, functioned Annular Preventor and Knife valve from both remote stations. John Crisp (AOGCC) waived witnessing test. 16:15 - 17:00 0.75 DRILL RIRD SURFAC Fill conductor with mud, check surface equipment and lines for leaks. Pressure test standpipe to 3000 psi. 17:00 - 00:00 7.00 DRILL DRLG SURFAC Spud well @ 1700 hrs, drill 12-1/4" hole from 114' to 920'. ART=1.12 AST=3.91 hrs 9/3/2001 00:00- 14:15 14.25 DRILL DRLG SURFAC Drill from 920' to 2663', casing point. ART=7.98 AST=2.31 14:15 - 15:30 1.25 DRILL ClRC SURFAC Cim BU, pumped 25 bbls 11.6 ppg sweep and cim hole clean @ 15 bpm, 130 rpm. Monitor well, static. 15:30 - 16:45 1.25 DRILL WIPR SURFAC Wipe hole to 1800', 15-40k over, unable to pass 1800' with 75k over, RIH to 1922'. 16:45 - 17:30 0.75 DRILL WIPR SURFAC Circ BU xl.5 with 15 bpm, 1950 psi, 130 rpm. Reciprocated pipe, large amount of drill cuttings (clay) back through first BU, slowed to slight volume after. 17:30 - 19:45 2.25 DRILL WIPR SURFAC Continue wiper trip, worked past tight spot @ 1797' 50K over, wiped hole to 1705', unable to pass with 75k over. Backream from 1775' to 1635', pulled to 1508' 15-35k over, hole swabbing. Backream from 1540' to 1350', 9 bpm, 810 psi, 60 rpm. Attempted to pull pipe, hole swabbing. Pump out from 1350' to 977'. 19:45 - 22:30 2.75 DRILL TRIP SURFAC POH, 10-25k over, laid down MWD and motor. Bit, lower half of motor and stabalizer above motor packed of with dehydrated clays. Clean rig floor. 22:30 - 00:00 1.50 DRILL TRIP SURFAC MU 12-1/4" BNHO clean out assembly and RIH to 1011', fill pipe. 9/4/2001 00:00 - 01:00 1.00 DRILL TRIP SURFAC RIH with BNHO clean out assembly to 2663', no problems. 01:00 - 03:00 2.00 DRILL ClRC SURFAC Circ and condition mud with 15 bpm, 130 rpm, had large amount of clay cuttings back, shakers overloaded for 20 min. Pumped 40 bbl 11.2 ppg sweep, circ hole clean. Monitor well, static. 03:00 - 06:00 3.00 DRILL TRIP SURFAC :POH, max overpul115k, no swabbing. LD BNHO, clean rig floor. 06:00 - 08:00 2.00 CASE RURD SURFAC RU to run 9-5/8" casing, held prejob safety meeting with crew. 08:00 - 12:00 4.00 CASE RUNC SURFAC Ran 61 joints of 9-5/8", 36#, L-80 BTM casing. Landed casing @ 2654'. 12:00- 12:30 0.50 CASE RURD SURFAC Lay down fill up tool, MU cement head. 12:30 - 14:30 2.00 CASE ClRC SURFAC Staged pumps up to 10 bpm 550 psi, circ and cond mud, reciprocated casing 20-25'. PJSM. 14:30 - 16:30 2.00 CEMEN'I' PUMP !SURFAC Pump 40 bbls vis.spacer, 5 bbls of FW, test cement lines to 2500 psi. Pumped 50 bbls of 10.5 ppg spacer, 310 bbls of 10.7 ppg lead cement and 48 bbls of 15.8 tail cement. Displaced cement with20 bbls of FW and 179 bbls of mud. Bumped plugs to 1000 psi, floats held, ClP at 1630 hrs, had 119 bbls of 10.7 pgg cement back to surface. 16:30 - 18:30 2.00 CASE RURD SURFAC Flush cement from Conductor, RD cement head, LD landing joint. PU jet sub and flush surface stack. 18:30 - 21:30 3.00 CASE RURD SURFAC ND Divertor system, install wellhead and test M/M seals to 1000 psi. NU BOP stack. 21:30 - 00:00 2.50 RIGMNT RURD SURFAC Slip and cut drilling line, changed out saver sub on top drive to 4", changed out annular preventor on stack. 9/5/2001 00:00 - 02:00 2.00 WELCTL EQRP SURFAC Changed pipe rams to 4", hang bails and elevators, completed change out of Annular Preventor. Printed: 10/19/2001 9:34:55AM ' OPerations'Summary Report i Legal Well Name: CD2-39 Common Well Name: CD2-39 Spud Date: 8/31/2001 Event Name: ROT- DRILLING Start: 8/29/2001 End: 9/20/2001 Contractor Name: doyonl @ ppco.com Rig Release: 9/20/2001 Group: Rig Name: Doyon 19 Rig Number: 19 !'. : Date. 'From.=T°' Holm C°de ~.Sub " · .... :' · .': · ~ ~..... ~. ~.~ ~: ~ .~:... Code "Phase' . ~ ........DeScriptionofOperations.. ~ ~i'..:~. ~ i.' 9/5/2001 02:00 - 09:00 7.00 WELCTL BOPE SURFAC Install test plug, Tested kill and choke line valves, manifold valves, pipe and blind rams, surface safety valves and TD valves to 250/5000 psi, Annular Preventor to 250/3500 psi. John Crisp (AOGCC) waived witnessing test. Pull test plug and install wear bushing. 09:00 - 11:30 2.50 DRILL TRIP SURFAC MU BHA #3, change running tools and grabber dies to 4". 11:30 - 12:30 1.00 RIGMNT OTHR SURFAC Shim TD rails to improve TD/Rotary table alienment for stabbing 4" XT39 drill pipe. 12:30 - 12:45 0.25 DRILL DEQT SURFAC Shallow test MWD/LWD. 12:45 - 13:30 0.75 RIGMNT RGRP SURFAC Change out 4" XT39 saver sub on TD, damaged threads. 13:30 - 14:30 1.00 DRILL TRIP SURFAC RIH, tagged cement @ 2500'. 14:30 - 15:00 0.50 DRILL DRLG SURFAC Clean out cement to 2556'. 15:00 - 15:30 0.50 DRILL CIRC SURFAC Circ and condition mud. 15:30 - 16:30 1.00 DRILL DRLG SURFAC RU and Test casing to 2500 psi for 30 min. 16:30 - 17:30 1.00 DRILL DRLG SURFAC Clean out cement from 2500' to 2663', drill 20' of new hole. 17:30 - 18:00 0.50 DRILL ClRC SURFAC Circ hole clean for FIT. 18:00 - 18:30 0.50 DRILL FIT SURFAC Perfom FIT to 16.0 ppg EMW. 18:30 - 19:00 0.50 DRILL CIRC INTRM1 Change well over to 9.6 ppg LSND mud. 19:00 - 00:00 5.00 DRILL DRLG INTRM1 Drill from 2683' to 3191' ART=2.68 AST=0.11 9/6/2001 00:00 - 15:00 15.00 DRILL DRLG INTRM1 Drill from 3191' to 4720', ART=9.32 AST=0.69 Pumped 40 bb1180 FV sweeps @ 3095', 3727', and 4260' each sweep resulted in large increase in returns 1"-3" clay balls. 15:00 - 16:00 1.00 DRILL CIRC INTRM1 Pumped 40 bbls 240 FV sweep and circ hole clean. Sweep had a large increase in in returns 2"-3" clay balls. 16:00 - 19:00 3.00 DRILL WIPR INTRM1 Wiped hole to shoe, max over pull 35k, had slight intermittant swabbing last 500' to shoe, reduced pulling speed, ok. RIH to 4624', no problems. 19:00 - 19:45 0.75 DRILL CIRC INTRM1 Precationary wash and ream from 4626' to 4720', pumped 80 bbl sweep 240 FV and circ hole clean. Heavy cuttings throughout first BU, sweep brought out a large amount of 2"-4' clay balls. 19:45 - 00:00 4.25 DRILL DRLG INTRM1 Drill from 4720' to 5083', ART=2.76 AST=0. Pumped 60 bbl sweep 180 FV had large increase with sweep back, smaller clay cuttings. 9/7/2001 00:00 - 23:00 23.00 DRILL DRLG INTRM1 Drill from 5083' to 7203'. ART=13.32 AST=1.25 Pumped 210 FV sweeps @ 5761'and 6650' moderate increase in returns ( small clay balls). 23:00 - 00:00 1.00 DRILL CIRC INTRM1 Circ and condition mud for wiper trip. Pumped 40 bbls 260 FV sweep around, slight increase in returns. 9/8/2001 00:00 - 00:30 0.50 DRILL DRLG INTRM1 Circ hole clean14.4 bpm, 3240 psi, 130 rpm. Monitor well, static. 00:30 - 04:00 3.50 DRILL WIPR INTRM1 Wipe hole from 7203' to 4725', no problems, max overpull 20k. Monitor well, static. RIH to 7107', unable to MU Top Drive. 04:00 - 04:30 0.50 RIGMNT RGRP INTRM1 Change out saver sub on Top Drive (damaged threads) intermitantly reciprocated pipe. 04:30 - 04:45 0.25 DRILL WIPR INTRM1 Precautionary wash and ream from 7107' to 7203'. 04:45 - 00:00 19.25 DRILL DRLG INTRM1 Drill from 7203' to 8922'. ART=12.04 AST=0.5 Pumped 40 bbl 280 FY sweeps at 7688', 8160' and 8833', moderate increase in returns from sweeps, small clay balls, sand. 9/9/2001 00:00 - 02:30 2.50 DRILL DRLG INTRM1 Drill from 8922' to 9113', TD per Geologist. ART=1.78 AST=0 02:30 - 04:00 1.50 DRILL INTRM1 Pumped 40 bbl 280 FV sweep 14 bpm, 3520 psi, 130 rpm, circ hole clean, minimal increase in returns from sweep. 04:00 - 07:30 3.50 DRILL WIPR INTRM1 Monitor well, static. Wiped hole to 7015', max overpull 30k (7303'-7207') no other problems. 07:30 - 09:00 1.50 DRILL CIRC INTRM1 Pumped 60 bbls 350 FV sweep: 14 bpm, 3540 psi, 110 rpm (MWD shock limited) circ hole clean, minimal increase in returns from sweep, monitor well, static. 09:00 - 14:00 5.00 DRILL TRIP INTRM1 POH to shoe, 5-20k over, hole in good condition. Monitor well, static. Printed: 10/19/2001 9:34:55 AM : :: : :: ii:i oPerations summary Report: : Legal Well Name: CD2-39 Common Well Name: CD2-39 Spud Date: 8/31/2001 Event Name: ROT - DRILLING Start: 8/29/2001 End: 9/20/2001 Contractor Name: doyen1 @ppco.com Rig Release: 9/20/2001 Group: :Rig Name: Doyen 19 Rig Number: 19 :: Date:::: :: :Fr°~:~:To Hours :C°de (~oU~3e :phasel : ; : : ... ..'DescriPti°n:°f:OPerati0nsi: :;;:: :: : :? :::: 9/9/2001 09:00 - 14:00 5.00 DRILL TRIP INTRM1 Continue to POH to BHA. 14:00 - 16:30 2.50 DRILL TRIP INTRM1 Change running tools to 5", stand back HWDP and Flex Collars, remove source from LWD. LD remainder of BHA. 16:30 - 16:45 0.25 LOG SFTY 'INTRM1 PJSM with rig crew and Schlumbeger loggers. 16:45 - 17:30 0.75 LOG PULD INTRM1 RU loggers, MU GR/Den/Neu/Dipole Sonic tool string, load source. 17:30 - 18:45 1.25 LOG ELOG INTRM1 RIH with wireline logs to 9096'. 18:45 - 23:00 4.25 LOG OTHR INTRM1 LogGR/Den/Nue to 6096', Dipole Sonic to casing shoe (2654'). 23:00 - 00:00 1.00 LOG ELOG INTRM1 POH with logging tools, remove source. 9/10/2001 00:00- 00:30 0.50 LOG RURD INTRM1 Rig down loggers. 00:30- 00:45 0.25 ABANDN SFTY INTRM1 PJSM, picking up tubing. 00:45 - 03:00 2.25 ABANDN TRIP INTRM1 RU tubing tongs, PU 33 jts of 3-1/2" tbg. RD tongs, change running tools to 4". 03:00 - 03:45 0.75 ABANDN TRIP INTRM1 RIH to 2475' =03:45 - 05:00 1.25 RIGMNT RURD INTRM1 Slip and cut drilling line. 05:00 - 05:30 0.50 RIGMNT RSRV INTRM1 Service Top Drive and drawworks. 05:30 - 09:00 3.50 ABANDI~ TRIP INTRM1 RIH to 9113'. 09:00 - 10:30 1.50 ABANDI~ ClRC INTRM1 Circulate and condition mud for cementing 10 bpm, 1770 psi. 10:30 - 11:15 0.75 ABANDI~ RURD INTRM1 PJSM. Space out string, RU cement lines. 11:15 - 12:45 1.50 CEMEN'I'PLUG INTRM1 Test lines to 3500 psi, plug back 8 1/2" OH from 9113' to 8517' with 235 sxs of 15.7 ppg G cement (20% excess). Displaced to equalization, CIP @ 1205 hours. POH slowly to 8519'. 12:45 - 13:00 0.25 CEMEN'I'CIRC INTRM1 Flush drill pipe with 100 bbls of mud, 11 bpm, 1960 psi. 13:00 - 14:15 1.25 CEMEN'I'PLUG INTRM1 Test lines to 3500 psi, plug back 8 1/2" OH from 8519' to 8105' with 34 bbls of 17.0 ppg G cement (20% excess). Displaced to equalization, ClP @ 1340 hours. POH slowly to 8105'. 14:15 - 15:30 1.25 ABANDI~ CIRC INTRM1 Circ and condition mud, 10 bpm, 1640 psi. Slight show of cement contaminated mud at bottoms up. Monitor well, static. 15:30 - 18:00 2.50. ABANDI', TRIP INTRM1 POH, monitor well at shoe, static. Continue to POH with 4" drill pipe. 18:00 - 20:30 2.50' ABANDI~ TRIP INTRM1 Change running tools to 3 1/2", RU tubing tongs and LD 33 joints of tubing, RD tongs. 20:30 - 22:30 2.00 DRILL PULD INTRM1 MU BHA #4, shallow test tools. 22:30 - 00:00 1.50 DRILL TRIP INTRM1 RIH with 4" drill pipe to 3446', fill pipe. 9/11/2001 00:00 - 02:30 2.50 DRILL .TRIP INTRM1 RIH with steerable drilling assembly, tagged cement @ 8110'. 02:30 - 03:00 0.50 DRILL ClRC INTRM1 Circ to clean up hole, condition mud. 03:00 - 05:30 2.50 DRILL DRLG INTRM1 Drill out cement from 8110' to 8425'. 05:30 - 00:00 18.50 DRILL DRLG INTRM1 Drill off of cement and sidetracked well @ 8448'. Drill 8 1/2' hole from 8448' to 9079'. ART=3.67 AST=8.16 Pumped 40 bbl 280 FV sweep at 8755' moderate increase in small clays and sand in sweep. 9/1212001 00:00 - 01:00 1.00 DRILL DRLG INTRM1 Drill from 9070' to 9132', casing point. ART=0.13 AST=0.69 01:00 - 03:00 2.00 DRILL CIRC INTRM1 Pump 40 bbl 280 FV sweep and circ hole clean, 14 bpm, 3620 psi, 100 rpm. 03:00 - 05:30 2.50 DRILL WIPR INTRM1 Pump out to 8763', wiped hole to 7997', max overpull 25k. RIH, wiped through tight spot @ 8666', no other problems. 05:30 - 08:00 2.50 DRILL CIRC INTRM1 Pump 60 bbl 320 FV sweep, circ @ 14 bpm, 3510 psi, 105 rpm. Monitor well, static. 08:00 - 14:00 6.00 DRILL TRIP INTRM1 Pump out 4 stands, 4 bpm, 620 psi. POH to 1064', max overpull, 20k. monitored well at shoe, static. Hole in good condition. 14:00 - 15:30 1.50 DRILL TRIP INTRM1 Handle BHA, LD motor and MWD, clean rig floor. 15:30 - 18:30 3.00 CASE NUND INTRM1 Flush wellhead and BOP stack, change top pipe rams to 7", Pull wear bushing and install test plug. Body test rams against annular prevertor to 25013500 psi. Pull test plug and install thin wear bushing. Change saver sub on TD to 4-1/2" IF for fill up tool. Printed: 10/19/2001 9:34:55 AM Legal Well Name: CD2-39 Common Well Name: CD2-39 Spud Date: 8/31/2001 Event Name: ROT- DRILLING Start: 8/29/2001 End: 9/20/2001 Contractor Name: doyonl @ppco.com Rig Release: 9/20/2001 Group: Rig Name: Doyon 19 Rig Number: 19 :;:;::::: ': Sub '" ' ..... · :;:Date::.:: :From::,:;To;:Hours Code. phase .' · .DeSCripti°n.of Operations '.. " :.;; ::::::.:: ::::;: :: . . .. Code .. :. ::.' 9/12/2001 18:30 - 20:00 1.50 CASE RURD INTRM1 RU to run 7" casing, bails, fill up tool, elevators slips and power tongs. 20:00 - 20:30 0.50 CASE SFTY INTRM1 Safety and operations meeting with crew. 20:30 - 23:40 3.17 CASE RUNC INTRM1 Run casing to 2616'. 23:40 - 00:00 0.33 CASE CIRC INTRM1 Stage pumps up to 8 bpm, 380 psi, circ one casing volume. (135K up, 120K dn) 9/13/2001 00:00 - 02:00 2.00 CASE RUNC INTRM1 Run 7" casing to 5108'. 02:00 - 02:30 0.50 CASE ClRC INTRM1 :Stage pumps up to 7 bpm, 640 psi, Circ BU, cond mud. PUW 190k SOW 142k. 02:30 - 04:30 2.00 CASE RUNC INTRM1 Run casing to 7201'. 04:30 - 05:15 0.75 CASE CIRC INTRM1 Stage pumps up to 7 bpm, 960 psi, CBU and cond mud. POW 240k SOW 150k. 05:15 - 07:30 2.25 CASE RUNC INTRM1 Run casing, MU hanger and landing joint, land casing with shoe @ 9122'. 07:30 - 08:00 0.50 CASE RURD INTRM1 LD fill up tool, MU cement head. 08:00 - 09:45 1.75 CEMEN'[ CIRC INTRM1 Staged pumps up to 7 bpm, cond mud for cementing, final circ pressure 730 psi, reciprocated casing throughout. PJSM. 09:45 - 11:30 1.75 CEMEN-[ PUMP INTRM1 test lines to 3500 psi, pump 20 bbls of chemical wash, 50 bbls of 12.5 ppg spacer and 145 sxs of 15.8 ppg G cement with adds. Displace cement with 20 bbls of FW and 327 bbls of 9.6 ppg mud. Bumped plubs to 1000 psi, floats held. CIP @ 1117 hrs, bleed off to check floats, held. Monitor well, static. 11:30 - 12:30 1.00 CEMEN'I'PULD INTRM1 LD cement head and landing joint. 12:30 - 15:00 2.50 CASE PTCH INTRM1 Pull thin wear bushing, install and test packoff to 5000 psi, 10 min. 15:00 - 16:00 1.00 CASE RURD INTRM1 Change top pipe rams to 3-1/2" x 6", change top drive saver sub to 4" XT. 16:00 - 22:00 6.00 WELCTL BOPE INTRM1 Install test plug in wellhead, test BOPE. test Annular to 250/5000 psi. Test pipe and blind rams, choke, kill, manifold, Top drive and surface safety valves to 250/5000 psi. Perform Accumulator test, pull test plug and install wear bushing. 22:00 - 00:00 2.00 DRILL PULD INTRM1 PU M1XL motor, MWD and LWD, MU BHA #5, install source in NUE/DEN tool. 9/14/2001 00:00 - 01:30 1.50 DRILL PULD PROD M/U BHA# 5 01:30 - 05:00 3.50 DRILL TRIP PROD RIH w/BHA # 5 to 3927' - picking up 3533' of 4" DP f/pipe shed 05:00 - 08:00 3.00 DRILL TRIP PROD Continue RIH f/3927' to 8928' 08:00- 08:30 0.50 DRILL CIRC PROD Cim for casing test 08:30 - 09:30 1.00 DRILL OTHR PROD Pressure test 7" casing to 3500 psi for 30 mins. 09:30 - 12:00 2.50 DRILL DRLG PROD Clean out shoe track f/8928 to 9122' - clean out rat hole to 9132' - MWD failure 12:00 - 12:30 0.50 DRILL DRLG PROD Drill 6 1/8" hole f/9132' to 9152' - 7226' TVD - ADT- 1.9 ART - 1.9 12:30- 13:30 1.00 DRILL CIRC PROD Circ hole clean for FIT 13:30 - 14:00 0.50 DRILL FIT PROD Perform F.I.T. to 12.5 ppg EMW w/9.6 ppg mud @ 1090 psi 14:00 - 18:00 4.00 DRILL TRIP PROD Observe well - pump dry job - trip out for MWD - pull to 1782' - flow check - cont. POOH to BHA 18:00 - 21:00 3.00 DRILL TRIP PROD Std back HWDP, jars, & flex DC - remove RA source f/MWD - dowmload MWD - change out MWD - install RA source - RIH to 388' test MWD 21:00 - 00:00 3.00 DRILL TRIP PROD RIH f/388' to 7267': fill DP every 2000' 9/15/2001 00:00 - 00:30 0.50 DRILL TRIP PROD Continue RIH f/7267' to 8508' 00:30 - 02:00 1.50 RIGMNT RURD PROD Cut & slip drill line 60' - service top drive 02:00 - 02:30 0.50 DRILL TRIP PROD Continue RIH to 9152' 02:30 - 04:30 2.00 DRILL OTHR PROD Change well over to 9.2 ppg FIo Pro 04:30 - 12:00 7.50 DRILL DRLH PROD Drill 6 1/8" hole f/9152' to 9649' - 7233' TVD - ADT 5.34 - ART 5.34 12:00 - 00:00 12.00 DRILL DRLH PROD Drill 6 1/8" hole f/9649' to 10,348' - 7231' TVD - ADT 8.38 - AST .98 - Printed: 10/19/2001 9:34:55AM Legal Well Name: 0D2-39 Common Well Name: CD2-39 Spud Date: 8/3112001 Event Name: ROT- DRILLING Start: 8/29/2001 End: 9/20/2001 Contractor Name: doyonl @ppco.com Rig Release: 9/20/2001 Group: Rig Name: Doyon 19 Rig Number: 19 :Fio~iTo H0Uis C~de. SUb 'ph:ase i, :~e~ciip~i°~0f°Perati°ns' ~ i:.i Code · 911512001 1~):00 - 00:00 12.00 DRILL DRLH PROD ARTT.40 9/16/2001 00:00 - 00:00 24.00 DRILL DRLH PROD Drill 6 1/8" hole f/10,348' to 11,778' - 7231' TVD - ADT 7.71 - ART 6.77 - AST .94 9/17/2001 00:00 - 14:00 14.00 DRILL DRLH PROD Drill 6 1/8" hole f/11,778' to 12,651' - 7228' TVD - ADT 9.67 - ART 8.4 AST 1.27 14:00 - 16:30 2.50 DRILL CIRC PROD Pump sweep and circulate hole clean 3 X bottoms up 16:30 - 21:00 4.50 DRILL WlPR PROD Monitor well - wiper trip f/12,561' to 9122' - ( pump out) Monitor well 21:00 - 00:00 3.00 DRILL TRIP PROD RIH f/9122' to 12,651' 9/18/2001 00:00 - 01:00 1.00 DRILL CIRC PROD Circulate bottms up 01:00 - 02:30 1.50 DRILL OTHR PROD Change well over to 9.2 ppg brine 02:30 - 03:00 0.50 DRILL OTHR PROD Monitor well - hole taking fluid @ 43 bbls/hr 103:00 - 04:00 1.00 DRILL OTHR PROD Mix & spot 38 bbls hi vis pill 04:00 - 05:30 1.50 DRILL TRIP PROD Pull out & stand back 4" drill pipe to 11,200' ( hole taking fluid @ 14 bbl$/hr 05:30 - 06:30 1.00 DRILL OTHR PROD Mix & spot 40 bbls hi vis pill @ 11,200' 06:30 - 12:00 5.50 DRILL TRIP PROD Continue POOH std back 4" drill pipe to 4,572' - hole taking fluid @ 8 bbls/hr 12:00 - 16:00 4.00 DRILL TRIP PROD PJSM - Continue POOH laying down excess 4" drill pipe 16:00 - 18:00 2.00 DRILL TRIP PROD Lay down BHA - remove RA source f/MWD 18:00 - 18:30 0.50 DRILL OTHR PROD Pull wear bushing 18:30 - 19:00 0.50 CMPLTN RURD CMPLTN Rig up to run 3 1/2" completion 19:00- 19:30 0.50 CMPLTN SFTY CMPLTN Pre job safety meeting 19:30-00:00 4.50 CMPLTNRUNT CMPLTN M/U&RIHw/ WEG-pupjt.-XNnipple-2jt$.31/2"tbg-Baker SAB3 packer assembly - 1 jt 3 1/2" tbg - X nipple - 2 jts. 3 1/2" tbg - #1 GLM assembly w/shear valve - 52 its. 3 1/2" tbg - #2 GLM assembly - 49 its. 3 1/2" tbg 911912001 00:00 - 04:00 4.00 CMPLTN RUNT CMPLTN Contiune running 3 1/2" completion - 44 its. 3 1/2" tbg - #3 GLM assembly - 56 its. 3 1/2" tbg - Camco 3 1/2" TRM-4E SSSV 04:00 - 04:30 0.50~ CMPLTN RUNT CMPLTN PJSM - rig up control line spool - install line to SSSV & test 04:30 - 10:00 5.50 CMPLTN RUNT CMPLTN Continue RIH w! 3 1/2" completuion - 66 jts. 3 1!2" tbg - 3 1/2" x 4 1/2" XO - 2 its. 4 1/2" tbg - FMC tbg hanger w/pup jt. - Ran 272 its. total 3 1/2/" 9.3# EUE -Mod Tubing - Landed tbg w/WEG @ 8774' - XN nipple @ 8761' - Baker packer @ 8682' - X nipple @ 8639' 10:00 - 10:30 0.50 CMPLTF, OTHR CMPLTN RILDS - L/D landing jt. A - set two way check - M/U landing jr. B - test metal to metal seals on tbg hanger to 5000 psi - L/D landing jr. B 10:30 - 12:00 1.50 CMPLTF, NUND CMPLTN PJSM - Change out saver sub in top drive - NID BOPE 12:00 - 13:30 1.50 CMPLTN NUND CMPLTN PJSM w/new crew - Cont. NID BOPE 13:30 - 15:00 1.50 CMPLT~, NUND CMPLTN Connect SSSV control line through wellhead - Install tree - test tree to 5000 psi for 10 mins 15:00 - 15:30 0.50 CMPLTI~ OTHR CMPLTN Open SSSV - drop packer setting ball & rod 15:30 - 16:30 1.00 CMPLTI~ OTHR CMPLTN Rig up floor manifold and hard lines to tbg and annulus - test line to 3500 psi 16:30 - 18:30 2.00 CMPLT~ PCKR CMPLTN PJSM - Pressure up on tbg to 3500 psi to set packer - test tbg to 3500 psi for 30 mins. ok - bled pressure down to 2500 psi - switch to annulus and pressure test to 3500 psi for 30 mins. ok - bled tbg pressure down to shear RP valve - observed shear out @ 22000 psi 18:30 - 21:00 2.50 CMPLTI~ CIRC CMPLTN Begin to displace well w! 9.6 ppg inh.' brine - pumped 5.3 bbls tbg pressured up to 3500 psi - RP valve appears to be pluging off - switch to annulus & pumped tbg volume w/9.2 ppg brine @ 2.8 b!m @ 2140 psi to clear RP valve - switch back to tbg - pumped 53 bbls 9.2 ppg brine @ 1.8 b/m @ 2000 psi 21:00 - 00:00 3.00 CMPLTI~ (::IRC CMPLTN Switch back to tbg side - pumped '163 bbls 9.6 ppg corrison inh. brine @ 2.5 blm @ 1740 psi - freeze protect w! 134 bbls diesel @ 2.5 b/m @ Printed: 10/19/2001 9:34:55AM ( Legal Well Name: CD2-39 Common Well Name: CD2-39 Spud Date: 8/31/2001 Event Name: ROT- DRILLING Start: 8/29/2001 End: 9/20/2001 Contractor Name: doyonl @ppco.com Rig Release: 9/20/2001 Group: Rig Name: Doyon 19 Rig Number: 19 Date: :From::~:To:::::: :: :: ::::::::::::::.Hours .... Code Sub' 'Phase Description: of OPerations Code · · · · : 9/19/2001 21:00 - 00:00 3.00 CMPLTN CIRC CMPLTN 1740 - 2000 psi 9/20/2001 00:00 - 03:00 3.00=CMPLTN OTHR CMPLTN Vaccume out displacement lines - rig down lines and manifold - set BPV - secure well - finish cleaning pits - prep for move - Release rig @ 0300 hrs. 9/20/2001 Printed: 10/19/2001 9:34.:55AM Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/39 PH1 / 39 Survey Section Name CD2-39 PB1 MWD BHI Rep. _C_ MILCHAK ~i~"~i~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1953.61 Grid Correction 0.000 Depths Measured From: RKB {~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -1514.68 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m~ 10m~ Vert. Sec. Azim. 142.91 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL (F'~ (DD) (DD) (F'r) (FT) (FT) (FT) (Per 100 FT)Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 02-SEP-O1 MWD 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 02-SEP-01 MWD 201.00 0.54 144.67 87.00 201.00 0.41 -0.33 0.24 0.62 0.62 ., 02-SEP-01 MWD 294.00 2.56 119.03 93.00 293.96 2.75 -1.70 2.31 2.24 · 2.17 02-SEP-01 MWD 383.00 5.08 117.68 89.00 382.76 8.13 -4.50 7.53 2.83 2.83 -1.52 02-SEP-01 MWD 473.00 8.03 114.57 90.00 472.16 17.27 ~8.96 16.78 3.30 3.28 -3.46 02-SEP-01 MWD 559.00 10.62 114.35 86.00 557.01 29.52 -14.73 29.47 3.01 3.01 -0.26 02-SEP-01 MWD 650.00 13.20 116.64 91.00 ,646.05 46.20 -22.84 46.40 2.88 2.84 2.52 02-SEP-01 MWD 739.00 13.63 117.15 89.00 732.62 64.76 -32.19 64.81 0.50 0.48 0.57 02-SEP-01 MWD 829.00 13.59 123.98 90.00 820.10 84.31 -42.94 I 83.02 1.79 -0.04 7.59 02-SEP-01 MWD 919.00 13.09 . 125.97 90.00 907.67 104.07 -54.83 100.03 0.75 -0.56 2.21 03-SEP-01 MWD 1008.00 13.73 129.20 89.00 994.24 123.97 -67.43 116.37 1.11 0.72 3.63 , 03-SEP-01 MWD 1102.00 15.97 135.88 94.00 1085.11 147.64 -83.76 134.03 3.00 2.38 7.11 (, 03-SEP-01· MWD 1195.00 18.65 140.53 93.00 1173.89 175.21 -104.43 152.39 3.24 2.88 5.00 03-SEP-01 MWD 1290.00 20.55 141.48 95.00 1263.38 207.05 -129.21 172.43 2.03 2.00 1.00 03-SEP-01 MWD 1385.00 23.73 141.41 95.00 1351.37 242.84 -157.20 194.74 3.35 1 3.35 -0.07 03-SEP-01 MWD 1479.00 27.37 139.93 94.00 ' 1436,16 283.34 -188.53 220.46 3.93 3.87 -1.57 03-SEP-01 MWD 1573.00 30.48 139.56 94.00 1518.42 328.73 -223.22 249.84 3.31 3.31 -0.39 03-SEP-01 MWD 1669.00 32.71 139.37 96.00 1600119 378.93 -261.44 282.53 2.33 2.32 -0.20' 03-SEP-01 MWD 1766.00 36.33 141.22 97,00 1680.10 , 433.83 -303.74 317..60 3.88 3.73 1.91 03-SEP-01 MWD 1861.00 39.94 144.02 95.00 1754.81 492.47 -350.38 353.16 4.21 3.80 2.95 03~sEp-01 MWD 1957.00 40.24 143.49 96.00 1828.26 554.29 -400.24 389.71 ' 0.47 0.31 -0.55 03~SEP-01 MWD 2057.00 40.53 143.14 100.00 1904.43 619.08 -452.19 428.42 0.37 0.29 -0.35 03-SEP-01 MWD 2147.00 39.41 143.73 90.00 1973.40 676.89 -498.63 462.86 1.31 -1.24 0.66 i I SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00101 Sidetrack No. Page 2 of 5 -= [ ! ~-= I :~c.-~ Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/39 PH1 / 39 Survey Section Name CD2-39 PB1 MWD BHI Rep. C MILCHAK ~lllrjl"~l~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1953.61 Grid Correction 0.000 Depths Measured From: RKB ~] MSL0 SS0 Target Description Target Coord. E/W Slot Coord. E/W -1514.68 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m[~ 10m~ Vert. Sec. Azim. 142.91 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle 3irection Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FD (DB) (DO) (F'r) (F~ (FT) (F~ (Per 100 FT)Drop (-) Left (-) 03-SEP-01 MWD 2242.00 38.84 144.32 95.00 2047.10 736.82 -547.14 498.08 0.72 -0.60 0.62 03-SEP-01 MWD 2338.00 38.67 145.62 96.00 2121.97 796.87 -596.34 532.57 0.87 .0.18 1.35 03-SEP-01 MWD 2433.00 38.46 . 145.98 95.00 2196.25 856.02 -645.33 565.86 0.32 -0.22 0.38 03-SEP-01 MWD 2530.00 38.53 146.23 97.00 2272.16 916.31 -695.44 599.53 0.18 ' 0.070.26 I 05-SEP-01 MWD 2736.00 37.40 147.44 206.00 2434.57 1042.73 -801.51 668.87 0.66 -0.55 0.59 05-SEP-01 MWD 2832.00 37.69 146.08 96.00 2510.69 1101.09 -850.43 700.94 0.91 0.30 -1.42 05-SEP-01 MWD 2927.00 38.88 142.70 95.00 2585.26 1159.92 -898.26 735.21 2.54 1.25 -3.56 05-SEP-01 MWD 3022.00 38.78 142.41 95.00 2659.27 1219.48 -945.55 771.43 0.22 -0.11 -0.31 05-SEP-01 MWD 3118.00 38.60 141.83 96.00 2734.20 1279.48 -992.92 808.28 0.42 -0.19 -0.60 . 06-SEP,01 MWD 3212.00 38.57 142.06 94.00 2807.68 1338.10 -1039.08 844.41 0.16 -0.03 0.24 06-SEP-01 MWD 3308.00 38.51 141.94 96.00 2882.77 1397.91 -1086.21 881.24 0.10 -0.06 .-0.13 06-SEP-01 MWD 3405.00 38.46 141.98 97.00 2958.70 1458.26 -1133.75 918.44 0.06 -0.05 0.04 06-SEP-01 MWD 3499100 38.36 1'41.21 94.00 3032.36 1516.65 -1179.52 . 954.71 0.52 -0.11 -0.82 06-SEP-01" MWD 3595.00 38.25 140.81 96.00 3107.69 1576.12 -1225.77 992.15 0.28 -0.11 -0.42 06-SEP-01 MWD 3690.00 38.01 140.72 95.00 3182.42 1634.74 -1271.20 1029.25 0.26 -0.25 -0.09 06-SEP-01 MWD 3786.00 37.94 140.66 96.00 3258.09 1693.76 -1316.91 1066.68 0.08 -0.07 -0.06 06-SEP-01 MWD 3882.00 37.98 140.05 96.00 3333.78 1752.75 -1362.38 1104.35 0.39 0.04 -0.64 · O6-SEP-01 MWD 3976.00 38.74 141.93 94.00 3407.49 1811.05 -1407.71 1141.06 1.48 0.81 2.00 06-SEp-01 MWD 4074.00 39.27 143.41 98.00 3483.65 1872.73 -1456.75 1178.46 1.09 0.54 1.51 06-SEP-0i MWD 4168.00 38.90 145;75 94.00 3556.62 193i.96 -1505.04 1212.81 1.62 -0.39 2.49 06-SEP-01 MWD 4264.00 38.95 14'6.05 96.00 3631.30 1992.19 -1554.98 1246.62 0.20 0.05 0.31 . 06-SEP-01 MWD 4359.00 38.93 145.74 95.00 3705.19 2051.82 -1604.42 1280.10 0.21 -0.02 -0.33 06-SEP-01 MWD 4455.00 38.95 146.23 96.00 3779.86 2112.07 -1654.43 1313.85 0.32 0,02 0.51 06-SEP-01 MWD 4551.00 39;05 1'46.40 96.00 3854.47 2172.38 -! 704.70 1347.36 0.15 0.10 0.18 i [If.ra ' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00101 .S detrack No. Page 3 of 5 -=[![4 =- I ::~l Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co, - Rig: #19 Field ALPINE FIELD Well Name & No, PAD CD#2/39 PH1/'39 SurVey Section Name CD2-39 PB1 MWD BHI Rep. C MILCHAK ~i~r~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1953.61 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SS0 Target Description Target Coord. E/W Slot Coord. E/W -!514.68 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m~ 10m~ Vert. Sec. Azim. 142.91 Magn. to Map Corr. 0.000 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 (FT) (DD) (DD) (FT) (F'r) (F'I~ (F~ (Per 100 FT) Drop (-) Left (-) 06-SEP-01 MWD 4644,00 39.11 146.41 93.00 3926.66 ' 2230.89 -1753.54 1379.80 0.06 0.06 0.01 06-SEP-O1 MWD 4743.00 39.20 146,09 99.00 4003.43 2293.30 -1805.52 1414.53 0.22 0.09 -0.32 06-SEP-01 MWD 4839.00 39.03 146.23 96.00 4077,91 2353.77 -1855.82 1448.26 0.20 -0.18 0.15 06-SEP-01 MWD 4933.00 38.61 146.04 94.00 4151.15 2412.60 -1904.75 1481.09 0.46 0.45 -0.20 06-SEP-01 MWD 5029.00 38.33 145.91 96.00 4226.31 2472.23 -1954.25 1514.51 0.30 -0.29 -0.14 07-SEP-01 MWD 5124,00 38.18 145.72 95.00 4300.91 2530.98 -2002.90 1547.56 0.20 -0,16 -0.20 07-SEP-01 MWD 5219.00 38.26 145,35 95.00 4375,55 2589.69 -2051,36 1580.82 0.26 0.08 -0.39 07-SEP-01 MWD 5314,00 38.02 144.95 95.00 4450.27 2648.32 -2099,51 1614.35 0.36 -0.25 -0.42 , 07-SEP-01 MWD 5409.00 37.77 145.00 95.00 4525.23 2706.63 -2147.29 1647.83 0.27 -0.26 0.05 07-SEP-01 MwD 5505.00 37.66 145.11 96.00 4601.18 2765.32 -2195;43 1681.47 0.13 -0.11 0,11 07-SEP-01 MWD 5599.00 37.52 144.65 94.00 4675.66 2822.62 -2242.33 1714.46 0.33 -0.15 -0.49 07-SEP-01 MWD 5695.00 37.27 144.58 96.00 4751.93 2880.90 -2289.87 1748.22 0.26 -0.26 -0,07 , 07;SEP-01 MWD 5790'.00 37.11 143.67 95.00 4827.61 2938.31 -2336.39 1781.87 0.60 -0.17 -0.96 07-SEP-01' MWD 5888,00 36.99 143.30 98.00 4905,83 2997.35 -2383.85 1817.00 0.26 -0.12 " -0.38 07-SEP-01 MWD 5984.00 37.72 144.04 96.00 4982.14 3055.59 -2430.78 1851.51 0.89 0.76 0.77 07-SEP-01 MWD 6080.00 37.54 143.47 96.00 5058.17 3114.20 -2478.05 1886.16 0.41 -0.19 -0.59 07-SEP-01 MWD 6174.00 38.31 143.37 94.00' 5132.31 3171.97 -2524.44 1920.59 0.82 0.82 -0.11 07-SEP-01 MWD 6270.00 37.93 143.12 96.00 5207.84 3231.23 -2571.92 ' 1956.06 0.43 -0.40 -0.26 07-SEP-01 MWD 6365.00 38.38 143.29 95.00 5282'.54 3289.92 -2618.92 1991.21 0.49 0,47 0.18 07-SEP-01 MWD 6460,00 39.07 143.35 95.00 5356.66 .3349.35 -2666,58 2026.71 0,73 0,73 0,06 07-SEP-01 MWD 6556.00 38.82 143.45 96.00 5431.32 3409.69 -2715.03 2062.69 0.27 -0.26 0.10 07-SEP-01 MWD 6651.00 38.22 143.65 95.00 5505.65 3468~85 -2762.62 2097.84 0.65 -0.63 0.21 07-SEP-01 MWD 6747.00 37.60 143,29 96.00 5581.39 3527.83 -2810.02 2132.95 0.69 -0.65 -0,38 ,. 07-SEP-01 MWD 6842.00 39.87 i45.33 95.00 5655.49 3587.25 -2858.30 2167.60 2.74 2.39 2.15 iii iiii [iFH_=i Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD I Well Name & No. PAD CD#2/39 PH1 / 39 SurVey Section Name CD2-39 PB1 MWD BHI Rep. C MILCHAK IJM 'EIi , WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1953.61 Grid Correction 0.000 Depths Measured From: RKB ~ MSL r-] ssi-1 Target Description Target Coord. E/W Slot Coord. E/W -1514.68 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m[-1 10m~ Vert. Sec. Azim. 142.91 Magn. to Map Corr. 0.000 Map North to: OTHER i SURVEY DATA Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Build (+) Right (+) Comment Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (F'r) (00) (DD) (FT) (FT) (FT) (F'r) Per 100 F~ Drop (-) Left (-) 07-SEP-01 MWD 6938.00 39.29 145.47 96.00 5729.48 3648.35 -2908.65 2202.33 0.61 -0.60 0.15 07-SEP-01 MWD 7033.00 39.09 144.90 95.00 5803.11 3708.34 -2957.93 2236.60 0.43 -0.21 -0.60 07-SEP-01 MWD 7129.00 38.88 144.79 96.00' 5877.73 3768.70 -3007.31 2271.38 0.23 -0.22 -0.11 08-SEP-01 MWD 7224.00 38.73 144.54 95.00 5951.77 3828.20 -3055.88 2305.81 0.23 0.16 -0.26 08-SEP-01 MWD 7320.00 38.58 144.31 96.00 6026.73 3888.15 -3104.65 2340.69 0.22 -0.16 -0.24 08-SEP-01 MWD 7414.00 38.06 144.22 94.00 6100.48 3946.42 -3151.96 2374.73 0.56 -0.55 -0.10 08-SEP-01 MWD 7510.00 37.50 143.84 96.00 6176.36 4005.22 -3199.56 2409.28 0.63 -0.58 -0.40 08-SEP-01 MWD 7605.00 37.47 144.06 95.00 6251.74 4063.02 -3246.30 2443.30 0.14 -0.03 0.23 08-SEP-01 MWD 7701.00 38.73 144.67 96.00 6327.29 4122.23 -3294.45 2477.81 1.37 1.31 0.64 08-SEPt01 MwD 7797.00 38.44 144.49 96.00 6402.33 4182.08 -3343;24 2512.51 0.32 -0.30 -0.19 08-SEP-01 MWD 7892.00 38.16 144.39 95.00 6476.88 4240.94 -3391.14 2546.75 0.30 -0.29 -0.11 , 08-SEP-01 MWD 7988.00 38.03 144.33 96.00 6552.43 4300.15 -3439.27 2581.26 0.14 -0.14 -0.06 08-SEP-01 MWD 8084.00 38.00 143.84 96.00 6628.06 4359.26 -3487.16 · 2615.94 0.32 -0.03 -0.51 -- , , 08-SEP-01' MWD 8179.00 37.86 143.47 95.00 6703.00 4417.65 -3534.19 2650.55 0.28 -0.15 -0.39 .. 08-SEP-01 MWD 8276.00 37.98 143.26 97.00 6779.52 4477.26 -3582.03 2686.12 0.18 0.12 -0.22 08-SEP-01 MWD 8371.00 37.71 143.31 95.00 6854.54 4535.54 -3628.75 2720.97 0.29 -0.28 0.05 08-SEP-01 MWD 8466.00 37.38 143.41 95.00 6929.86 4593.43 ,3675.20 2755.51 0.35 -0.35 0.11 08-SEP-01 MWD 8541.00 37.31 143.54 75.00 6989.49 4638.93 -3711.76 2782.59 0.14 -0.09 0.17 08-SEP-01 MWD 8562.00 37.29 143.71 21.00 7006.19 4651.65 -3722.01 2790.14 0.50 -0.10 0.81 08-SEP-01 MWD 8658.00 36.90 143.80 96.00 7082.76 4709.55 -3768.71 2824.37 0.41 -0.41 0.09 08-SEP-01 MWD 8753.00 36.37 144.01 95.00 7159.00 4766.23 -3814.51 2857.77 0.57 -0.56 0.22 08-sEp-01 MWD 8850.00 36.93 144.27 97.00 7236.82 4824.11 -3861.44 2891.69 0.60 0.58 0.27 09-SEP-01 MWD 8942.00 37.23 144.85 92.00 7310.22 4879.56 -3906.63 2923.85 0.50 ' 0.33 0.63 09-SEP-01 MWD 9038.95 36.96 144.67 96.95 7387.55 4938.00 -3954.39 2957.59 0.30 -0.28 -0.19 I~ t·: [ ! ~ :1 ::~"~ Company PHILLIPS ALASKA, INC. Rig Contractor & No...D°y°n Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No, PAD CD#2/39 PH1 / 39 SurVey Section Name CD2-39 PB1 MWD BHI Rep. C MILCHAK , WELL DATA , Target TVD (F'r) Target Coord, N/S Slot Coord. N/S -1953.61 Grid Correction 0,000 Depths Measured From: RKB ~ MSLE} ssE~ Target Description Target Coord. E/W Slot Coord. E/W -1514.68 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m0 lomE] Vert. Sec. Azim, 142.91 Magn. to Map Corr. 0.000 Map North to: OTHER i 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) (DD) (DB) (FI') (F"r) (FT) (FT) (Per ~00 F--r) Drop (-) Left (-) 09-SEP-01 MWD 9113.00 36.96 144,67 74.05 7446.72 4982.51 -3990.71 2983.34 0.00 0.00 0.00 Projected Data - NO SURVEY · , , SURVEY CALCULATION. AND FIELD WORKSHEET Job No. 0450-00101 Sidetrack No. 1 Page 1 of .... 3_ Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/39 PH1 / 39 Survey Section Name CD2-39 MWD BHI Rep. MILCHAK / GEHRES I~r~ WELL DATA Target TVD (F~ Target Coord. N/S Slot Coord. N/S -1953.61 Grid Correction 0.000 Depths Measured From: RKB ~ MSLE~ SS[~ Target Description Target Coord. E/W Slot Coord. E/W -1514.68 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m0 10m0 reft. Sec. Azim. 151.86 Magn. to Map Corr. 0.000 Map North to: OTHER I 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) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) MWD 8371.00 37.71 143.31 6854.54 4483.71 -3628.75 2720.97 TIE IN POINT 11-SEP-01 MWD 8425.00 38.09 143.00 54.00 6897.15 4515.90 -3655.30 2740.86 0.79 0.70 -0.57 11 -SEP-01 MWD 8445.00 39.55 143.54 20.00 6912.73 4528.29 -3665.34 2748.36 7.49 7.30 2.70 11-SEP-01 MWD 8475.00 ' 41.93 143.80 30.00 6935.46 4547.67 -3681.12 275.9.96 7.95 7.93 0.87 11 -SEP-01 MWD 8539.00 42.46 144.15 64.00 6982.88 4590.25 -3715.88 2785.24 0.91 0.83 0.55 11 -SEP-01 MWD 8580.00 43.64 145.77 41.00 7012.84 4618.04 -3738.80 2801.30 3.94 2.88 3.95 11 -SEP-01 MWD 8607.00 46.26 146.34 27.00 7031.94 4637.01 -3754.62 2811.95 9.82 9.70 2.11 11 -SEP-01 MWD 8635.00 49.39 146.93 28.00 7050.74 4657.67 -3771.95 2823.36 11.29 i 1.18 2.11 11-SEP-01 MWD 8668.00 53.14 148.19 33.00 7071.39 4683.34 -3793.68 2837.16 11.75 11.36 3.82 I. 11 -S EP-01 MWD 8728.00 58.93 149.30 60.00 7104.89 4733.01 -3836.21 2862.95 9.77 9.65 1.85 11-SEP-01 MWD 8793.00 60.39 150.33 65.00 7137.73 4789.06 -3884.70 2891.15 2.63 2.25 1.58 1 i -SEP-01 MWD 8826.00 63.00 150.62 33.00 7153.37 4818.11 -3909.98 2905.47 7.95 7.91 0.88 , 11 -S EP-01 MWD 8859.00 65.88 151.57 33.00 7167.61 4847.87 -3936.04 2919.85 9.11 8.73 2.88 ., 11 -SEP-O1 MWD 8890.00 68.83 151.75 31.00 7179.54 4876.48 -3961.21 2933.43 9.53 9.52 0.58 -- 11 -SEP-01 MWD 8920.00 71.76 151.50 30.00 7189.66 4904.72 -3986.06 2946.86 9.80 9.77 -0.83 11 -SEP-01 MWD 8954.00 75.10 152.14 34.00 7199.35 4937.30 -4014.78 2962.24 9.99 9.82 1.88 11 -SEP-01 MWD 8987.00 76.38 151.36 33.00 7207.48 4969.28 -4042.96 2977.38 4.50 3.88 -2.36 11 -SEP-01 MWD 9015.00 78.57 151.56 28.00 7213.55 4996,62 -4066.97 2990.44 7.85 7.82 0.71 11 -SEPt01 MWD 9047.00 80.90 151.36 32.00 7219.26 5028.10 -4094.63 3005.48 7.31 7.28 -0.63 11-SEP-01 MWD 9069.00 82.81 150.67 22.00 7222.37 . 5049.88 -4113.68 3016.03 9.22 8.68 -3.14 15-SEP-01 MWD 9132.00 87.50 150.88 63.00 7227.69 5112.62 -4168.44 3046.67 7.45 7.44 0.33 15-SEP-01 MWD 9215.00 88.94 149.71 83.00 7230.27 5195.55 -4240.50 3087.78 2.23 1.73 -1.41 15-SEP-01 MWD 93i 1.00 89.18 150.36 96~00 7231.84 5291.48 -4323.66 3135.72 0.72 0.25 0.68 15-SEP-01 MWD 9406.00 89.59 150.30 95.00 7232.86 5386.44 -4406.19 3182.75 0.44 0.43 -0.06 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD , Well Name & No. PAD CD#2/39 PH1 ! 39 Survey Section Name CD2-39 MWD BHI Rep. MILCHAK / GEHRES J~Jlil~"~l~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1953.61 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. EJW -1514.68 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 151.86 Magn. to Map Corr. 0.000 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 (FT) (DO) (OD) (FT) (FT) (FT) (FT) (Per 100 F'r)Drop (-) Left (-) i 5-SEP-01 MWD 9501.00 89.97 150.20 95.00 7233.23 5481.41 -4488.67 3229.89 0.41 0.40 -0.11 (- 15-SEP-01 MWD 9597.00 90.27 150.95 96.00 7233.03 5577.38 -4572.29 3277.05 0.84 0.31 0.78 15-SEP-O1 MWD 9691.00 90.99 151.07 94.00 7231.99 5671.36 -4654.50 3322.60 0.78 0.77 0.13 15-SEP-01 MWD 9787.00 89.93 150.04 96.00 7231.22 5767.33 -4738.10 3369.79 1.54 -. -1.10 -1.07 15-SEP-01 MWD 9883.00 89.49 149.55 96.00 7231.71 5863.27 -4821.06 3418.09 0.69 -0.46 -0.51 15-SEP-01 MWD 9979.00 89.76 149.99 96.00 7232.34 5959.20 -4904.01 3466.42 0.54 0.28 0.46 15-SEP-01 MWD 10075.00 90.21 150.66 96.00 7232.36 6055.17 -4987.42 3513.95 0.84 0.47 0.70 15-SEP-01 MWD 10171.00 90.55 150.43 96.00 7231.73 6151.14 -5071.00 3561.16 0.43 0.35 -0.24 15-SEP-01 MWD 10267.00 90.92 150.30 96.00 7230.50 6247.10 -5154.44 3608.62 0.41 0.39 -0.14 16-SEP,01 MwD 10361.00 90.34 149.58 94.00 7229.46 6341.04 -5235.79 3655.70 0.98 -0~62 -0.77 ~ 16-SEP-01 MWD ' 10456.00 90.55 149.61 95.00 7228;72 6435.96 -5317.72 3703.78 0.22 0.22 0.03 16-SEP-01 MWD 10551.00 88.56 149.85 95,00 7229.46 6530.89 -5399.76 3751.67 2.11 -2.09 0.25 16-SEP-01 MWD 10648.00 88.83 150.29 97.00 7231.67 6627.82 -5483.81 3800.05 0.53 0.28 0.45 ~ ( - 16-SEP-O1 MWD 10743.00 89~14 150.08 95.00 7233.35 6722.76 -5566.22 3847.28 0.39 0.33 -0.22 16-SEP-01 MWD 10838.00 89.66 150.52 95.00 7234.35 6817.72 -5648.73 3894.34 0.72 0.55 0.46 16,SEP-01 MWD 10934.00 90.10 150.66 96.00 7234.55 6913.70 -5732.36 3941.48 0.48 0.46 0.15 16-SEP-01 MWD 11029.00 90.55 151.19 95.00 7234.01 7008.68 -5815.39 3987.65 0.73 0.47 0.56 16-SEP-01 MWD 11125.00 90.93 150.83 96.00 7232.77 7104.66 -5899.35 4034.17 0,55 0.40 -0.37 , 16-SEP;01 MWD 11221.00 89.28 151.17 96.00 7232.59 7200.65 -5983.31 4080.71 1.75 -1.72 0.35 16-SEp-01 MWD 11317.00 89.62 150.76 96.00 7233.52 7296.63 -6067.24 4127.30 0.55 0.35 -0.43 16-SEP-01 MWD 11412.00 90.00 151.12 95.00 7233.83 7391.62 -6150.28 4173.45 0.55 0.40 0.38 16-SEP-01 MWD 11507.00 90.21 150.05 95.00 7233.66 7486.59 -6233.04 4220.10 1.15 0.22 -1.13 16-SEP-01 MWD 11603.00 90.69 150.10 96.00 7232.90 7582.54 -6316.23 4267.99 0.50 0.50 0.05 16-SEP-01 MWD 11699.00 91.06 150.31 96.00 7231.44 7678.49 -6399.53 4315.69 0.44 0.39 0.22 i S U RVEY CALCU LA TI ON AND FIELD WOR KSH EET Job No. 0450-00101 Sidetrack No. 1 Page 3 of 3 [[l~r]-'l Company PHILLIPS ALASKA, INC. Rig Contractor & No, Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD , Well Name & No. PAD CD#2/39 PH1 / 39 SurVey Section Name CD2-39 MWD BHI Rep. MILCHAK / GEHRES I~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1953.61 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W -1514.68 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m0 10mu Vert. Sec. Azim. 151.86 Magn. to Map Corr. 0.000 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 (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 400 FT) Drop (-) Left (-) 17-SEP-01 MWD 11794.00 89.35 151.05 95.00 7231.10 7773.47 -6482.36 4362.21 1.96 -1.80 0.78 17~SEP-01 MWD 11889.00 89.79 151.47 95.00 7231.81 7868.46 -6565.65 4407.88 0.64 0,46 0,44 17-SEP-01 MWD 11984.00 90.38 151.12 95.00' 7231.67 7963.45 -6648.98 4453.51 0.72 0.62 -0.37 17-SEP-01 MWD 12080.00 90,58 151.42 96.00 7230.86 8059.45 -6733.16 4499,66 0.38 ~, 0,21 0.31 , 17-SEP-01 MWD 12176.00 91.06 151.02 96.00 7229.49 8155.43 -6817.29 4545.87 0.65 0.50 -0.42 17-SEP-01 MWD 12273.00 89,25 152.06 97.00 7229.23 8252.42 -6902.56 4592.09 2.15 -1.87 1.07 17-SEP-01 MWD 12367.00 89.76 151.99 94.00 7230.04 8346.42 -6985.57 4636,19 0.55 0.54 -0.07 17-SEP-01 MWD 12463.00 90.17 151.96 96.00 7230.10 8442.42 -7070.32 4681.29 0.43 0.43 -0.03 17-SEP-01 MWD 12558.00 90.65 151.09 95.00 7229,42 8537.41 -7153.82 4726.58 1.05 0.51 -0.92 17-SEP-01 MWD 12597.00 90.86 151.24 39.00 7228,91 8576.41 -7187.98 4745.39 0.66 0.54 0.38 17-SEP-01 MWD 12651.00 90.86 151.24 54.00 7228.'09 8630.40 -7235.32 4771.37 0.00 0.00 0.00 Projected Data - NO SURVEY -- .. · . Record Of Shipment Of Confidential Information To: I From: AOGCC Phillips Alaska, Inc. 300i F'¢rcuP-',ne. L;r.,...,~ ~,._~ ~jf. "7. ~'~ ~-(:~,/~ P.O. Box 100360 Anchorage, AK 99501 Attn: Steve Davies District: Alaska Anchorage, Alaska 99510-0360 Attn: Jeanne L. Haas (907) 263-4470 ( x ) Enclosed ( )Under separate cover ()Via .................. Subject: Quantity 1 log 1 log 1 log 1 log 1 report Sperry-Sun Drilling Sperry-Sun Drilling Sperry-Sun Drilling Sperry-Sun Drilling Sperry-Sun Drilling 1 report I log 1 log 1 log 1 log Description Services Rig Monitoring TVD log dated 8-14-01 for well CD2-33 Services Rig Monitoring MD log dated 8-14-01 for well CD2-33 Services Rig Monitoring TVD log dated 8-15-01 for well CD2-33A Services Rig Monitoring MD log dated 8-15-01 for well CD2-33A Services Sperry-Sun Drilling Services Sperry-Sun Drilling Services Sperry-Sun Drilling Services Sperry-Sun Drilling Services Sperry-Sun Drilling Services End of Well Report for Alpine CD2-33A End of Well Report for Alpine CD2-33 ! O' Rig Monitoring TVD log dated 9-11-01 for well CD2-39 PH Rig Monitoring MD log dated 9-11-01 for well CD2-39 PH Rig Monitoring MD log dated 9-10-01 for well CD2-39 PH Rig Monitoring TVD log dated 9-10-01 for well CD2-39 PH Note - Please verify and acknowledge receipt by signing and returning this transmittal or faxing it. Fax number 265-1515 Signed by Jeanne L. Haas Received b~ Date Date 11/15/01 Remarks: NOV 1 5 2001 Oil & Gas Cons, Commi~on Anc~ra!]e Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1556 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD2-39,~DI_t~O' 21426 ARC,IMP & DIN (PDC) 09117/01 CD2-39- 21426 VISION RESISTIVITY 09/17101 1 1 ,, CD2-39 21426 VISION DEN/NEUTRON 09117101 1 1 CD2-33A (REDO) 21395 CDR & DIN (PDC) 08113/01 1 10/24/01 DATE: RECEIVED UL.,I /.. U LUUI Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 56~!~ (~i~~llS. Commissior~ ,Anchorage Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1516 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job if Log Description Date BL Sepia Prints CD CD2-39 PB1 21399 PEX/DSI 09/09101 CD2-39 PB1 21399 DSI 09109101 CD2-39 PB1 21399 PEX DENSITY/NEUTRON 09109101 CD2-39 PB1 21399 PEX TVD 09109101 CD2-42 (REDO) 21290 LWD ARC & IMPULSE 05/13/01 10/09/01 SlGNED~~' DATE: RECEIVED UL;I I Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. T~a~k~& Gas Cons. ~ch0rage MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD2-39 Date Dispatche 5-Oct-01 Installation/Rig Doyon 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) ~ O/- ! (.O © 2 REC :_tVED 0CT !,0 2001 qast~a 0il & G~ ~ Cons. Commis~ An~ ~age Received By: ~, ~'~._ (~,..~~.__._~) Please sign and return to: Anadrill LWD Division 3@40 Arctic Bird, Suite 300 Anchorage, Alaska @0503 nrosel@slb.com Fax: 007-561-8417 LWD Log Delivery V1.1, Dec '97 ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska Inc. Field .................... : Colville River Well ..................... : CD2-39PH API number ............... : 50-103-20387-70 Engineer ................. : St. Amour 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 ....... : 15.90 ft KB above permanent ....... : 52.90 ft DF above permanent ....... : 52.90 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: 142.91 degrees 9-Sep-2001 06:31:17 Page 1 of 5 Spud date ................ : 2-Sep-01 Last survey date ......... : 09-Sep-01 Total accepted surveys...: 97 MD of first survey ....... : 0.00 ft MD of last survey ........ : 9113.00 ft Geomagnetic data - Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 01-Sep-2001 Magnetic field strength .: 1147 21 HCNT Magnetic dec (+E/W-) ..... : 25.27 degrees Magnetic dip ............. : 80 54 degrees. MWD survey Reference Criteria Reference G .............. : 1002 68 mGal Reference H .............. : 1147.21 HCNT Reference Dip ............ : 80.54 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.28 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.28 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0,00 0,00 0,00 2 114.00 0.00 0.00 3 201,00 0.54 144.67 4 294,00 2.56 119,03 5 383,00 5.08 117.68 6 473.00 8.03 114.57 7 559,00 10,62 114,35 8 650,00 13,20 116.64 9 739,00 13,63 117.15 10 829,00 13.59 123.98 11 919.00 13,09 125,97 12 1008,00 13,73 129,20 13 1102,00 15,97 135,88 14 1195,00 18.65 140,53 15 1290,00 20.55 141,48 16 1385,00 23,73 141,41 17 1479,00 27.37 139,93 18 1573,00 30,48 139,56 19 1669,00 32.71 139,37 20 1766,00 36,33 141,22 21 1861,00 39.94 144,02 22 1957,00 40,24 143,49 23 2057,00 40,53 143.14 24 2147,00 39.41 143.73 25 2242,00 38,84 144,32 26 2338,00 38,67 145,62 27 2433.00 38.46 145,98 28 2530,00 38,53 146,23 29 2736,00 37,40 147,44 30 2832,00 37,69 146,08 9-Sep-2001 06:31:17 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 0,00 0,00 0.00 0.00 0,00 0.00 114,00 114,00 0,00 0,00 0,00 0,00 87.00 201,00 0.41 -0,33 0.24 0.41 93.00 293,96 2,75 -1,70 2,31 2,87 89.00 382,76 8.13 -4,50 7,53 8,77 90,00 86.00 91,00 89,00 90,00 90,00 89,00 94,00 93.00 95,00 95,00 94,00 94,00 96,00 97,00 472,16 17,27 -8,96 16,78 19,03 557.01 29.52 -14,73 29,47 32,94 646.05 46,20 -22,84 46,40 51,72 732,62 64,76 -32,19 64,81 72,36 820,10 84,31 -42,94 83,02 93,46 907,67 994,24 1085,11 1173.89 1263,38 1351,37 1436,16 1518,42 1600,19 1680,10 1754,81 1828,26 1904,43 1973,40 2047,10 0.00 0,00 144,67 126.39 120,82 95.00 96,00 100,00 90,00 95,00 118.10 116,56 116,21 116,41 117,35 104,07 -54,83 100,03 114,07 118,73 123,97 -67.43 116,37 134.50 120,09 147,64 -83,76 134,03 158,05 122,00 175,21 -104.43 152,39 184,74 124.42 207,05 -129,21 172,43 215,47 126.85 242,84 -157,20 194,74 250,27 128.91 283,34 -188,53 220,46 290,08 130,54 328,73 -223,22 249,84 335,03 131,78 378,93 -261,44 282,53 384,93 132.78 433,83 -303,74 317,60 439,47 133,72 96,00 95,00 97,00 206,00 96,00 492,47 -350,38 353,16 497.48 134,77 554,29 -400,24 389.71 558,63 135.76 619.08 -452,19 428,42 622,91 136,55 676,89 -498,63 462,86 680,35 137,13 736,82 -547,14 498,08 739,89 137,69 2121,97 796,87 -596,34 532,57 799,54 138,23 2196,25 856,02 -645.33 565.86 858.28 138.75 2272,16 916,31 -695,44 599,53 918,19 139,24 2434.57 1042,73 -801,51 668,87 1043,94 140,15 2510,69 1101,09 -850,43 700,94 1102,07 140,50 2 of 5 DLS (deg/ 100f) 0,00 0.00 0.62 2,24 2,83 3,30 3,01 2,88 0,50 . 1,79 0,75 1.11 3,00 3.24 2,03 3,35 3,93 3,31 2,33 3,88 4,21 0.47 0,37 1,31 0,72 0,87 0.32 0,18 0,66 0,91 Srvy tool type TIP 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 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 ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 31 2927.00 38.88 142.70 95.00 2585.26 32 3022.00 38.78 142.41 95.00 2659.27 33 3118.00 38.60 141.83 96.00 2734.20 34 3212.00 38.57 142.06 94.00 2807.68 35 3308.02 38.51 141.94 96.02 2882.79 36 3405.00 38.46 141.98 37 3499.00 38.36 141.21 38 3595.00 38.25 140.81 39 3690.00 38.01 140.72 40 3786.00 37.94 140.66 96.98 94.00 96.00 95.00 96.00 2958.70 3032.36 3107.69 3182.42 3258.09 9-Sep-2001 06:31:17 Page 3 of 5 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 1159.92 -898.26 1219.48 -945.55 1279.48 -992.92 1338.10 -1039.08 1397.92 -1086.22 1458.26 -1133.75 1516.65 -1179.52 1576.12 -1225.77 1634.74 -1271.20 1693.76 -1316.91 41 3882.00 37.98 140.05 96.00 3333.78 1752.75 -1362.38 42 3976.00 38.74 141.93 94.00 3407.49 1811.05 -1407.71 43 4074.00 39.27 143.41 98.00 3483.65 1872.73 -1456.75 44 4168.00 38.90 145.75 94.00 3556.62 1931.96 -1505.04 45 4264.00 38.95 146.05 96.00 3631.30 1992.19 -1554.98 735.21 771.43 808.28 844.41 881.25 46 4359.00 38.93 145.74 95.00 3705.19 2051.82 -1604.42 47 4455.00 38.95 146.23 96.00 3779.86 2112.07 -1654.43 48 4551.00 39.05 146.40 96.00 3854.47 2172.38 -1704.70 49 4646.00 39.11 146.41 95.00 3928.21 2232.15 -1754.59 50 4743.00 39.20 146.09 97.00 4003.43 2293.30 -1805.52 918.44 954.71 992.15 1029.25 1066.68 1104.35 1141.06 1178.46 1212.81 1246.62 1280.10 1313.85 1347.36 1380.50 1414.53 1448.25 1481.09 1514.51 1547.55 1580.82 51 4839.00 39.03 146.23 96.00 4077.92 2353.76 -1855.82 52 4933.00 38.61 146.04 94.00 4151.15 2412.60 -1904.75 53 5029.00 38.33 145.91 96.00 4226.31 2472.23 -1954.25 54 5124.00 38.18 145.72 95.00 4300.92 2530.98 -2002.90 55 5219.00 38.26 145.35 95.00 4375.55 2589.69 -2051.36 1614.34 1647.83 1681.47 1714.46 1748.22 56 5314.00 38.02 144.95 95.00 4450.27 57 5409.00 37.77 145.00 95.00 4525.24 58 5505.00 37.66 145.11 96.00 4601.18 59 5599.00 37.52 144.65 94.00 4675.66 60 5695.00 37.27 144.58 96.00 4751.93 1160.78 1220.31 1280.31 1338.92 1398.74 1459.08 1517.48 1576.98 1635.64 1694.71 1753.76 1812.09 1873.74 1932.88 1993.00 2052.52 2112.67 2172.88 2232.57 2293.64 2354.04 2412.82 2472.41 2531.12 2589.80 2648.40 2706.70 2765.37 2822.66 2880.93 140.70 140.79 140.85 140.90 140.95 140.99 141.01 141.01 141.00 140.99 140.97 140.97 141.03 141.14 141.28 141.42 141.55 141.68 141.80 141.92 142.03 142.13 142.22 142.31 142.38 142.44 142.50 142.55 142.60 142.64 2648.32 -2099.51 2706.63 -2147.29 2765.31 -2195.43 2822.62 -2242.33 2880.90 -2289.87 2.54 0.22 0.42 0.16 0.10 0.06 0.52 0.28 0.26 0.08 0.39 1.48 1.09 1.62 0.20 0.21 0.32 0.15 0.06 0.23 0.20 0.46 0.30 0.20 0.26 0.36 0.27 0.13 0.33 0.26 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD lviWD MWD MWD MWD MWD MWD MWD FlED MWD MWD 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 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 61 5790.00 37.11 143.67 62 5888.00 36.99 143.30 63 5984.00 37.72 144.05 64 6080.00 37.54 143.47 65 6174.00 38.31 143.37 Course length (ft) 95.00 98.00 96.00 96.00 94.00 TVD depth (ft) 4827.61 4905.83 4982.14 5058.17 5132.32 66 6270.00 37.93 143.12 96.00 5207.84 67 6365.00 38.38 143.29 95.00 5282.54 68 6460.00 39.07 143.35 95.00 5356.66 69 6556.00 38.82 143.45 96.00 5431.32 70 6651.00 38.22 143.65 95.00 5505.65 96.00 95.00 96.00 95.00 96.00 71 6747.00 37.60 143.29 72 6842.00 39.87 145.33 73 6938.00 39.29 145.47 74 7033.00 39.09 144.91 75 7129.00 38.88 144.79 95.00 96.00 94.00 96.00 95.00 96.00 96.00 95.00 96.00 96.00 76 7224.00 38.73 144.54 77 7320.00 38.58 144.31 78 7414.00 38.06 144.22 79 7510.00 37.50 143.84 80 7605.00 37.47 144.06 81 7701.00 38.73 144.67 82 7797.00 38.44 144.49 83 7892.00 38.16 144.39 84 7988.00 38.03 144.33 85 8084.00 38.00 143.84 5581.39 5655.49 5729.48 5803.11 5877.74 5951.77 6026.74 6100.48 6176.36 6251.74 6327.29 6402.33 6476.88 6552.43 6628.07 86 8179.00 37.86 143.47 95.00 6703.00 87 8276.00 37.98 143.26 97.00 6779.52 88 8371.00 37.71 143.31 95.00 6854.54 89 8466.00 37.38 143.41 95.00 6929.86 90 8541.00 37.31 143.54 75.00 6989.49 9-Sep-2001 06:31:17 Page 4 of 5 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 2938.30 -2336.40 2997.35 -2383.85 3055.59 -2430.78 3114.20 -2478.05 3171.97 -2524.45 1781.87 1817.00 1851.50 1886.15 1920.58 3231.23 -2571.93 3289.92 -2618.93 3349.35 -2666.59 3409.69 -2715.03 3468.85 -2762.62 1956.04 1991.19 2026.69 2062.67 2097.82 3527.83 -2810.02 3587.24 -2858.31 3648.35 -2908.66 3708.33 -2957.94 3768.70 -3007.32 2132.93 2167.58 2202.32 2236.59 2271.36 3828.20 -3055.89 3888.14 -3104.66 3946.41 -3151.97 4005.21 -3199.57 4063.02 -3246.31 2305.80 2340.68 2374.72 2409.26 2443.29 4122.23 -3294.45 4182.08 -3343.25 4240.94 -3391.14 4300.15 -3439.28 4359.26 -3487.16 2477.79 2512.49 2546.74 2581.25 2615.93 4417.65 -3534.20 4477.26 -3582.03 4535.54 -3628.76 4593.43 -3675.21 4638.93 -3711.77 2938.33 2997.37 3055.61 3114.21 3171.98 3231.24 3289.93 3349.36 3409.70 3468.86 3527.84 3587.25 3648.35 3708.33 3768.70 3828.20 3888.15 3946.42 4005.22 4063.03 4122.24 4182.10 4240.96 4300.17 4359.29 4417.68 4477.29 4535.58 4593.47 4638.96 142.67 142.68 142.70 142.72 142.74 142.75 142.75 142.76 142.78 142.79 142.80 142.83 142.87 142.91 142.94 142.96 142.99 143.01 143.02 143.03 143.05 143.07 143.09 143.11 143.12 143.13 143.13 143.14 143.14 143.14 2650.54 2686.11 2720.95 2755.50 2782.58 0.60 0.26 0.90 0.41 0.82 0.43 0.49 0.73 0.27 0.65 0.69 2.74 0.61 0.43 0.23 0.23 0.22 0.56 0.63 0.14 1.37 0.32 0.30 0.14 0.32 0.28 0.18 0.29 0.35 0.14 MWD MWD MWD MWD MWD MWD MWD MWD MWD lviWD MWD MWD MWD MWD MWD IviWD MWD, MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 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 9-Sep-2001 06:31:17 Seq Measured Incl Azimuth Course TVD Vertical Displ # depth angle angle length depth section +N/S- - (ft) (deg) (deg) (ft) (ft) (ft) (ft) 91 8562.00 37.29 143.71 21.00 7006.19 92 8658.00 36.90 143.80 96.00 7082.77 93 8753.00 36.37 144.01 95.00 7159.00 94 8850.00 36.93 144.27 97.00 7236.82 95 8942.00 37.23 144.85 92.00 7310.22 96 9038.95 36.96 144.67 96.95 7387.55 Final Survey is Projected to TD of 9113 ft: 97 9113.00 36.96 144.67 74.05 7446.72 Page 5 of 5 4651.65 -3722.02 4709.54 -3768.71 4766.22 -3814.52 4824.11 -3861.45 4879.56 -3906.64 Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool c/ual (ft) (ft) (deg) 100f) type type 2790.13 2824.36 2857.76 2891.68 2923.84 4938.00 -3954.40 2957.58 4982.50 -3990.72 2983.32 4651.69 143.14 0.50 4709.59 143.15 0.41 4766.27 143.16 0,57 4824.16 143.17 0.60 4879.62 143.19 0.50 4938.07 143.21 0.30 4982.58 143.22 0.00 lvIWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6_lC_08] ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska Inc. Field .................... : Colville River Well ..................... : CD2-39 API number ............... : 50-103-20387-00 Engineer ................. : St. Amour ~OUNTY: .................. : 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 ....... : 15.90 ft KB above permanent ....... : 52.90 ft DF above permanent ....... : 52.90 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: 151.86 degrees 17-Sep-2001 13:55:10 Page 1 of 6 Spud date ................ : 2-Sep-01 'Last survey date ......... : 17-Sep-01 Total accepted surveys...: 146 MD of first survey ....... : 0.00 ft MD of last survey ........ : 12651.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 01-Sep-2001 Magnetic field strength..: 1147.21 HCNT Magnetic dec (+E/W-) ..... : 25.27 degrees Magnetic dip ............. : 80.54 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.21 HCNT Reference Dip ............ : 80.54 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.28 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.28 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report 17-Sep-2001 13:55:10 Page 2 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 1 0.00 0.00 0.00 0.00 2 114.00 0.00 0.00 114.00 3 201.00 0.54 144.67 87.00 4 294.00 2.56 119.03 93.00 5 383.00 5.08 117.68 89.00 0.00 0.00 0.00 0 114.00 0.00 0.00 0 201.00 0.41 -0.33 0 293.96 2.59 -1.70 2 382.76 7.52 -4.50 7 .00 .00 .24 .31 .53 0.00 0.00 0.41 2.87 8.77 0.00 0.00 144.67 126.39 120.82 0.00 0.00 0.62 2.24 2.83 TIP MWD MWD MWD MWD 6-axis 6-axis 6-axis 6 473.00 8.03 114.57 90.00 7 559.00 10.62 114.35 86.00 8 650.00 13.20 116.64 91.00 9 739.00 13.63 117.15 89.00 10 829.00 13.59 123.98 90.00 472.16 15.82 -8.96 16 557.01 26.88 -14.73 29 646.05 42.03 -22.84 46 732.62 58.95 -32.19 64 820.10 77.01 -42.94 83 .78 .47 .40 .81 .02 19.03 32.94 51.72 72.36 93.46 118.10 116.56 116.21 116.41 117.35 3.30 3.01 2.88 0.50 1.79 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 11 919.00 13.09 125.97 12 1008.00 13.73 129.20 13 1102.00 15.97 135.88 14 1195.00 18.65 140.53 15 1290.00 20.55 141.48 90.00 89.00 94.00 93.00 95.00 907.67 95.53 -54.83 100 994.24 114.34 -67.43 116 1085.11 137.07 -83.76 134 1173.89 163.96 -104.43 152 1263.38 195.26 -129.21 172 .O3 .37 .03 .39 .43 114.07 134.50 158.05 184.74 215.47 118.73 120.09 122.00 124.42 126.85 0.75 1.11 3.00 3.24 2.03 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 16 1385.00 23.73 141.41 95.00 1351.37 17 1479.00 27.37 139.93 94.00 1436.16 18 1573.00 30.48 139.56 94.00 1518.42 19 1669.00 32.71 139.37 96.00 1600.19 20 1766.00 36.33 141.22 97.00 1680.10 21 1861.00 39.94 144.02 95.00 1754.81 22 1957.00 40.24 143.49 96.00 1828.26 23 2057.00 40.53 143.14 100.00 1904.43 24 2147.00 39.41 143.73 90.00 1973.40 25 2242.00 38.84 144.32 95.00 2047.10 230.46 -157.20 194 270.22 -188.53 220 314.66 -223.22 249 363.78 -261.44 282 417.63 -303.74 317 475.52 -350.38 353 536.72 -400.24 389 600.80 -452.19 428 657.99 -498.63 462 717.37 -547.14 498 .74 .46 .84 .53 .60 .16 .71 .42 .86 .08 250.27 290.08 335.03 384.93 439.47 497.48 558.63 622.91 680.35 739.89 128.91 130.54 131.78 132.78 133.72 134.77 135.76 136.55 137.13 137.69 3.35 3.93 3.31 2.33 3.88 4.21 0.47 0.37 1.31 0.72 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 26 2338.00 38.67 145.62 96.00 2121.97 27 2433.00 38.46 145.98 95.00 2196.25 28 2530.00 38.53 146.23 97.00 2272.16 29 2736.00 37.40 147.44 206.00 2434.57 30 2832.00 37.69 146.08 96.00 2510.69 777.03 -596.34 835.92 -645.33 895.99 -695.44 1022.23 -801.51 1080.49 -850.43 532.57 565.86 599.53 668.87 700.94 799.54 858.28 918.19 1043.94 1102.07 138.23 138.75 139.24 140.15 140.50 0.87 0.32 0.18 0.66 0.91 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 17-Sep-2001 13:55:10 Page 3 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) 31 2927.00 38.88 142.70 95.00 2585.26 32 3022.00 38.78 142.41 95.00 2659.27 33 3118.00 38.60 141.83 96.00 2734.20 34 3212.00 38.57 142.06 94.00 2807.68 35 3308.02 38.51 141.94 96.02 2882.79 36 3405.00 38.46 141.98 96.98 2958.70 37 3499.00 38.36 141.21 94.00 3032.36 38 3595.00 38.25 140.81 96.00 3107.69 39 3690.00 38.01 140.72 95.00 3182.42 40 3786.00 37.94 140.66 96.00 3258.09 41 3882.00 37.98 140.05 96.00 3333.78 42 3976.00 38.74 141.93 94.00 3407.49 43 4074.00 39.27 143.41 98.00 3483.65 44 4168.00 38.90 145.75 94.00 3556.62 45 4264.00 38.95 146.05 96.00 3631.30 46 4359.00 38.93 145.74 95.00 47 4455.00 38.95 146.23 96..00 48 4551.00 39.05 146.40 96.00 49 4646.00 39.11 146.41 95.00 50 4743.00 39.20 146.09 97.00 96.00 94.00 96.00 95.00 95.00 51 4839.00 39.03 146.23 52 4933.00 38.61 146.04 53 5029.00 38.33 145.91 54 5124.00 38.18 145.72 55 5219.00 38.26 145.35 3705.19 3779.86 3854.47 3928.21 4003.43 4077.92 4151.15 4226.31 4300.92 4375.55 56 5314.00 38.02 144.95 95.00 4450.27 57 5409.00 37.77 145.00 95.00 4525.24 58 5505.00 37.66 145.11 96.00 4601.18 59 5599.00 37.52 144.65 94.00 4675.66 60 5695.00 37.27 144.58 96.00 4751.93 1138.83 -898.26 1197.61 -945.55 1256.76 -992.92 1314.51 -1039.08 1373.45 -1086.22 735.21 771.43 808.28 844.41 881.25 1432.90 -1133.75 1490.37 -1179.52 1548.81 -1225.77 1606.37 -1271.20 1664.32 -1316.91 918.44 954.71 992.15 1029.25 1066.68 1722.18 -1362.38 1779.47 -1407.71 1840.35 -1456.75 1899.13 -1505.04 1959.12 -1554.98 1104.35 1141.06 1178.46 1212.81 1246.62 2018.51 -1604.42 2078.53 -1654.43 2138.66 -1704.70 2198.27 -1754.59 2259.23 -1805.52 1280.10 1313.85 1347.36 1380.50 1414.53 2319.49 -1855.82 2378.13 -1904.75 2437.53 -1954.25 2496.03 -2002.90 2554.44 -2051.36 1448.25 1481.09 1514.51 1547.55 1580.82 2612.71 -2099.51 2670.64 -2147.29 2728.95 -2195.43 2785.87 -2242.33 2843.71 -2289.87 1614.34 1647.83 1681.47 1714.46 1748.22 At Azim (deg) 1160.78 1220.31 1280.31 1338.92 1398.74 140.70 140.79 140.85 140.90 140.95 1459.08 1517.48 1576.98 1635.64 1694.71 140.99 141.01 141.01 141.00 140.99 1753.76 1812.09 1873.74 1932.88 1993.00 140.97 140.97 141.03 141.14 141.28 2052.52 2112.67 2172.88 2232.57 2293.64 141.42 141.55 141.68 141.80 141.92 2354.04 2412.82 2472.41 2531.12 2589.80 142.03 142.13 142.22 142.31 142.38 2648.40 2706.70 2765.37 2822.66 2880.93 142.44 142.50 142.55 142.60 142.64 DLS (deg/ 100f) 2.54 0.22 0.42 0.16 0.10 0.06 0.52 0.28 0.26 0.08 0.39 1.48 1.09 1.62 0.20 0.21 0.32 0.15 0.06 0.23 0.20 0.46 0.30 0.20 0.26 0.36 0.27 0.13 0.33 0.26 Srvy tool type MWD FfWD FIWD MWD MWD MWD MWD M-WD FfWD FiWD FiWD MWD MWD FfWD MWD MWD MWD M-WD MWD MWD MWD MWD MWD M-WD MWD FIWD M'WD 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 17-Sep-2001 13:55:10 Page 4 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg (ft) (ft) (ft) (ft) (ft) (deg) 100f 61 5790.00 37.11 143.67 95.00 4827.61 2900.61 -2336.40 62 5888.00 36.99 143.30 98.00 4905.83 2959.02 -2383.85 63 5984.00 37.72 144.05 96.00 4982.14 3016.68 -2430.78 64 6080.00 37.54 143.47 96.00 5058.17 3074.70 -2478.05 65 6174.00 38.31 143.37 94.00 5132.32 3131.85 -2524.45 66 6270.00 37.93 143.12 96.00 5207.84 3190.45 -2571.93 67 6365.00 38.38 143.29 95.00 5282.54 3248.47 -2618.93 68 6460.00 39.07 143.35 95.00 5356.66 3307.24 -2666.59 69 6556.00 38.82 143.45 96.00 5431.32 3366.93 -2715.03 70 6651.00 38.22 143.65 95.00 5505.65 3425.47 -2762.62 1781.87 1817.00 1851.50 1886.15 1920.58 1956.04 1991.19 2026.69 2062.67 2097.82 2938.33 2997.37 3055.61 3114.21 3171.98 142.67 142.68 142.70 142.72 142.74 3231.24 3289.93 3349.36 3409.70 3468.86 142.75 142.75 142.76 142.78 142.79 0.60 0.26 0.90 0.41 0.82 0.43 0.49 0.73 0.27 0.65 Srvy Tool / tool qual ) type type MWD MWD MWD MWD MWD FiWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 71 6747.00 37.60 143.29 96.00 5581.39 3483.82 -2810.02 72 6842.00 39.87 145.33 95.00 5655.49 3542.74 -2858.31 73 6938.00 39.29 145.47 96.00 5729.48 3603.52 -2908.66 74 7033.00 39.09 144.91 95.00 5803.11 3663.14 -2957.94 75 7129.00 38.88 144.79 96.00 5877.74 3723.09 -3007.32 2132.93 2167.58 2202.32 2236.59 2271.36 3527.84 3587.25 3648.35 3708.33 3768.70 142.80 142.83 142.87 142.91 142.94 0.69 2.74 0.61 0.43 0.23 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 76 7224.00 38.73 144.54 95.00 5951.77 3782.15 -3055.89 77 7320.00 38.58 144.31 96.00 6026.74 3841.61 -3104.66 78 7414.00 38.06 144.22 94.00 6100.48 3899.38 -3151.97 79 7510.00 37.50 143.84 96.00 6176.36 3957.65 -3199.57 80 7605.00 37.47 144.06 95.00 6251.74 4014.91 -3246.31 81 7701.00 38.73 144.67 96.00 6327.29 4073.64 -3294.45 82 7797.00 38.44 144.49 96.00 6402.33 4133.03 -3343.25 83 7892.00 38.16 144.39 95.00 6476.88 4191.42 -3391.14 84 7988.00 38.03 144.33 96.00 6552.43 4250.14 -3439.28 85 8084.00 38.00 143.84 96.00 6628.07 4308.72 -3487.16 2305.80 2340.68 2374.72 2409.26 2443.29 2477.79 2512.49 2546.74 2581.25 2615.93 3828.20 3888.15 3946.42 4005.22 4063.03 4122.24 4182.10 4240.96 4300.17 4359.29 142.96 142.99 143.01 143.02 143.03 143.05 143.07 143.09 143.11 143.12 .23 .22 .56 .63 .14 .37 .32 .30 .14 .32 MWD MWD MWD MWD MWD MWD MWD FIWD FIWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 86 8179.00 37.86 143.47 95.00 6703.00 4366.52 -3534.20 87 8276.00 37.98 143.26 97.00 6779.52 4425.47 -3582.03 88 8371.00 37.71 143.31 95.00 6854.54 4483.11 -3628.76 89 8425.00 38.09 143.00 54.00 6897.15 4515.90 -3655.30 90 8445.00 39.55 143.54 20.00 6912.73 4528.29 -3665.35 2650.54 2686.11 2720.95 2740.84 2748.34 4417.68 4477.29 4535.58 4568.75 4581.29 143.13 143.13 143.14 143.14 143.14 0.28 0.18 0.29 0.79 7.49 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 17-Sep-2001 13:55:10 Page 5 of 6 Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 91 8475.00 41.93 143.81 30.00 6935.46 92 8539.00 42.46 144.14 64.00 6982.88 93 8580.00 43.64 145.77 41.00 7012.84 94 8607.00 46.26 146.34 27.00 7031.94 95 8635.00 49.39 146.93 28.00 7050.74 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 4547.67 -3681.13 2759.94 4590.25 -3715.89 2785.22 4618.03 -3738.80 2801.28 4637.01 -3754.63 2811.93 4657.67 -3771.96 2823.34 96 8668.00 53.14 148.19 33.00 7071.39 4683.34 -3793.68 2837.14 97 8728.00 58.93 149.30 60.00 7104.89 4733.00 -3836.21 2862.93 98 8793.00 60.39 150.33 65.00 7137.73 4789.06 -3884.70 2891.14 99 8826.00 63.00 150.62 33.00 7153.37 4818.11 -3909.98 2905.45 100 8859.00 65.88 151.57 33.00 7167.61 4847.87 -3936.04 2919.84 101 8890.00 68.83 151.75 31.00 7179.54 102 8920.00 71.76 151.50 30.00 7189.66 103 8954.00 75.10 152.14 34.00 7199.35 104 8987.00 76.38 151.36 33.00 7207.48 105 9015.00 78.57 151.56 28.00 7213.55 32.00 22.00 63.00 83.00 96.00 7219.25 7222.37 7227.69 7230.27 7231.84 106 9047.00 80.90 151.36 107 9069.00 82.81 150.67 108 9132.00 87.50 150.88 109 9215.00 88.94 149.71 110 9311.00 89.18 150.36 111 9406.00 89.59 150.30 95.00 7232.86 112 9501.00 89.97 150.20 95.00 7233.23 113 9597.00 90.27 150.95 96.00 7233.03 114 9691.00 90.99 151.07 94.00 7231.99 115 9787.00 89.93 150.04 96.00 7231.22 116 9883.00 89.49 149.55 117 9979.00 89.76 149.98 118 10075.00 90.21 150.66 119 10171.00 90.55 150.43 120 10267.00 90.92 150.30 4876.48 -3961.22 2933.42 4904.72 -3986.07 2946.84 4937.30 -4014.79 2962.22 4969.28 -4042.96 2977.36 4996.61 -4066.97 2990.42 5028.10 -4094.63 3005.46 5049.87 -4113.68 3016.02 5112.62 -4168.45 3046.66 5195.54 -4240.51 3087.76 5291.48 -4323.66 3135.71 5386.44 -4406.20 3182.73 5481.40 -4488.68 3229.87 5577.38 -4572.30 3277.03 5671.36 -4654.51 3322.59 5767.33 -4738.11 3369.78 96.00 7231.71 5863.27 -4821.07 3418.07 96.00 7232.34 5959.20 -4904.01 3466.41 96.00 7232.36 6055.17 -4987.41 3513.95 96.00 7231.73 6151.14 -5071.00 3561.15 96.00 7230.49 6247.10 -5154.44 3608.62 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 4600.86 4643.84 4671.81 4690.86 4711.57 4737.24 4786.74 4842.48 4871.31 4900.80 4929.12 4957.08 4989.32 5020.98 5048.06 5079.26 5100.86 5163.15 5245.59 5341.04 5435.47 5529.95 5625.37 5718.75 5814.21 5909.82 6005.44 6100.99 6196.52 6292.09 143.14 143.15 143.16 143.17 143.18 143.21 143.27 143.34 143.38 143.43 143.48 143.53 143.58 143.63 143.67 143.72 143.75 143.84 143.94 144.05 144.16 144.26 144.37 144.48 144.58 144.66 144.75 144.83 144.92 145.00 7.96 0.90 3.96 9.82 11.29 11.75 9.77 2.63 7.95 9.11 9.53 9.80 9.99 4.50 7.85 7.31 9.22 7.45 2.23 0.72 0.44 0.41 0.84 0.78 1.54 0.69 0.53 0.85 0.43 0.41 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD IMP MWD IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP 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 5-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 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 121 10361.00 122 10456.00 123 10551.00 124 10648.00 125 10743.00 90.34 90.55 88 56 88.83 89 14 149.58 149.61 149.85 150.29 150.08 126 10838.00 127 10934.00 128 11029.00 129 11125.00 130 11221.00 89 66 90.10 90 55 90.93 89 28 150.52 150.66 151.19 150.83 151.17 131 11317.00 132 11412.00 133 11507.00 134 11603.00 135 11699.00 89 62 90.00 90 21 90.69 91.06 150.76 151.12 150.05 150.10 150.31 136 11794.00 89.35 151.05 137 11889.00 89.79 151.47 138 11984.00 90.38 151.12 139 12080.00 90.58 151.42 140 12176.00 91.06 151.02 141 12273.00 89.25 152.06 142 12367.00 89.76 151.99 143 12463.00 90.17 151.96 144 12558.00 90.65 151.09 145 12597.00 90.86 151.24 Projected to a Total Depth of 146 12651.00 90.86 151.24 Course length (ft) 94.00 95.00 95.00 97.00 95.00 95.00 96.00 95.00 96.00 96.00 96.00 95.00 95.00 96.00 96.00 95.00 95.00 95.00 96.00 96.00 97.00 94.00 96.00 95.00 39.00 12651 ft: 54.00 17-Sep-2001 13:55:10 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 7229.46 7228.72 7229.46 7231.67 7233.35 7234.35 7234.55 7234.01 7232.77 7232.59 7233.51 7233.83 7233.65 7232.90 7231.44 7231.10 7231.81 7231.67 7230.86 7229.49 7229.23 7230.04 7230.10 7229.42 7228.90 6341.04 -5235.79 6435.96 -5317.72 6530.89 -5399.76 6627.81 -5483.81 6722.76 -5566.22 3655.70 6385.74 145.08 3703.78 6480.44 145.14 3751.66 6575.14 145.21 3800.05 6671.77 145.28 3847.27 6766.41 145.35 6817.72 -5648.73 6913.69 -5732.36 7008.68 -5815.39 7104.66 -5899.35 7200.65 -5983.31 3894.34 6861.05 145.42 3941.48 6956.67 145.49 3987.64 7051.24 145.56 4034.17 7146.81 145.63 4080.71 7242.39 145.71 7296.63 -6067.24 7391.62 -6150.28 7486.59 -6233.03 7582.54 -6316.23 7678.49 -6399.53 4127.30 7337.98 145.77 4173.44 7432.60 145.84 4220.10 7527.28 145.90 4267.99 7623.03 145.95 4315.69 7718.75 146.01 7773.47 -6482.36 7868.46 -6565.65 7963.45 -6648.98 8059.44 -6733.16 8155.43 -6817.29 4362.20 7813.44 146.06 4407.88 7908.05 146.12 4453.51 8002.67 146.19 4499.65 8098.29 146.25 4545.87 8193.92 146.30 8252.42 -6902.56 8346.42 -6985.57 8442.42 -7070.32 8537.41 -7153.82 8576.40 -7187.98 4592.09 8290.51 146.37 4636.18 8384.06 146.43 4681.29 8479.61 146.49 4726.58 8574.25 146.55 4745.39 8613.12 146.57 8630.39 -7235.32 4771.37 7228.09 8666.93 146.60 6 of 6 DLS (deg/ i00f) 0.98 0.22 2.11 0.53 0.39 0.72 0.48 0.73 0.55 1.75 0.55 0.55 1.15 0.50 0.44 1.96 0.64 0.72 0.38 0.65 2.15 0.55 0.43 1.05 0.66 0.00 Srvy tool type IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP 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 [(c)2001 Anadrill IDEAL ID6_iC_08] 09/27/01 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1488 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD '~? CD2-33A 21395 M10,CDR,N/D (PDC) 08/13/01 1 CD2-33A 21395 CDR RESISTIVITY MD 08/13/01 CD2-33A 21395 CDR RESISTIVITY TVD 08/t 3/01 CD2-33A 21395 VISION DIN MD 08/13/01 1 1 CD2-33A 21395 VISION DIN TVD 08/13/01 1 CD2-39 PB1 21400 N/D & ARC (PDC) 09109101 CD2-39 PB1 21400 VISION RESISTIVITY MD 09109101 CD2-39 PB1 21400 VISION RESISTIVITY TVD 09/09/01 1 CD2-39 PB1 21400 VISION DIN MD 09/09/01 t 1 CD2-39 PB1 21400 VISION DIN TVD 09/09/01 I 1 CD2-24 PB1 21322 PROCESSED DSI 06/15/01 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 09/26/01 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1481 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD ;CD2-33B 21396 M10,CDR,IMP 09124101 CD2-33B 21396 VISION RESISTIVITY MD 09124101 CD2-33B 21396 CDR RESISTIVITY TVD 09124101 CD2-39 PB1 21393 PROCESSED DSI 09109/01 D SE P 2:8 2001 DATE: Alaska Oil & Gas Cons. Commia,~ion Anchoraoe Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 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 _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Disposal 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1954' FNL, 1516' FEL, Sec. 2, T11N, R4E, UM At top of productive interval 802' FNL, 1537' FWL, Sec. 12, T11N, R4E, UM At effective depth At total depth 1347' FSL, 2071' FEL, Sec. 12, T11N, R4E, UM 5. Type of Well: Development Exploratory __ Stratig raph ic _ Service _ ..... Per APD ..... Per APD 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Colville River Unit 8. Well number CD2-39 9. Permit number/approval number 201-160 10. APl number 50-103-20387 11. Field / Pool Oolville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measu red true vertical Effective depth: measured true vertical Casing Length Conductor 78' Surface 2617' Production 9085' 12651 7228 12651 7228 Size 16" 9-5~" 7' feet Plugs (measured) feet feet Junk (measured) feet Cemented lO yds portland 3 ready mix cmt 405 Sx AS III L & 2,30 Sx 15.8 class G 145 Sx 15.8 class G Measured Depth 115' 2654' 9122' True vertical Depth 115' 2370' 7228' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3.5" 9.3#, 1-80 @ 8774' MD 7" Baker SAB-3 Permanent Packer @ 8682' MD, Camco TRM-4E @ 2206' MD 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __X 15. Status of well classification as: 14. Estimated date for commencing operation October 4, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas __ Suspended __ Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ ~ Title: Alpine Drilling Team Leader Chip Alvord " Questions? Call Vern Johnson 265-6051 Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I App~yal r~o...,~ Plug integrity__ BOP Test_ Location clearance_ I,,, , '~_~7~"~{'"',~ Mechanical Integrity Test_ Subsequent form required 10-~.~ '~;' (;~.~,"¢, ~.~(~.~~~ ORIGINAL SIGNED B'Y /~;~ / I Approved by order of the Commission r') Taylor Seamount Commissioner Date Form 10-403 Rev 06/15/88 · O?,/G/i'4kL SUBMIT IN TRIPLICATE Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. b. The depth to the base of freshwater aquifers and permafrost, if present. c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. d. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. f. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operation and calculations showing how this value was determined. g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission to confirm containment of drilling wastes. ....... CD2-39 There are no USDW aquifers in the Colville River Unit. Base of Permafrost = 1600' TVD (RKB) The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. Types of fluids can be mud, diesel, cement, and water. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated pressure at casing shoe during disposal operations is 1906 psi. See attached calculation page. See attached cementing reports, LOT/FIT reports, and casing reports. See attached casing summary sheet and calculation page. NA DETAILS: CD2-39 Pressure Calculations for Annular Disposal ~9-5/8" 36 Ib/ft, J-55 BTC casing @ 2654 ft MD (2370 ft TVD) Pbu~t = 3520 psi, @ 85%: Pbu~85°,'o = 2992 psi Estimated Top of Cement @ 8375 ft MD (6858 ft TVD) (7" csg x 8-1/2" Open hole annulus) ~7" 26 Ib/ft, L-80, BTC casing @ 9122 ft MD (7227 ft TVD) Pco,apse = 5410 psi, @ 85%: Pco,ap~e85°/o = 4598 psi ~=3-1/2" 9.3 Ib/ft L-80 tubing to 8774 ft MD ASSUMPTIONS: · Maximum injection pressure, PApp,ed = 1500 psi · Maximum density of injection fluid is 12.0 ppg. · Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft · Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULATIONS: Maximum pressure at 9-5/8" shoe: Pmax = PHydrostatic -I- PApplied ' PFormation Pmax = 12.0 (0.052) (2370)+1500- 0.4525 (2370) Pmax = 1906psi Maximum fluid density to burst 9-5/8" casing: Pburst85% = PHydrostatic + PApplied ' PFormation 2992 = UWm~x (0.052) (2370) + 1500- 0.4525 (2370) MWmax = 20.8 ppg Maximum Fluid Density to Collapse 7" Casing: Pco,apse85% = PHydrostatic + PApplied' PGasGradient ' PHeader 4598 = UWm~ (0.052) (6858) + 1500- (0.1) (6858) - 2000 MWmax = 16.2 ppg Casing Detail Well: CD2-39 9 518" Surface Casing Date: 9/4/0I PHILLIPS Alaska, Inc, ~ A SUbSidiary or PHILLIPS Pi: 1 FIOLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.85 FMC Gen V Hanger 2.95 36.85 Jts 3 to 61 59 Jts 9-5/8" 36# J-55 BTC Csg 2524.09 39.80 Davis Lynch Float Collar 1.54 2563.89 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 86.93 2565.43 Davis Lynch Float Shoe 1.75 2652.36 2654.11 TD 12 1/4" Surface Hole 2663.00 RUN TOTAL 35 BOWSPRING CENTRALIZERS - I per jt on Jt #1 - #13 (On stop rings of Jt #1 & #2) and over collars on jts# 15,17,19,21,23,25,27,29,31 33,35,37,39,41,43,45,47,49,51,53,55. Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 165k Dn Wt - 137k Block Wt - 70k Supervisor'. David P. Budey PHILLIPS ALASKA INC, Cementing RepOrt Page 1 of 3 Legal Well Name: CD2-39 Common Well Name: CD2-39 Event Name: ROT - DRILLING Prim:ary Hole Size: 12.250 (in) TMD Set: 2,654 (ft) Date Set: 9/4/2001 Csg Type: Surface Casing Csg Size: 9.625 (in.) Report #: 1 Start: 8/29/2001 Spud Date: 8/31/2001 Report Date: 9/4/2001 End: : Squeeze;oPen Hole Hole Size: SQTMD: (fi) SQ Date: SQ Type: :::SqUeeze:Casing: ::::: Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: plUg Hole Size: Top Set: (ft) BTM set: (fi) Plug Date: Plug Type: Drilled Out: i Cmtd. Csg: Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jerry Culpepper Pipe Movement: Reciprocating .. . ..:'~:'. ": ' ' ' ' :. Pipe :MoVement .... :"'; .'~: : ....:.'.i:::: .... ' ..... ; ' Rot Time Start: · Time End: · RPM: Init Torque: (fi-lb0 Avg Torque: (fi-lbo Max Torque: (fi-lbo Rec Time Start: 12:30 Time End: 16:25 SPM: Stroke Length: 25.0 (ft) Drag Up: 165 (lbs) Drag Down: 137 (lbs) · ".. .:. . ... .. Type: Cement Casing Volume Excess %: 150.00 Meas. From: Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 420 (gpm) Mud Circ Press: 550 (psi) Start Mix Cmt: 15:02 Start Slurry Displ: 15:04 Start Displ: 16:09 End Pumping: 16:30 End Pump Date: 9/4/2001 Top Plug: Y Bottom Plug: Y Returns: Full i Total Mud Lost: Cmt Vol to Surf: Disp Avg Rate: 9.50 (bbl/min) Disp Max Rate: 10.00 (bbl/min) Bump Plug: Y Press Prior: 500 (psi) Press Bumped: 1,000 (psi) Press Held: 2 (min) Float Held: Y (bbl) (bbl) Ann Flow After: N Mixing Method: Density Meas By: Densomiter MUd. Data ..... '"" ' : ':;' ":';'" Type: Spud Mud Density: 9.7 (ppg) Visc: 54 (s/qt) Bottom Hole Circulating Temperature: (°F) Displacement Fluid Type: Mud PV/YP: 16 (cp)/19 (Ib/100ft2) Gels 10 sec: 10 (Ib/100ft2) Gels 10 min: 15 (Ib/100fi2) Bottom Hole Static Temperature: (°F) Density: 9.7 (ppg) Volume: 199.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: To: (fi) (°F) Description: Biozan w/nutplug marker Cmt Vol: .(bbl) Density: 8.34 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Purpose: SPACER Yield: (ft3/sk) Mix Water: (bbl) Other Vol: 0 Foam Job: N Temperature: (°F) Temperature: (°F) Temperature: (°F) Compressive Strength 1' Compressive Strength 2: Time Temp Pressure (°F) (psi) (°F) (psi) Printed: 9/8/2001 9:55:53AM Legal Well Name: CD2-39 Common Well Name: CD2-39 Event Name: ROT - DRILLING PHILLIPS ALASKA INC. Cementing RePort page 2 of 3 Spud Date: 8/31/2001 Report #: 1 Report Date: 9/4/2001 Start: 8/29/2001 End: Stage No: I Slurry NO: 2 of4 ' Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: To: (ft) (°F) Description: ARCO Spacer Class: Purpose: SPACER Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (fP/sk) Mix Water: (bbl) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Foam Job: N Temperature: (°F) Temperature: (°F) Temperature: (°F) Time Temp Pressure Compressive Strength 1' (°F) (psi) Compressive Strength 2: (°F) (psi) Slurry Data Fluid Type: Lead Slurry Interval: 2,154.00 (fi)To: 37.00 (ft) Water Source: Description: ASLite Class: G Purpose: PRIMARY CmtVol: 320.0 (bbl) Density: 10.70 (ppg) Yield: 4.44 (fP/sk) MixWater: (bbl) Slurry Vo1:405 (sk) Water Vol: (bbl) Other Vol: 0 Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (°F) Temperature: (°F) Temperature: (°F) Temperature: (°F) Time Temp Pressure Compressive Strength 1' (°F) (psi) Compressive Strength 2: (°F) (psi) Slurry Data Fluid Type: TAIL Description: G + Adds Slurry Interval: 2,654.00 (fi)To: 2,154.00 (fi) Cmt Vol: 48.0 (bbl) Water Source: Slurry Vol: 230 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (°F) Temperature: (°F) Temperature: (°F) Temperature: (°F) Class: G Purpose: PRIMARY Density: 15.80 (ppg) Yield: 1.17 (ft'/sk) Mix Water: (bbl) Water Vol: (bbl) Other Vol: 0 Foam Job: N Time Temp Pressure Compressive Strength 1' (°F) (psi) Compressive Strength 2: (°F) (psi) Printed: 9/8/2001 9:55:53 AM Legal Well Name: CD2-39 Common Well Name' CD2-39 Event Name: ROT- DRILLING PHILLIPS ALASKAiINC. Cementing Report Report #: Start: 1 8/29/2001 Page 3 of 3 Spud Date: 8/31/2001 Report Date: 9/4/2001 End: Casing~Test Shoe Test Liner:TOp Te:st: Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Log/s:u rVey. Evaluation .' Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Inter:pretation summary. .. Tool: N Tool: N CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks:':..~ ..':. ~. : ' · . ': ..: · . .. :::'. :... Displaced cement with 20bbls of fresh water from cementers, and 179 bbls of mud with rig pumps. Displaced mud @ 10 bpm, slowed to 8 bpm after 20 bbls of tail around shoe. Reciprocated pipe untill last 20 bbls of displacement, had 119 bbls of 10.7 ppg cement returns to surface with full returns throughout. ' Printed: 9/8/2001 9:55:53 AM :Page 1 of 2 Phillips Alaska, Inc, Daily Drilling Report WELL NAME JOB NUMBER EVENT CODE 24 HRS PROG TMD 'rv9376.02, DFS REPT NO. DATE C92-39 ODR 2,663.0 3.00 3 9/4/2001 SUPERVISOR I RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD DALLY TANG CUM. TANG David BurleyI Doyon 19 Alpine 0.00 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD CUM INTANG WI MUD Testing DOPE. 0.00 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD BHA #3, MIT, clean out cmt, FIT, drill 8-1/2" hole. 9/4/2001 319,898 614,634 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE 998907 AUTH. LAST SURVEY: DATE TMD INC AZIM LAST CASING NEXT CASING LAST BOP PRES TEST 9/3/2001 2,530.00 38.530 146.230 (in) ~ (ft) (in) (~ (ft) DENSITY(PPg) ! 9.60 PPi ECDI MUD DATA DA~LY COST.. 0.00 . CUM COST 0.00 .FV'53 · PV/YP.19/19 1GELS:10/15 WLIHTHP" FCIT'SOL' OILIWAT 1%SandlMBTll.2/ / / /20.0 I:''P'hIp'M:8.0/ '1 '.PfiMf/ '[" .Cl.." Ca. · H2S LIME[ ES BNA. NO~.: 3 .' ' '. .....'... · .BHA/. :HOLE'CONDITIONS .... ". ". :.' .' ':: ".' ." .'BIT. ...NO;':.. I 3 · BHA;WT. BELOW JARS : STRING:WT. UP · .':. "'STRING:WT. DN..' '1 i:STRINGWT...ROTii . · .TORQUE/UNITS. · ii. "BHA:LENGTH I .,.. . . 1,095.52 ... . . .. . .:'i.' : 'i.i :".:': '..' 'ITEMDESCR[PTION' ' · ! .. ' NoJTS" . ::LENGTH: ' ..O~D;:"': ' il.D, ':'. 'CONN.SIZE::' CO:NNTYPE BIT 1 1.00 8.500 6 3/4"MACH1XL 1.2 I 31.60 6.750 NMSTAB 1 5.00 2.875 GAMMA SUB 1 19.73 7.000 3.250 MWD 1 27.32 7.000 3.250 NEUTRON I 22.34 7.000 3.250 NON-MAG FLEX 3 90.00 4.500 2.875 XO 1 1.68 6.250 3.000 HWT 3 89.48 5.000 3.000 JARS 1 32.98 6.125 2.250 HWT 26 774.39 5.000 3.000 .'.:': .::.i'.i: ' : '.':. '."i :BITS:' ::::: :"':' i:.:. :':'".':'..:i : ..". .... .' · . . . . "BIT/RUN .:' · SIZE .... MANUF~ .".: TypE.... SERIALNO..' '.'JETSORTFA .... i. :i..DEpTHiN DATE.iN::.:: · i.O~D.L.B-G.OiR 2/ 12.250 ISTC H°. 75001'~ 2,663.0 "9/3/2'°Oll0:0-:-:---- ' ..... · :'::~.'":: " ' ': "" .'.' .'. :..'BIT:OPERATIONS; . .: . :: : :. '";: ". ~.'.:'i .... ~.:.;i::...:'::.'..::::'.":. :.' · ' ' ' .' ' .:" :.' : CUM DEPTH: ' BIT/RUN 'i...'WOB '. .' RPM: !'GPM:". PRESS.' ".PBIT HRS..:. .:24H:~DIST:' :2.4HrROp! CUM. HRS 'cUM'ROP 2/ / / · . :':..':. :.. · ... '.':.,..' ..':OPERATIONS:'SUMMARY:::."~'::..:: i.i. :~:...I.::::: !: ;: :.':...~": , ,. FROM. .'TO .... HOURS "'CODE TROUBI".E . SUB : 'PHASE .... ' '":.'.:.?i".i:. :i' i .'" DESCRI. PT!ON:::!:"i".:.":.;'''' :";':i "' 00:00 01:00 1.00 DRILL T TRIP SURFAC RIH with BNHO clean out assembly to 2663', no problems. 01:00 03:00 2.00 DRILL T CIRC SURFAC Circ and condition mud with 15 bpi, 130 rpm, had large amount of clay cuttings back, shakers overloaded for 20 min. Pumped 40 bbl 11.2 ppg sweep, circ hole clean. Monitor well, static. 03:00 06:00 3.00 DRILL T TRIP SURFAC POH, max overpull 15k, no swabbing. LD BNHO, clean rig floor. 06:00 08:00 2.00 CASE P RURD SURFAC RU to run 9-5/8" casing, held prejob safety meeting with crew. 08:00 12:00 4.00 CASE P RUNC SURFAC Ran 61 joints of 9-5/8", 36#, L-80 BTM casing. Landed casing @ 2654'. 12:00 12:30 0.50 CASE P RURD SURFAC Lay down fill up tool, MU cement head. 12:30 14:30 2.00 CASE P CIRC SURFAC Staged pumps up to 10 bpi 550 psi, circ and cond mud, reciprocated casing 20-25'. PJSM. 14:30 16:30 2.00 CEMENT F PUMP SURFAC Pump 40 bbls vis.spacer, 5 bbls of FW, test cement lines to 2500 psi. Pumped 51:: bbls of 10.5 ppg spacer, 310 bbls of 10.7 ppg lead cement and 48 bbls of 15.8 tail cement. Displaced cement with20 bbls of FW and 179 bbls of mud. Bumped Printed: 9/5/20017:12:16 AM Page 2 of 2 Phillips :Alaska, Inc, Daily Drilling Report WELLNAME aDB NUM"£R £VENTCOBE 24HRSPRO6 TMB ~/B376.02, B"SItREPT"O' DAT£ CD2-39 ODR 2,663.0 3.00 3 9/4/2001 OPERATIONS SUMMARY; FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 14:30 16:30 2.00 CEMENT F PUMP SURFAC plugs to 1000 psi, floats held, CIP at 1630 hrs, had 119 bbls of 10.7 pgg cement backto surface. -- "~ 16:30 18:30 2.00 CASE P RURD SURFAC Flush cement from Conductor, RD cement head, LD landing joint. PU jet sub and flush surface stack. 18:30 21:30 3.00 CASE P RURD SURFAC ND Divertor system, install wellhead and test M/M seals to 1000 psi. NU BOP stack. 21:30 00:00 2.50 RIGMNT P RURD SURFAC Slip and cut drilling line, changed out saver sub on top drive to 4", changed out annular preventor on stack. 24 HR SUMMARY: RIHw/BNHO to 2663', circ hole clean, POH, Run and cement 9-5/8" surface casing, shoe @ 2654'. Install wellhead, NU and test BOPE. .......... 'ERSONN'EL ·DATA; :":::. ':': ....... "' ..... cOMpANY . SERVICE ' ' NO..' ' ' Ho'uRS : .... COMpANy: i.': ::: :.":i: i SERVICE '.' NO. HOURS Phillips 1 Artic Catering Inc. 5 Doyon 26 MI Drilling Fluids 4 Baker Inteq 1 FMC 1 Service Personnel (GIS) 4 APE 1 Anadril 3 Dowell 2 ·. . "" '. ' '. ".MATERIALS/CONSUMPTION.'::'.. "..'"' :.. '.:.'..'.':". · . · : .. · . '.' ;':ITEM. · · UNITS..' i' : USAGE : · ON.HAND ..' ::ITEM':'. .... : UNriPs: "USAGE ON' HAND Fuel gals 1,230 -3,145 Water, Potable bbls 110 -335 Water, Drilling bbls 331 -1,451 · .... .: :...:: .. ... :: ::.: : ... . .. suPPoRT. CRAFT. .: ~:.:.':'.... .:..~: . .. . . .:.. .: . .. .:"" · '.'"TYPE: ..'.:. '. NO.' ".'1' '"" '!''REMARKS .... : ' · · TY'PE:i..:"::! .: NO.':!.: ii:.. i ':': ' ' REMARKS"i':- CD2-24 1,198I CD2-39 Printed: 9/5/2001 7:12:16 AM CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-39 Date: 9/5/01 Supervisor: D. Burley Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8", 36#, J-55, BTC CSG Casing Setting Depth: 2,654' TMD 2,370' TVD Hole Depth: 2,673' TMD 2,384' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 19' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 820 psi + 9.6 ppg 0.052 x 2,370' EMW for open hole section = 16.3 ppg Used cement unit Riq pump used NO Pump output = 0.0997 bps Fluid Pumped = 1.0 bbls # 2 Fluid Bled Back = 0.8 bbls 2,800 psi 1,800 psi I I I I I I I I I I I I I t I I I I I I I I I I I I ILI I I I"1--|'-'|"i I I I I I I I I I I I I /- , TIME LINE /~ --e--~EAK-OFF TEST / --~--CASING TEST .~ ..... ";!;::7'"" LOT SHUT IN TIME f ~-'CASING TEST SHUT IN TIME ,~ --"t'-TIME LINE ~~'~:':'~:-;';;::":i::'~r ~iC-":. 2.700 psi 2,600 psi 2,500 psi 2,400 psi 2.300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi ~ 0 psi ' 10 20 30 40 50 60 STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ........................ -(i ........... -~-O-~'i' .................... ',"--'d-~iE~-"',' ..... i:i'~;~-i- .... .................................................................. 4- .............. 4- ........... ~ .... ...................... !-._o. .......... _5_0___p__s.L .................... ±__..2_.s_Lk__s__i _..2_.°___Rs__' .... ....................... _2_._o__ ......... j. f _o_ _ p_s. '_,. ....................... ..4..s.t__k_ _s_. i.. J__0__0___p_sj ___ 3.0 260 psi_ 6stks i 250 psi ................ T ..... ~Z6- ..... r'-'i-6~-~Z-i'~? .................. '§'~;iEi'"T'"J,~/if-~-~i--'~ ................ +,, ..... i:6- ..... h-zi~-i;a-?~ ............... T'-¥~';[i-~--,t'-'~'~-Fa'--t ............... t ............... ,~ ............ -.-:/' ...............t .............. t ............ :---t ~ i 6.0 i 530 ps,. ,~, i 12stks i 860 ps, ,~ ..................... , ¥-6'. ......... , i~f6';;~T~T'~,_ ,.,_ , ............... T"~'~'~k-~--T'-l-;6-J,6'-'~T-i, , p r ............... -~- ............... r ............ -. ................. -r' .............. '~ ............. -.--~ : I 8.0 I 690 ps~; ,7F"6~ = 16 stks ~ 1,230 ps~ ,,t ............... +,' ............... 9.0 ,F .............. 760 s~' -'H.~, ~ .............. 4-, .............. 18 stks ,4-' ................ 1,420 s~, ; ............... -r ......................... P-'"-.--~ ~ ~ ............................ t ..........-P---.--~ [ ............... $ .... J_9..A ........ _s._2.o__p__s.,__., [ .................. ._2_o__.s. Lk.s.__ ,~ _ J_,_s_o..o...p__s_,_- ' ~ , [ 22stks ] 1,780psi ................................................. r ............... -r' .............. ~ ................ I [ I I I , , 24stks , 2,100Ds, .................................................. ,~ ............... 4- .............. 4- .......... .____.__~ [ ............... ± ................ ,.' ~ 26stks ~ 2,350 ps, ~ I I i ............................. i ............. -=--! ,, ,, [ 28 stks ,,._ 2,520 ps[ i ............... -r' ................................. i i i i i ! ! ............... -l- ............... r ................. i i ............... -[-. ............... [. ................ J SHUT IN TIME SHUT IN PRESSURE .......... % .... 4- ............... r ............ ~ .... .... _o_._o___m_j_n___± ............... L___.8__2..O_.p__sj .... · i i · t...j...o_._m_j_n___$ ............... [..._7._~.o__.p__s.,___. 2.0min i I 750 psi i .......... -. .... '~- ............... r ............ -. .... 3.Omen ' I 730 ps[ .... _~:_o__mj_n___., .................... Z_2.o__p_sl___ 6.0 min i 720 psi .......... : .... T ............................ '- .... 7.0 m~n_ 710 psi 8.0 min , 710 ps~ ,. ............... _1_ ............... ~. ................ d , 9.0 min i 710 psi ~ 25.0 min ]. 2,470 psi j , ........... ~---T ............... r ............ '" .... , ........... ~ ................... , ............. :", ..'__J__O__O__DJ_n__'.. . ............... ,,.___.7_l_.O_____si___p _; ___3_o__.o__.m__~.n__-. ....... ......................... l 2,470 ps, I T i ................ ..t. .............. ~ ................ ! i i i SHUT IN TIME SHUT IN PRESSURE '---67::T~i~;'-T .............. T'~'.§~-6-F~i--I ............... d.. .............. .d-.---~ ............ 1.0 min [ 2,500 psi ! 3.0 min i 2,500 psi ; ........... -. .... 1- .............. 1- ............. %--1 4.0 m[n ~ ~ 2,490 ps[ : ............... .d. .............. .&- ................ _._5:.o_.m_j.n_ .................. i..2_,_.49.o_..p..sj..l 6.0 min i 2,490 psi i ---X6-~ii~--' ............... T-~;~-~ti'~i--i ..... · -' ..... ~ .... 1- .............. 4- ............. -,--4 ,....8:.o._.m_:.n_...,, .............. .,, ..2_,__4_s__o___p..s.,.. ,., ._._9_..o__.m_j~ .................. i__2_,__4_8__o__.p..s/_l 10.0 min i 2,480 psi i '--~-~:~'~h--T .............. T'~;~-~'~'a-i ............ -.'"1- .............. 'I' ............. ".''1 .__.2.o.:.o...m.;.n__ .,, .............. ± ._2.,..4Z.0...p._s_,__j NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Modified by Scott Reynolds Casing Detail Well: CD2-39 7" Intermediate Casin.q Date: 9/t 3/01 ARCO Alaska, Inc. Subsidiary of Atlar Subsidiary of Atlantic Richfield Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 35.12 FMC 11" X 7" Hanger 2.22 35.12 Jts 3 to 222 220 Jts 7" 26# L-80 BTCM Csg 9003.73 37.34 7" Davis Lynch Float Collar 1.42 9041.07 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 78.28 9042.49 7" Davis Lynch Float Shoe 1.70 9120.77 9122.47 1 straight blade centralizer per jt #1-#20 1 spiral blade centralizer every other jr. #160-#220 51 Total Use Best-o-Life 2000 pipe dope Remarks: Up Wt = 300k Dn Wt = 170k Block Wt= 80k Supervisor: David Burley PHILLIPS ALASKA INC. Cementing Report Page 1 of 2 Legal Well Name: CD2-39PB1 Common Well Name: CD2-39PB1 Event Name: ROT - DRILLING Report #: 2 Start: 8/29/2001 Spud Date: 8/31/2001 Report Date: 9/13/2001 End: Primary Hole Size: 8.500 (in) TMD Set: 9,122 (ft) Date Set: 9/13/2001 Csg Type: Intermediate Casing/Li Csg Size: 7.000 (in.) cement:Job:TYPe: PrimarY: Squeeze Open HOle: i : Squeeze :Casing :: Hole Size: SQ TMD: SQ Date: SQ Type: (fi) Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Hole Size: Top Set: (fi) BTM set: (fi) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jim Thompson Pipe MoVement: Reciprocating ':.: : .... ·" .." eMovement'.: :.' · · .. .:. .. Pip .. ii .... : .:- Rot Time Start: · Time End: ' RPM: Init Torque: (fi-lb0 Avg Torque: (fi-lb0 Max Torque: (ft-lbf) RecTime Start: · Time End: · SPM: Stroke Length: (fi) Drag Up: (lbs) Drag Down: (lbs) ....... · ' stage NO: 1:::of:'11 :. :.' :' ::.: !~.i .'.'::ii ' · : : ... .. . .' . . · .' .' .. .. · : . · . . . .......' : . :.. .. .. ' . . ... Type: Pre-Flush Volume Excess %: Meas. From: Time Circ Prior To Cementing: 3.25 Mud Circ Rate: 294 (gpm) Mud Circ Press: (psi) Start Mix Cmt: : Start Slurry Displ: : Start Displ: : . End Pumping: : End Pump Date: Top Plug: N Bottom Plug: N Disp Avg Rate: 7.75 (bbl/min) Disp Max Rate: 8.00 (bbl/min) Bump Plug: N Press Prior: 595 (psi) Press Bumped: (psi) Press Held: (min) Float Held: N Returns: Total Mud Lost: (bbl) Cmt Volto Surf: (bbl) Ann Flow After: N Mixing Method: , Density Meas By: MUdlData: ! : .... .!..... ... .. . . : : .. . · :'' .': ..'.:' :: .: :: ... .. ... Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 44 (s/qt) Bottom Hole Circulating Temperature: (°F) Displacement Fluid Type: PV/YP: 11 (cp)/24 (Ib/100fF) Gels 10 sec: 7 (Ib/100fi2) Gels 10 min: 9 (Ib/100ft=) Bottom Hole Static Temperature: (°F) Density: (ppg) Volume: (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (fi) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: To: (fi) (°F) Description: 50 bbls 12.5 ppg Class: Purpose: SPACER Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft*/sk) Mix Water: (bbl) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Foam Job: N Temperature: (°F) Temperature: (°F) Temperature: (°F) Compressive Strength 1' Compressive Strength 2: Time Temp Pressure (°F) (psi) (°F) (psi) Printed: 9/17/2001 10:19:09AM PHILLIPS ALASKA INc. Cementing Report · Page 1 of 2 Legal Well Name: CD2-39PB1 Common Well Name: CD2-39PB1 Event Name: ROT - DRILLING Report #: 2 Start: 8/29/2001 Spud Date: 8/31/2001 Report Date: 9/13/2001 End: 9/20/2001 cement Job Type: Primary .. : Primary : Hole Size: 8.500 (in) TMD Set: 9,122 (ft) Date Set: 9/13/2001 Csg Type: Intermediate Casing/Li Csg Size: 7.000 (in.) sqUeeze:OPen Hole Hole Size: SQTMD: (ft) SQ Date: SQ Type: ; Squeeze CaSing Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: :~: plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jim Thompson Pipe Movement: Reciprocating :. :... ...... . ...... .'.'.. ~ Pi:PeMovement;:.~;.'. :::':..:..:'. :.:.:' :. · . .. . . .' :.... · .. .. ..... :.. ... . : .'.:· .. .. . . ..... : . ...:. : .. ... :. ': ..' ... .. Rot Time Start: · Time End: · RPM: Init Torque: (ft-lbf) Avg Torque: (ft-lbf) Max Torque: (ft-lbf) Rec Time Start: · Time End: · SPM: Stroke Length: 25.0 (ft) Drag Up: (lbs) Drag Down: (lbs) Type: Pre-Flush Volume Excess %: Meas. From: Time Circ Prior To Cementing: 3.25 Mud Circ Rate: 294 (gpm) Mud Circ Press: (psi) Start Mix Cmt: : Start Slurry Displ: : Start Displ: : End Pumping: : End Pump Date: Top Plug: Y Bottom Plug: Y stageNo: .1 :of:: 1'..::. : . . ..' . . . : . .: : :.' ...... DispAvg Rate: 7.75 (bbl/min) Disp Max Rate: 8.00 (bbl/min) Bump Plug: Y Press Prior: 595 (psi) Press Bumped: 1,000 (psi) Press Held: (min) Float Held: Y Returns: Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: Mixing Method: Density Meas By: Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 44 (s/qt) Bottom Hole Circulating Temperature: (°F) Displacement Fluid Type: PV/YP: 11 (cp)/24 (Ib/100ft2) Gels 10 sec: 7 (Ib/100ft2) Gels 10 min: 9 (Ib/100ff2) Bottom Hole Static Temperature: (°F) Density: (ppg) Volume: (bbl) : ..... . ... . . .. . Slurry Data Fluid FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: To: (ft) Description: 50 bbls 12.5 ppg Class: Purpose: SPACER Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Mix Water: (bbl) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Foam Job: N (°F) Temperature: (°F) Temperature: (°F) Temperature: (°F) Compressive Strength 1' Compressive Strength 2: Time Temp Pressure (°F) (psi) (°F) (psi) Printed: 9/24/2001 4:05:43 PM PHILLIPS ALASKA INC.· Cementing Report Page 2 of 2 Legal Well Name: CD2-39PB1 Common Well Name: CD2-39PB1 Event Name: ROT - DRILLING Report #: Start: 2 8/29/2001 Spud Date: 8/31/2001 Report Date: 9/13/2001 End: 9/20/2001 Stage No:l SlUrry No: 2:of 2: Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 9,122.00 (ft)To: 8,375.00 (ft)Cmt Vol: 30.0 (bbl) Water Source: Slurry Vo1:145 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (°F) Temperature: (°F) Temperature: (°F) Temperature: (°F) Density: 15.80 (ppg) Water Vol: (bbl) Class: G Yield: 1.15 (~/sk) Other Vol: 0 Compressive Strength 1' Compressive Strength 2: Time Temp (°F) (°F) Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y .LOg/Survey:EvalUati°n ''~!':i: :.:... ' i. .. . . . Sh e ' Liner::T°PTe t ' : '. o'Test: . ... :::' ' . s~ '.'"' . .: · . : . .. .. .. .. . Pressure: 12.50 (ppge) Liner Lap: Tool: N Pos Test: (ppge) Tool: N Open Hole: 20 (ft) Neg Test: (ppge) Tool: N Hrs Before Test: Hrs Before Test: Cement Found on Tool: N . ... . ''. . :.... .' ..... · . .....;:': Inte:rPretationSummary...:' ;:. .... CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: TempSurvey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: ...... . . · . .Rema ...... : ............ . .... Pumped 20 bbls of ARCO wash, 50 bbls of 12.5 ppg spacer and 30 bbls of 15.8 ppg cement. Displaced with 20 bbls of FW from cementers and 327 bbls of mud at 8 bpm using rig pumps, reciprocated casing 20-25' untill last 30 bbls of displacement. Bumped plugs to 1000 psi, floats held. Maintained full returns throughout, CIP at 1117 hours 09/13/2001. Printed: 9/24/2001 4:05:43 PM Page 1 of 2 Phillips Alaska, Inc, Daily Drilling Report WELL NAME JOB NUMBER EVENT CODE 24 HRS PROG TMD TVD228.07, DFS REPT NO. DATE CD2-39 ODR 9,132.0 12.00 12 9/13/2001 SUPERVISOR RIG NAME & NO. FIELD NAME / OCS NO. AUTH MD DAILY TANG CUM. TANG David Burley Doyon 19 A p ne 12,672.0 0.00 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WlO MUD CUM INTANG W/MUD RIH with aHA # 5. 0.00 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD RIH, test csg, drill out cmt, FIT, Drill 6-1/8" horz. hole. 9/13/2001 275,365 1,961,285 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFL AUTH. 16.20 998D07 LAST SURVEY: DATE TMD INC AZIM LAST CASING NEXT CASING LAST BOP PRES TEST 9/11/2001 9,069.00 82.810 150.670 9.625 (in) (~ 2,654.0 (ft) 7.000 (n) (~ (ft) 9/13/2001 DENSITY(PPg)· 9.60 PP ECg MUD DATA DAILY COST 0.00 CuM·COST·· 0.00 'FY · Pv/YP I GELS: WL/HTHP FCfT.SOL 'OIL/WAT ' '. %sand/MBT . Ph!pM .pflMf Cl Ca' i H2S LIME i ES 48 9/26I 10/12 4.8/9.8 / / /16.2 9.5/ '/ i aHA'NO.. 5 . .' ' . .:.. '.aHA / HOLE:CON'DITIONS:~ : :' ' ...... ' :' :: :.. '.B!T'NO.. 5 · BNA WT'. BELOW,JARs ' . STRING wT:..Up' ' . : ': STRING.WT;IDN ' · : i. :STRING WT:. RoT ".: ':' TORQUE I. uNITS i: . ' ' ' ' !BHALENGTH393.35 'i.:.'. .": :i!T:EM:DEscRiPTiON ..... · · I . :NOJ'TS .i : ':L~ENGTH: · 1.0~D..' . :.I:~Di: :i'.'i cONNSIZE: CONNTYPE BIT 1 0.85 6.125 TURBO-BACK STAB 1 0.85 6.094 MOTOR MACH lX-AKO 1 21.87 6.000 N MSTAB 1 3.70 6.125 2.375 SNM FLEX COLLAR 1 10.51 4.750 2.375 MWD 1 35.22 5.250 2.120 ANNULAR PRESSURE 1 15.20 4.750 2.120 NEUTRON-ADN 1 25.09 5.875 2.500 NM FLEX COLLARS 3 93.11 4.625 2.375 XO 1 1.19 5.250 2.500 HWDP 3 91.99 4.000 2.562 JARS I 32.43 4.750 2.250 HWDP 2 61.34 4.000 2.562 :' :'"'"' : : : i :OpERATIONS'SUMMARY:i.'.' .... .'? ':i i :. i ::i~:::. :..'~ .: · · I:RO..,M: ~.'1;O:: .HOURS' "CODE. TROUBLE :!sUBii ::.PHASE..'. ~ ':' :'..'.'i~::.:'.i~!.':.i:i.'.: .".'i DESCRIpTIoN'~I':.'..'II'. ": . ' ' 00:00 02:00 2.00 CASE P RUNC INTRM1 Run 7" casing to 5108'. 02:00 02:30 0.50 CASE P ClRC INTRM1 Stage pumps up to 7 bpm, 640 psi, Circ BU, cond mud. PUW 190k SOW 142k. 02:30 04:30 2.00 CASE P RUNC INTRM1 Run casing to 7201'. 04:30 05:15 0.75 CASE P ClRC INTRM1 Stage pumps up to 7 bpm, 960 psi, CBU and cond mud. POW 240k SOW 150k. 05:15 07:30 2.25 CASE P RUNC INTRM1 Run casing, MU hanger and landing joint, land casing with shoe @ 9122'. 07:30 08:00 0.50 CASE P RURD INTRM1 LD fill up tool, MU cement head. 08:00 09:45 1.75 CEMENT F CIRC INTRM1 Staged pumps up to 7 bpm, cond mud for cementing, final circ pressure 730 psi, reciprocated casing throughout. PJSM. 09:45 11:30 1.75 CEMENT F PUMP INTRM1 test lines to 3500 psi, pump 20 bbls of chemical wash, 50 bbls of 12.5 ppg spacer and 145 sxs of 15.8 ppg G cement with adds. Displace cement with 20 bbls of FW and 327 bbls of 9.6 ppg mud. Bumped plubs to 1000 psi, floats held. CIP @ 1117 hrs, bleed off to check floats, held. Monitor well, static. 11:30 12:30 1.00 CEMENT F PULD INTRM1 LD cement head and landing joint. 12:30 15:00 2.50 CASE P PTCH INTRM1 Pull thin wear bushing, install and test packoff to 5000 psi, 10 min. 15:00 16:00 1.00 CASE P RURD INTRM1 Change top pipe rams to 3-1/2" x 6", change top drive saver sub to 4" XT. 16:00 22:00 6.00 WELCTL F BOPE INTRM1 Install test plug in wellhead, test BOPE. test Annular to 250/5000 psi. Test Printed: 9/17/2001 9:43:14 AM Page 2 of 2 Phillips Alaska, Inc, Daily Drilling Report CD2-39 ODR 9,132.0 12.00 12 9/13/2001 OPERATIONS: SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 16:00 22:00 6.00 WELCTL F BOPE INTRM1 pipe and blind rams, choke, kill, manifold, Top drive and surface safety valves to 250/5000 psi. Perform Accumulator test, pull test plug and install wear bushing. 22:00 00:00 2.00 DRILL P PULD INTRM1 PU M1XL motor, MWD and LWD, MU BHA #5, install source in HUE/DEN tool. 24 HR SUMMARY: Ran 7" casing, cond mud and cement casing landed with shoe @ 9122'. CIP @ 1117 hrs. RD, install and test packoff to 5000 psi. Test BOPE, MU BHA #5. ' ' PERSONNEL DATA ..... i':COMPANY ' .. SERVICE '..'. · NO.:' HOURS '"iCOMPANY: ''" ':'i:.:i :' SERVICE: : i :i:':" :NO.. HOURS Phillips 1 Anadril 2 Doyon 23 Artic Catering Inc. 5 Baker Inteq 1 MI Drilling Fluids 4 Service Personnel (GIS) 4 Dowell 2 ':'" · .""' · .. '",.. '.. ~MAT,ERIALS:/.c. ONSUMPTION:". ::.i! :.i:'.::..! .": ' .' i.;;:' .:i.':': .'." .'..." 'i:iiTEM:. '. :i: UNITS: . USAGE.:. ONHAND .. ....: :.iTEM::i .: ' .'::.'UNITS ..... ':USAGE. ':: ':..:..ON HAND Fuel gals 678 -1,798 Water, Potable bbls 110 -1,315 Water, Drilling bbls 84 -3,873 . : ...:. . .' : ... "· .: .. SUpPORTC'RAFT::...: '." '.:'~ .':::' :' .'.."ii.:.:.' ' :...... CD2-24' 'CD2_ Printed: 9/17/2001 9:43:14 AM CASING TEST and FORI~AT~ON ~NTEGR]TY TEST Well Name: CD2-39 Date: 9/14/01 Supervisor: D.Burley~ ~ Initial Casing Shoe Test Reason(s) for test: [~ Formation Adequacy for Annular Injection E] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5t8" 38¢ J-55 BTC X 7" 26# L-S0 BTMC 'TOC Casing Setting Depth: 2,854' TMD Hole Depth:8,375' Tb~D 2,370' TVD 6,857' I'VD Mud 'Weight: 9.7 ppg Length of Open Hale Section: 5,721~ ~PHILLIPS Alaska, ~ A Subsidia.W o¢ PHiLLiPS PETROLEUM COMPAHY LEAK-OFF DATA CASING TEST DATA B~INUTES MINUTES FOR FOR .... .~L O._T. ..... BBLS PRESSURE CSG TEST STROKES PRESSURE ................................................ ; ............... 1 ............. 1 ................ ~ ............... T .... Tz ..... F-~"~iT'-i F .............. T ............. -T ................ EZZZZiZiiiZEZF-~-~T-I ~ ............. T .............. t ................ EMW = Leak-off Press. + Mud Weight = 722 pd + 9.7 ppg ~ ~ 3.5 ]-'T{'~'~T'" ~ [ .............. T ............. T ............... 0.052 x %~D o.os2 ~ 2,37o' ~ ............... ~ .... TS-. .... P-T~-;-~T"d, ~ ..... ~ ............... ¢ ............. ¢ .............. , .............................. ~ ........... =---d ~ .............. ~ .............. ~ ............... · ~ 45 ~ 225 psi ~ ~ ! ~ E~W for open ho~e sect~o~ = 15~6 ppg [ ............... I ..... ~:~- ..... L..~.~Z~!.] [ .............. ~ ............. i ................ Pump output = bbls pumped Fluid Pumped = 1%5 bb~s ~ .............. ~ .... ~- .... ['--~-~T- j [ ~ ~ L .............. I .... L:EiiEi~¢~iEE]EZiZZZLRZZZZZiZZZZ] 40O psi TEST ""'~'~CASING TEST LOT SHUT IN TIME CASING TEST SHUT IN TIME ~TtME LINE 7.5 615 psi -----,-,-,,-----,---,-,,-------,' ' · ~ U pS~ ~ ~ SHUT IN TI~E ~ SHUT ~ PRESSURE ............................. P ........... %---d Z.___~:~ .... L_E~_EE_~ 11o ] 600 psi BARRELS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above i SHUT iN Tt~ClE ~ SHUT iN PRESSURE I L. 0m~n ? I 610ps~ ' NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Modified by Scott Reynolds Dote plotted = 17-Sep-200f Reference ~ MWD <0 - 91 Coordlnoto~ ~r~ il~ feet refere~lce slot [Phlll p . Alaska, Inc. ........ ~WJ~ ~.. -~-o~ ..................... -w-;~:-~-~¥~i ............ Field · Alpine Field Location Norfh Slope Alaska inch = 4-00 ti: East (feet) -> · 400 4000 3600 5200 2800 2400 2000 1~ 120~ ~0 4~ 0 4~ B~ 1200 I~ 20~ 24f10 ~ 3~0 56~ 40~ 4400 4O0 -~- 400 § I 8o0 1600 4600 4[~00 440a .I~00 5~00 3200 2a~ 2,4oo 2000 1600 1200 800 400 0 4~ 800 1200 1~0 20~ 2400 zsoo 3200 ~6r~ 4000 4400 4~00 Scale I rnch - 4-00 ft Easf (feel) -> Dote ph3tteU: 17-$ep--2001 Pl~t Eeference W M~ <0 - ~115'>, ~e VeStal Oepth~ ore mfem~e RK8 (~n scale ~ i,ch = los ft East (feet) -> ..~ ...................................... ...... '"~ "'/~ '~" X 1,~ .. ~oo. ~'%..._. 400 , ~ .',/, ~,,~ '~, ',... , ~ ,~ ~ ~1~ c~ .,~ - 1 520 f'["~. "- "'"'- , ~k '"' ~,,.. . ~ ,,/ ....... ~ .......... xxxXX // ~ ~ / . · ' ~ ' 2100" ~ '2100 · ' % · ' ~. ' ~- ~..m--...w~- i w~._l......w_~.w_..~_..w_m~.~_.,w -~---w-~--r ~-,..w~-~ .... ' ~-.-w , ] ,~,-..w-~..~-..~ i , -~-.-~ , , ..... ~ , , .~-.-.~-- .24~o Scale linch = 100 ft 700. , ~oo, ,,..e ............... v . r- ~ eeo -' 1 oo(I - I . 1200- - 1300- . 1400- . 15C~- 16~- .. 17~- . ,408 ,~ ,eoo ,'1oo , . I~o ,IOQO ,11oo .t~oo .{5~o ,170o WELLS W/SURFACE CASING SHOE (+/- 2400' TVD) WITHIN 1/4 MILE CD2-39 Wells I Permit# I Permit Datel Cement ReportI Casin~lTall¥ I No. ofLOTI Sourcewell I Ann. Vol. IStartDatel EndDate CD2-42 301-140 6/1/01 x x 2 CD2-24, CD2-33, CD2-33A 31699 6/1/01 7/16/01 CD2-35' x x 1 NA *CD2-35 was drilled on an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted as for annuluar disposal. Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 24, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drillinq Waste on well CD2-39 Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that CD2-39 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular injection on CD2-39 approximately October 4, 2001. Please find attached form 10-403 and other pertinent information as follows: , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. Form 10-403 Annular Disposal Transmittal Form Pressure Calculations for Annular Disposal Surface Casing Description Surface Casing Cementing Report & Daily Ddlling Report during cement job Casing and Formation Test Integrity Report (LOT at surface casing shoe). Intermediate Casing Description Intermediate Casing Cementing Report & Daily Drilling Report during cement job Formation LOT on 9-5/8" x 7" casing annulus Plan View of Adjacent Wells Details regarding wells within ~ mile radius of surface casing shoe. If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip AIvord at 265-6120. Sin~ely, ~.._..~ Vern dohn~en Drilling Engineer CC: CD2-24 Well File Chip Alvord Scott Reynolds Nancy Lambert Sharon AIIsup-Drake ATO-868 ATO-838 Anadarko ATO-1530 ORlfilNAL Note to File(s) CD2-39 (201-160...301-281) and CD2-14 (201-177...301-288) Colville River Unit (Alpine) Phillips Alaska, Inc Phillips has made application for annular disposal for the subject wells. The pertinent information for the wells has been examined and the following determinations made. --No unusual events were reported while drilling the surface holes of either well. --Surface casing in both wells was cemented to surface. The attachments to both applications note that ~120 bbls of cement was circulated to surface in each case. The net cement remaining in the surface holes was still 80% XS of the calculated hole volume. --Initial leakoff tests were conducted on both wells. It was not possible to pump into either well with slightly more than 16 ppg EMW reached in both cases. --The leak off pressure plot of CD2-39 is offset to the left of the casing pressure plot. The leak off plot does exhibit essentially linear response when pumping begins in contrast to the casing pressure plot. Beyond 6 strokes the casing pressure shows linear response and the slope of the linear section is similar to that of the leak off plot. It appears that some amount of air was in the mud present in the casing or drill pipe during the casing test --The leak off pressure plot of CD2-14 essentially overlays the casing test pressure plot, although there is minor crossover. --No unusual events were reported while drilling either 8-1/2" hole section. --7" casing was successfully run and cemented in each well. --Subsequent injectivity tests were done down the 9-5/8" x 7" annuli of each well. In each case the ultimate pressure was nearly the same as the stabilized pressure observed while conducting the initial leak off test after drillout. The pressure plots are similar to those exhibited on some of the wells on the CD1 pad. Based on examination of the submitted information, I recommend approval of Phillips' requests for the subject wells. MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD2-39PH Date Dispatche 23-Sep-01 Installation/Rig Doyon 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 SEP 2 6 AlE ~ka Oil & Gas Cons Ancl~orag~ Received By~ ~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosel @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ALASKA OIL AN~D GAS CO~SERYATIO$ COMMISSIO$ Vern Johnson Drilling Engineer Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 333 W. 7"" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 RE: Colville River Unit CD2-39 Phillips Alaska, Inc. Permit No: 201-160 Sur. Loc. 1954'FNL, 1516'FEL, Sec. 2, T1 IN, R5E, UM Btmhole Loc. 1347'FNL, 2071' FWL, Sec. 12, T1 iN, R4E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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, subsequent LOT data following setting production casing, and nay CQLs must be submitted to the Commission on form 10-403 prior to the approval of disposal operations. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (CD2-39 PH) and API number (50-103-20387-70) from records, data and logs acquired for well CD2-39. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE~ ~2OMMISSION DATED this ~7 '-t'-~t day of August, 2001 jjc/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Depamnent of Environmental Conse~wation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 52' ,,~'~z, feet Colville River Field 3. Address 6. Property Designation ~/z/oe ,~_. Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 AD~ ^r~,. o~r-~~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.025) 1954' FNL, 1516' FEL, Sec.2, T11N, R4E, UM Colville River Unit Statewide At target (--7" casing point ) 8. Well number Number 802' FNL, 1537' FWL, Sec. 12, T11N, R4E, UM CD2-39 #59-52-180 At total depth 9. Approximate spud date Amount 1347' FSL, 2071' FEL, Sec. 12, T11 N, R4E, UM 08/15/2001 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line CD2-42 12672 MD 2071' FEL Sec 12 feet 28,3' at 500' Feet 2560 7232 TVD feet T11N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 90.1° Maximum surface 2550 psig At total depth (TVD) 3249 at psig 7180' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 78' 37' 37' 115' 105' Pre-installed 12.25" 9.625" 36# J-55 BTC 2663' 37' 37' 2700' 2400' 427 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 9085' 37' 37' 9122' 7233' 132 Sx Class G N/A 3.5" 9.3# L-80 8rd mod 8821' 32' 32' 8853' 7178' 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) RECEIVED true vertical feet ~d~..~ h~ True Vertical depth Casing Structural Length Size Cemented Measu t 1' 2001 Conductor Surface Intermediate Alaska 0il & Gas Cons. Commission Production Liner Anchorage Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat BOP Sketch DiverterSketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /,~,~.~'~ ~_~... ~ { Title Drilling Team Leader Date v Commission Use Only I I dst I Permit Number. _ APl nu, mber Approval ~,,~C_~,[/r-,~---]/r~l see cover letter for .~.O//.-' //~ ~ 50- /~,.,~ -.' ..~___~ ~ ~' ~ Other re_g.uirements Conditions of approval Samples required~ Yes ~/"~--~ Uud¥o~g ~q~ill'ed-''_...... Yes Hydrogen sulfide measures Yes /~o~) Directional survey required /Yb-'~) No Required workin..0.g._pressure for BOPE ~,, 2M 3M 5M 10M 15M 2~050~ ?~[ ~ ,~.>~~ Other: ~~~/~j//~,~~j ~"///~~ / by order of Approved by,/ Commissioner the commission Date .......... Form CD2-39 Drilling Hazards Summary Submil in triplicate CD2-39 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casin.cI Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision None N/A Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, Iow mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of Iow density cement slurries 8-1/2" Hole / 7" Casinc! Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Iow BOPE drills, Keep mud Weight above 10.4 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud weight. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Iow Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-118" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Medium BOPE drills, Keep mud Weight above 9.3 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers ORIGINAL Alpine · CD2-39PH (Pilot Hole) & CD2-39 Procedure . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 16. 17. 18. 19. 20. 21. 22. 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 minimum 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 W' hole to a point +/- 100' TVD below the base of the Alpine Sand. Run electric line logs, and percussion side-wall cores. Set 500 ft cement plug #1 from TD to +/- 8613'. Set 400 ft cement plug #2 from +/- 8613' to +/- 8213'. RIH with drilling assembly. Dress off plug #2. Kick off at +/- 8541' and drill sidetrack to intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement + 500 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to minimum 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 3 %, 9.3 #, 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. ORIGINAL Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-42 will be the closest well to CD2-39, 28.3' at 500' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 25.5' at 513" MD. Drillinq Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpin.q Operations: Incidental fluids developed from drilling operations on well CD2-39 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. The CD2-39 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD2-39 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 below 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"'" ..... 3'6" ' 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 OR/G/N/IL CD2-39 & CD2-39 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 W' Section - 6 1/8" point- 12 ¼" 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 min (drilling) HPHT Fluid Loss at 12 - 14 cc/30 min 160 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 PH 6 % KCL 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 circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of 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% KCl, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and DuaI-FIo starch will be used for viscosity and fluid loss control respectively. ORIGINAL Colville River Field CD2-39PH Pilot Hole- Prior to Sidetracking RKB- GL = 37' Wellhead Updated 07/22/2001 16" Conductor to 114' 9.8 ppg drilling mud in hole Top Alpine Reservoir at 8790' MD / 7183' TVD Pilot Hole TD at 9113' MD / 7437' TVD (+/- 38.23° inc.) Cement Plug : :.:.. ..... .. .: .: . .................. :: ....: : :.. ........ .................... 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2700' MD / 2400' TVD cemented to surface Pluq #2: 400' (8213' MD), 17 pp,q to cover the HRZ when in place (HRZ top at +1.8291') Top of cement plug dressed off to 8541' MD / 6988' TVD (+/- 38.23° inc.) z[j~ Top of Cement Plug #1 at +/- 8613' 500 ft Colville River Field CD2-39 Production Well Completion Plan Cemented to Surface Camco KBUG GLM (2.867" drift ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 3-1/2" 9.3 ppf L-80 EUE-Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Packer Fluid mix: 9.6 pp.q KCI Brine with 2000' TVD diesel cap Tubing Supended with Completion diesel to lowest GLM M__~.D TVD Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBUG GLM (2.867" drift ID) at 5700' TVD for E Dummy with 1" BK-2 Latch Camco KBUG GLM (2.867" drift ID) & 1" Camco DCK-2 Shear Valve Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing (2jt) XO 4-1/2" 12.6 # IBT-mod x 3-1/2" EUE-mod 3-1/2", 9.3 #Iff, EUE-Mod Tubing Camco TRM-4E Tubing Retrievable SCSSV 2191' 2000' End thermal centralizers 2700' 2400' 3-1/2", 9.3 #/ft, EUE-Mod Tubing Camco KBUG GLM (2.867" drift ID) 3973' 3400' 3-1/2", 9.3 #Iff, EUE-Mod Tubing Start thermal centralizers. 5373' 4500' (1 per joint) Camco KBUG GLM (2.867" drift ID) 6901' 5700' 3-1/2", 9.3 #/fi, EUE-Mod Tubing Camco KBUG GLM (2.867" drift ID) 8646' 7065' 3-1/2" tubing joints (2) (R2) HES "X" (2.75" ID) 8726' 7115' 3-1/2" tubing joint (1) (R2) Baker S3 Packer 8767' 7138' 3-1/2" tubing joint (2) (R2) Pinned for casing side shear @ +/- 2000 psi set 2 joints above the X landing nipple HES "XN" (2.635" ID) (@+/- 65°) 8842' 7173' 3-1/2" 10' pup joint : WEG 8853' 7178' S3 Packer at +/- 8767'MD TO0(500, @MD +/-above8367'topM D~,,.~ ~ ................................................... 7~-e-ii-fi~-~ .... '-'~- 12672 MD / Alpine) ..... ~i:',i 7232' TVD Top Alpine at 8867' MD / 7183' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9122' MD / 7233' TVD @ 90.0 deg ORIGi IIAL Colville River Field CD2-39 Production Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' ,I :| 3-1/2" camco TRM-4E SCSSV (2.813" ID) at 2000' TVD-2050' MD - X profile (2.813" OD) -5/8 36 ppf J-55 BTC ~ Surface Casing @ 2700' MD / 2400' TVD cemented to surface (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) Camco KBUG GLM (2.867" Drift ID) - Baker HMC Liner Hanger at 34.00' TVD for - XO to IBT-Mod E Dummy with 1" BK-2 Latch - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe 3-1/2" 9.3 ppf L-80 EUE 8rd. Mod. R2 tubing run with Jet Lube Run'n'Seal p~pe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBUG GLM (2.867" Drift ID) at 5700' TVD for E Dummy with 1" BK-2 Latch (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 Bridge Plu.q Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Camco KBUG GLM (2.867" Drift ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2000 psi set 2 joints above the X landing nipple TOC @ +/- 8367' MD (500' MD above top Alpine) Baker S3 Packer set at +/- 8767' Well TD at 12672' MD / 7232' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 9122' MD / 7233' TVD @ 90.0 CD2-39 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) ~lal) 16 114 / 114 10.9 52 53 9 5/8 2700 / 2400 14.5 1086 1569 7" 9122 / 7233 16.0 3273 2550 N/A 12639 / 7232 16.0 3273 N/A · NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 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)- 0.1ID 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- (0.1x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1} D = [(10.9 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 = ,.- ASP = ... [(FG x 0.052) - 0.1] D [(14.5 x 0.052) - 0.1] x 2400 - 1569 psi OR FPP - (0.1 x D) 3273 - (0.1 x 7233') -. 2550 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3273 - (0.1 x 7233') = 2550 psi Alpine, CD2-39PH Cementinq Requirements CD2-39PH Cement Plug #1: 9113' MD to 8613' MD = 500'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 500'X 0.3941 ft3/ft X 1.15 (15% excess) = 226.6 ft3 => 196 Sx @ 1.16 ft3/sk CD2-39PH Cement Plug ~: 8613' MD to 8213' MD -- 400'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 400' X 0.3941 ft3/ft X 1.15 (15% excess) = 181.3 ft3 => 182 Sx @ 1.00 ft3/sk Alpine, CD2-39 Well Cementing Requirements 9 5/8" Surface Casing run to 2700 MD 1 2400' TVD. Cement from 2700' MD to 2200' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2200' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2200'-1100') X 0.3132 ft3/ft X 1.5 (50% excess) = 516.8 ft3 below permafrost 1100' X 0.3132 ft3/ft X 4 (300% excess) = 2270.1 ft3 above permafrost Total volume = 516.8 + 1378 = 1894.8 ft3 => 427 Sx @ 4.44 ft3/sk System: Tail slurry: 427 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant 500'X 0.3132 ft3/ft X 1.5 (5~0% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft° shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 -> 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 9122 MD 1 7232' TVD Cement from 9122' MD to +/- 8367' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (9122' - 8367')° X 0.1268 ft3/ft X 1.4 (40% excess) = 134.0 ft3 annular volume 80' X 0.2148 fi°Iff = 17.2 ft3 shoe joint volume Total volume = 134.0 + 17.2 = 151.2 ft3 => 132 Sx @ 1.15 ft3/sk System: 132 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk ~ By Weight Of mix Water, all other additives are BWOCement ORiGii AL Creat~ by bmic~el For: V Johnson D~e plotted: 13--Ju1-2001 Plot Reference is CD2--39PB1 Vermont[12. Coord~ncffes ore in feeE reference slot iTrue Vertical Depths are reference RKB (Doyon lg). Phillips i Locafion : North Slope, AlaskaI Strucfure : CD#2 Field : Alpine Field I ..... Point KOP Begin BId/Trn !West Sak EOC [Bose Permafrost C-40 C-30 9 5/8 Casin9 C-20 K-3 K-2 Albi(]n-97 Albian-96 HRZ K-1 LCU Miluveach A Alpine D Pilot Hole Tgt Bose Alpine TD PROFILE MD 250.00 750.00 1001.29 1750.43 1811.77 2445.23 2696.57 2700.59 31 61.25 4536.19 481 6.27 6850.67 7564.87 8290.55 8491.68 8622.81 8738.66 8762.85 8789.59 8924.53 911 2.95 COMMENT DATA Ina Dir TVD North 0.00 11 .t.00 250.00 0.00 10.00 115.00 747.47 -17.01 1 6.55 129.96 992.00 -48.54 38.23 143.75 1653.82 -307.27 38.23 143.75 1702.00 -337.89 58.25 145.75 2198.00 -653.04 38.23 143.75 2397.00 -779.49 58.23 143.75 2400.00 -781.39 38.23 143.75 2762.00 -1011.41 38.23 143.75 3842.00 -1 697.64 38.23 145.75 4062.00 -1837.42 38.23 143.75 5660.00 -2852.79 38.23 143.75 6221.00 -3209.25 38.23 143.75 6791.00 -3571.42 38.23 145.75 6949.00 -3671.82 38.23 143.75 7052.00 -3757.26 38.23 1 43.75 71 43.00 -3795.08 38.23 1 43.75 71 62.00 -3807.16 38.23 143.75 7183.00 -3820.50 58.23 143.75 7289.00 -3887.85 38.23 143.75 7457.00 -3981.89 East 0.00 40.06 87.62 309.25 551.69 562.76 655.47 656.87 825.51 1328.65 1 431.1 4 21 75.59 2456.94 27O2.48 2776.09 2824.07 2866.47 2875.52 2885.10 2954.48 3003.43 V. Sect 0.00 37.72 91.56 431.60 469.56 860.31 1017.08 1019.44 1 304.65 2155.45 2528.76 3587.67 4029.62 4478.67 4605.14 4684.29 4755.98 4770.94 4787.49 4870.99 4987.59 Deg/lO0 0.00 2.00 5.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Cre~ted by bmichael For: V Johnson D~te plotted: 13--Jul-2001 Plot Reference is CD2-39 Version~12. Coordlncrtes are Jn feet reference iTrue Ve~Jcal Depths ore reference EKD (Doyon 19)J Field : Alpine Field Location : North Slope, Alaska Point ..... KOP - Sidetrack Pt LOU Mituveach A Alpine D Alpine Target-EOC-Csg Pt TD -- Csg Pt PROFILE MD Inc 8541.26 38.23 8627.61 45.90 8742.17 56.10 8814.77 62.58 8866.65 67.22 9121.60 90.01 12671.95 90.02 COMMENT DATA Dir TVD North East 143.75 6987.94 -3696.56 2794.25 1 45.68 7052.00 -3743.79 2827.57 147.58 7124.00 -5818.10 2876.58 148.56 7161.00 -5871.08 2909.38 149.19 7185.00 -3911.29 2955.66 151.86 7255.00 -4127.54 3055.61 151.86 7252.00 -7258.34 4729.81 V. Sect 4577.46 4634.85 4725.57 4785.66 4832.56 5080.76 8651.09 Deg/lO0 0.00 9.00 9.00 9.00 9.00 9.00 0.00 Created by bmicho.l ]~OT: ¥ $ohnso=1 Data plo~.[ed: 13-Jul-2Q01 Plot Reference Tree Vertl=ol ~pthl am refemnoe RKB (Doyon 19).~ .................................... Phillips Alaska, Inc. Structure : CD#2 Well: 59PB1 Field : Alpine Field Location : North Slope, Alaska 500 - 1000 1500 2OOO 2500 c' 3000 5500 '~ 4000 (D 4500 I 5ooo V 550O 6O00 65O0 7000 75OO 142.91 AZIMUTH 4787' (TO eH TARGET) *,~*Plane of Proposal**,* RKB Elevation: 52' KOP 2.00 6.00 Begin Bid/Tm 15.78West Sak 19.30 %, 25.03 DLS: 5.00 deg per 100 ft h 30.86 ,., 56.75 EOC Bose Permafrost \ '~,,, C-40 C-30 9 5/8 Cesing C-20 'x 'x, ,,x %. K-3 K-2 x, TANGENT ANGLE ',,, 38.23 DEG ',,, Albian-97 ,\ '~'x Albion-96 K '\,. HRZ Alpi, ne_D. Pilot Hole mgt ~'" .......................................................................................................................... Base Alpin eTD-"~ 0 500 1 DO0 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 6500 7000 7500 Vertical Section (feet) -> Azimuth 142.91 with reference 0.00 N, O.00 E from slol #39 Crated by bmlcheel For: V JohlIsoI1 D~e p~otted: 13~-2~1 p~ Re~ is CD2-3g Vem~n~12. ~n~s ~e in feet re~n~ slot ~g. [T~ Ve~=l ~pths ~ r~er~e RKB (~yan 19).~ ]Phillips Sfrucfure: CD#2 Field : Alpine Field i Alaska, Inc.{ Well : Location : North Slope, Alaskai ! rnluJra( 6000 6200 6400 6600 6800 7200 7400 7600 7800 151.86 AZIMUTH 5001' (TO TARGET) ***Plane of Proposa[*,~ DLS: 9.00 deg per 100 ff. ,=~,~* o~ TARGET/TANGENT ANGLE '-- ~,~ 90.02 DEC '-.. /, - Pilot a~'~ ~[ *~e~ 5~ ~o/ Base Alpine% i i i I i i i i t [ i i i 4-400 4600 4800 5000 5200 5400 5600 i i i i I i i [ i i i i i [ t i , I i i i 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 Verficol Secfion (feet') -> Azimuth 151.8t5 wilh tolerance 0.00 N, 0.00 £ from slot #3~ i , 7800 8000 8200 TD - Csg Pt , , i , , 8400 8600 i 8800 i 9000 llc~.~,~ =y ur~=h~ For: V Johnson] D~te p~ot~e~: 1~-Jul-2001 / PI~ Reference ~ CD2-59~1 Vmm~on~12. m Co~din~. ~m ~n feet mfere~e a~t ~9. ~ Phillips Alaska, Inc. Structure : ¢D#2 Well : 59PB1 Field : Alpine Field Location : North Slope, Alosko 400 800 1200 1600 2O0O 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 Ecsf (feel) -> 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 f i i i i i i t 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 AKOP (',~.Begin BId/Trn L SURFACE LOCATION: '~"%,West Sak 1954' FNL. 1516' FEL "x,~ EOc SEC. 2, T11N, R4E '% Base Permafrost 'X x;~-~o ,x9 5~/8 Cosing \,,C-20 \ 'h \ \ \ 'x, K-3 ~ x,~,,,~ ~ xAk.A, Ibi~n-97 ,\ "'¥~x,Albia n- 9 6 ,,\ HRZ K-I'~ L U · L ~Ju eoch ^lplneAl~i~e~Bi.~j.u se Alpine [ PB1 TD LOCATION: . [ 656' FNL, 1485' FWL '~, SEC. 12, T11 N, R4E Target-EOC-Csg · [ TARGET LOCATION: ] , 802' FNL. 1537' FWL . SEC. 12. T11 N. R4E "~, · \, , , ~ , ,, ' TD LOCATION: 1347' FSL, 2071' FEL SEC. 12, T11N, R4E 'i,,. TD - Csg Pt Dora plot~ld: 16-Jul-2DOt Plot Reference Ig CD2-SgPB1 Vemion~12. '~rue vertk:ol Dep{h~ ore rafgrence RKB (Doyon 19),[ East (feet) -> 4-0 20 0 20 40 60 80 100 120 140 160 180 200 220 24-0 260 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 60 )300 40 60O 80O 1000 1400 20 1700 1800 300 50O 600 20 300 1_17oop 40 ~~r~l O0 $0 BO ~J c' 1 O0 0 U~ ~2o I ¥ 140 ~ ~0 200 220 . 240 - 2~0 1900 2O00 900 1000 2300 1 2400 2500 ' 2'0 ' ' ' 2'0 ' 4'0 ' 6'0 ' 8'0 ' ' ' ...... ~ ' ' ' i ' ' ' 40 0 100 120 140 160 1 O 200 2 0 24-0 East (feet) -> 14-o 16o 200 20 t 260 26O 80 0 E 100 120 I V ORIGINAL Phillips Alaska, Inc. Crsotsd by bm[¢ha.I For: V Johnson Structure : CD#2 Well: 39P81 Dote plotted: 16-Ju[-2001 Plo{ Reference ls C02-39P81 Vemlon~12. I Field : Alpine Field Location : North Slope, Alaska Coo~d~Qtes Qm in feet reference slot ~39. { .............................................................................................................................................................................................................. True Ver[~ool Dep[hs ore re. Ge RKB (Ooyon 200 4OO 600 8OO 1 ooo 1200 140o Q) (-- 1600 0 (/) 18oo I ¥ 2000 2200 2400 2600 2800 3000 3200 East (feet) -> 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3000 ~ 3500 2500 4000 5000 4500 3500 50OO 55O0 4OOO 4500 5000 55OO 6000 % 200 400 800 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 Eost (feet) -> 200 400 600 800 lOOO 1200 1400 0 c- .-I- 1600 ~ --h, --I- 1800 '~' I 2000 2200 2400 2600 2800 3000 3200 ORIGINAL Icroat*~ W ~mla~*~ For: V Johnson Data plowed: 1B-Jul-2001 Pier Reference True VeSSel Phillips Alaska, Inc. Structure : CD#2 Well : 59P81 Field : Alpine Field Locotion : North Slope, Alaska 20OO 2400 2800 5200 3600 4000 ID 4400 -~- 4800 0 5200 v 5600 6OOO 6400 6800 East (feet) -> 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 2000 ""'~,~000 ''".,*..,,~..(~0.~ 2400 ' ~x,5~.5 O0 "~ 2800 5 00~500 ooo [7500 , , '\ 7200 7600 t i i i i i i i i [ i i i i i i i i i i i [ i i i 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 East (feet) -> 4400 4800 5200 I v 5600 6OOO 6400 6800 7200 _ -7600 5600 O£1OItVAL Create~ by bmi¢l~o~l For: V Johnson 1 Dotl plot[ed: 18-dul-2001 / Plo[ EeflmnCe il CD2-59PB1 Vemion~12. / Coe~]~l q~ In f~[ ~e~ce ~ot ~39. / Tree Ve~icql Depthl qr~ce RKB (~yon 19).~ / Phillips Alaska, Inc.] 000330 320 31 TRUE NORTH 350 0 10 340 20 210 30 40 50 60 290 70 280 80 27O 2 0 90 260 100 250 110 240 120 23O 130 220 140 210 150 200 160 190 180 170 Normal Plane Travelling Cylinder- Feet All depths shown are Measured depths on Reference Well ORIG/ VAL Phillips Alaska, Inc. CD#2 39PB1 slot #39 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : CD2-39PB1 Version#12 Our ref : prop4232 License : Date printed : 13-Jul-2001 Date created : 26-0ct-2000 Last revised : 13-Jul-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 17.885,w151 2 27.216 Slot Grid coordinates are N 5974403.278, E 371721.844 Slot local coordinates are 1953.61 S 1514.68 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. CD#2,39PB1 Alpine Field,North Slope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 100.00 0.00 113.00 100.00 200.00 0.00 113.00 200.00 250.00 0.00 113.00 250.00 350.00 2.00 113.00 349.98 450.00 4.00 113.00 449.84 550.00 6.00 113.00 549.45 650.00 8.00 113.00 648.70 750.00 10.00 113.00 747.47 800.00 11.20 117.89 796.61 900.00 13.78 125.03 894.24 1000.00 16.50 129.90 990.77 1001.29 16.53 129.96 992.00 1100.00 19.30 133.42 1085.92 1200.00 22.15 136.06 1179.44 1300.00 25.03 138.13 1271.08 1400.00 27.94 139.79 1360.57 1500.00 30.86 141.16 1447.68 1600.00 33.80 142.31 1532.17 1700.00 36.75 143.30 1613.80 1750.43 38.23 143.75 1653.82 1811.77 38.23 143.75 1702.00 2000.00 38.23 143.75 1849.85 2443.23 38.23 143.75 2198.00 2500.00 38.23 143.75 2242,59 2696.57 38.23 143.75 2397.00 2700.39 38.23 143.75 2400.00 3000.00 38,23 143.75 2635.34 3161.25 38.23 143.75 2762.00 3500.00 38.23 143.75 3028.08 4000.00 38.23 143.75 3420.83 4500.00 38.23 143.75 3813.57 4536.19 38.23 143.75 3842.00 4816.27 38.23 143.75 4062.00 5000.00 38.23 143.75 4206.32 5500.00 38.23 143.75 4599.06 6000.00 38.23 143.75 4991.81 6500.00 38.23 143.75 5384.55 6850.67 38.23 143.75 5660.00 7000.00 38.23 143.75 5777.30 7500.00 38.23 143.75 6170.04 7564.87 38.23 143.75 6221.00 8000.00 38.23 143.75 6562.79 8290.53 38.23 143.75 6791.00 8491.68 38.23 143.75 6949.00 8500.00 38.23 143.75 6955.53 8541.26 38.23 143.75 6987.94 8622.81 38.23 143.75 7052.00 8738.66 38.23 143.75 7143.00 8762.85 38.23 143.75 7162.00 PROPOSAL LISTING Page 1 Your ref : CD2-39PB1 Version#12 Last revised : 13-Jul-2001 RECTANGULAR GRID C O 0 R D S G EO C O 0 R D I N A T E S Easting Northing C O O 0.00N 0.00E 371721.84 5974403.28 n70 20 0.00N 0.00E 371721.84 5974403.28 n70 20 0.00N 0.00E 371721.84 5974403.28 n70 20 0.00N 0.00E 371721.84 5974403.28 n70 20 0.68S 1.61E 371723.44 5974402.57 n70 20 2.73S 6.42E 371728.22 5974400.44 n70 20 6.13S 14.45E 371736.18 5974396.90 n70 20 10.89S 25.66E 371747.32 5974391.95 n70 20 17.01S 40.06E 371761.61 5974385.60 n70 20 20.97S 48.35E 371769.83 5974381.49 n70 20 32.36S 66.69E 371787.98 5974369.80 n70 20 48.30S 87.34E 371808.35 5974353.51 n70 20 48.54S 87.62E 371808.63 5974353.27 n70 20 68.77S 110.24E 371830.90 5974332.66 n70 20 93.71S 135.33E 371855.56 5974307.30 n70 20 123.05S 162.54E 371882.27 5974277.51 n70 20 156.70S 191.80E 371910.95 5974243.37 n70 20 194.58S 223.02E 371941.52 5974204.97 n70 20 236.58S 256.12E 371973.90 5974162.42 n70 20 282.59S 291.00E 372008.01 5974115.84 n70 20 307.27S 309.25E 372025.83 5974090.85 n70 20 337.89S 331.69E 372047.75 5974059.86 n70 20 43!.83S 400.57E 372115.03 5973964.78 n70 20 653.04S 562.76E 372273.44 5973740.87 n70 20 681.38S 583.54E 372293.73 5973712.19 n70 20 779.49S 655.47E 372363.99 5973612.89 n70 20 781.39S 656.87E 372365.36 5973610.96 n70 20 930.93S 766.51E 372472.44 5973459.60 n70 20 1011.41S 825.51E 372530.07 5973378.14 n70 20 1180.48S 949.47E 372651.15 5973207.02 n70 20 1430.03S 1132.44E 372829.85 5972954.43 n70 20 1679.58S 1315.40E 373008.56 5972701.84 n70 20 1697.64S 1328.65E 373021.49 5972683.56 n70 20 1837.42S 1431.14E 373121.60 5972542.07 n70 19 1929.12S 1498.37E 373187.27 5972449.26 n70 19 2178.67S 1681.34E 373365.97 5972196,67 n70 19 2428.22S 1864.30E 373544.68 5971944.09 n70 19 2677.77S 2047.27E 373723.39 5971691.50 n70 19 2852.79S 2175.59E 373848.72 5971514.35 n70 19 2927.32S 2230.23E 373902.09 5971438.91 n70 19 3176.87S 2413.20E 374080.80 5971186.33 n70 19 3209.25S 2436.94E 374103.99 5971153.56 n70 19 3426.42S 2596.17E 374259.51 5970933.74 n70 19 3571.42S 2702.48E 374363.35 5970786.97 n70 19 3671.82S 2776.09E 374435.24 5970685.36 n70 19 3675.97S 2779.13E 374438.21 5970681.16 n70 19 3696.56S 2794.23E 374452.96 5970660.31 n70 19 3737.26S 2824.07E 374482.11 5970619.12 n70 19 3795.08S 2866.47E 374523.51 5970560.59 n70 19 3807.16S 2875.32E 374532.16 5970548.37 n70 19 G R A P H I C RDINATES 17.88 w151 2 27.22 17.88 w151 2 27.22 17.88 w151 2 27.22 17.88 w151 2 27.22 17.88 w151 2 27.17 17.86 w151 2 27.03 17.82 w151 2 26.79 17.78 w151 2 26.47 17.72 w151 2 26.05 17.68 w151 2 25.80 17.57 w151 2 25.27 17.41 w151 2 24.66 17.41 w151 2 24.66 17.21 w151 2 24.00 16.96 w151 2 23.26 16.68 w151 2 22.47 16.34 w151 2 21.61 15.97 w151 2 20.70 15.56 w151 2 19.73 15.11 w151 2 18.72 14.86 w151 2 18.18 14.56 w151 2 17.53 13.64 w151 2 15,51 11.46 w151 2 10.78 11.18 w151 2 10.17 10.22 w151 2 08.07 10.20 w151 2 08.03 08.73 w151 2 04.83 07.94 w151 2 03.10 06.28 wlS1 1 59.48 03.82 w151 1 54.14 01.37 w151 1 48.80 01.19 w151 1 48.41 59.82 w151 1 45.42 58.91 w151 1 43.45 56,46 w151 1 38.11 54.01 w151 1 32.77 51.55 wl51 i 27.43 49.83 w151 1 23.68 49.10 w151 1 22.08 46.64 wl51 1 16.74 46.32 w151 1 16.05 44.19 w151 1 11.40 42.76 w151 1 08.30 41.77 w151 1 06.15 41.73 w151 1 06.06 41.53 wl51 1 05.62 41.13 w151 1 04.75 40.56 w151 1 03.51 40.44 w151 ! 03.26 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #39 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 4987.59 on azimuth 142.97 degrees from wellhead. Total Dogleg for wellpath is 40.01 degrees. Vertical section is from wellhead on azimuth 142.91 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL Phillips Alaska, Inc. CD#2,39PB1 A1Dine Field,North SloDe, Alaska Measured Inclin Azimuth True VertR E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 8789.59 38.23 143.75 7183.00 3820.50S 2885.10E 8924.53 38.23 143.75 7289.00 3887.85S 2934.48E 9000.00 38.23 143.75 7348.28 3925.52S 2962.10E 9112.95 38.23 143.75 7437.00 3981.89S 3003.43E PROPOSAL LISTING Page 2 Your ref : CD2-39PB1 Version#12 Last revised : 13-Jul-2001 GRID C O 0 R D S GEOGRAPHIC Eas~ing Nor~hing C 00 R D I N A T E S 374541.71 5970534.87 n70 19 40.31 w151 1 02.97 374589.95 5970466.69 n70 19 39.65 w151 i 01.53 374616.92 5970428.57 n70 19 39.28 w151 I 00.72 374657.29 5970371.51 n70 19 38.72 wl51 0 59.52 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #39 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 4987.59 on azimuth 142.97 degrees from wellhead. Total Dogleg for wellpath is 40.01 degrees. Vertical section is from wellhead on azimuth 142.91 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL Phillips Alaska, Inc. CD#2,39PB1 Alpine Fie'id,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CD2-39PB1 Versional2 Last revised : 13-Jul-2001 Comments in wellpath ==================== MD TVD Rectangular Coords. Comment 250.00 750.00 1001.29 1750.43 1811.77 2443.23 2696.57 2700.39 3161.25 4536.19 4816.27 6850.67 7564.87 8290.53 8491.68 8622.81 8738.66 8762.85 8789.59 8924.53 9112.95 250.00 747.47 992.00 1653.82 1702.00 2198.00 2397.00 2400 00 2762 00 3842 00 4062 00 5660 00 6221 00 6791 00 6949 00 7052 00 7143 00 7162 00 7183 00 7289.00 7437.00 0.00N 0.00E KOP 17.01S 40.06E Begin Bld/Trn 48.54S 87.62E West Sak 307.27S 309.25E EOC 337.89S 331.69E Base Permafrost 653.04S 562.76E C-40 779.49S 655.47E C-30 781.39S 656.87E 9 5/8" Casing 1011.41S 825.51E C-20 1697.64S 1328.65E K-3 1837.42S 1431.14E K-2 2852.79S 2175.59E Albian-97 3209.25S 2436.94E Albian-96 3571.42S 2702.48E HRZ 3671.82S 2776.09E K-1 3737.26S 2824.07E LCU 3795.08S 2866.47E Miluveach A 3807.16S 2875.32E Alpine D 3820.50S 2885.10E Pilot Hole Tgt 3887.85S 2934.48E Base Alpine 3981.89S 3003.43E TD Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2700.39 2400.00 781.39S 656.87E 9 5/8" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised CD2-39 PiHoleTgtRvsd 374543.000,5970532.000,0.0000 7183.00 3823.34S 2886.44E 13-Jul-2001 ORIGIN, L Phillips Alaska, Inc. CD#2 39PB1 slot #39 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD2-39PB1 Version#12 Our ref : prop4232 License : Date printed : 13-Jul-2001 Date created : 26-0ct-2000 Last revised : 13-Jul-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 17.885,w151 2 27.216 Slot Grid coordinates are N 5974403.278, E 371721.844 Slot local coordinates are 1953.61 S 1514.68 W Projection .type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-11984'>,,35,CD#2 MWD <8715 - 14301'>,,24,CD#2 MWD <0-10054'>,,24PH,CD#2 MWD <0-9507'>,,42PH,CD#2 MWD <8480 - 13138'>,,42,CD#2 MWD w/IFR <0 - ???>,,33,CD~2 PMSS <1805 - 9940'>,,AlplA,Alpine ~1 PMSS <1863-8850'>,,AlplB,Alpine #1 PMSS <1876-9940'>,,AlplA,Alpine #1 PMSS <0-3161'>,,Alpl,Alpine ~1 PMSS <1868-8850'>,,AlplB,Alpine #1 PMSS <0-7170'>,,Neve #1,Neve #1 Closest approach with 3-D Minimum Distance method Last revised Distance 17-May-2001 39.0 26-Jun-2001 149.8 18-Jun-2001 149.8 27-May-2001 28.3 2-Jul-2001 28.3 Il-Jul-2001 60.1 21-Sep-1999 1969.3 21-Sep-1999 2385.7 21-Sep-1999 1969.3 21-Sep-1999 2517.6 21-Sep-1999 2388.2 16-Dec-1999 6670.8 M.D. Diverging from M.D. 287.5 262.5 262 5 500 0 500 0 275 0 4740 0 9113 0 4740 0 5000.0 9113.0 9113.0 287.5 262.5 262.5 500.0 500.0 275.0 4740.0 9113.0 4740.0 5000.0 9113.0 9113.0 Phillips Alaska, Inc. CD~2 39PB1 slot #39 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : CD2-39PB1 Version#12 Our ref : prop4232 License : Date printed : 13-Jul-2001 Date created : 26-0ct-2000 Last revised : 13-Jul-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 17.885,w151 2 27.216 Slot Grid coordinates are N 5974403.278, E 371721.844 Slot local coordinates are 1953.61 S 1514.68 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath CD2-35A Vers. #2,,35A-61,CD#2 PMSS <0-11984'>,,35,CD~2 CD2-50 Vers#7,,50,CD~2 CD2-48 Version#3,,48,CD#2 CD2-25 Ver$ion#3,,25,CD#2 CD2-58 Ver$#3,,58,CD#2 CD2-57 Vers#3,,57,CD#2 CD2-56 Version#2,,56,CD#2 CD2-55 Vers#3,,55,CD#2 CD2-54 Vers#5,,54,CD#2 CD2-53 Vers#5,,53,CD#2 CD2-52 Vers#5,,52,CD#2 CD2-51 Vers~6,,51,CD#2 CD2-49 Version~6,,49,CD#2 CD2-45 Vers~4,,45,CD#2 CD2-44 Vers~4,,44,CD#2 CD2-34 Vers#5,,34,CD#2 CD2-31 Vers#5,,31,CD~2 CD2-29 Version#3,,29,CD#2 CD2-28 Vers#6,,28,CD~2 CD2-27 Vers~6,,27,CD~2 CD2-26 Version#4,,26,CD#2 CD2-23 Vers~8,,23,CD#2 CD2-22 Version#3,,22,CD#2 CD2-21 Version #? (Old 1-18),,21,CD#2 CD2-20 Version#5,,20,CD#2 CD2-19 Vers#4,,19,CD~2 CD2-18 Vers#4,,18,CD~2 CD2-17 Version#3,,17,CD#2 CD2-16 Version~5,,16,CD#2 CD2-15 Version#5,,15,CD#2 CD2-14 Version#3,,14,CD~2 CD2-13 Version#3,,13,CD#2 CD2-12 Version~3,,12,CD#2 CD2-11 Vers~5,,ll,CD~2 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 8-Feb-2001 )1020.5( 17-May-2001 )37.4( 9-Apr-2001 103.3( 9-Apr-2001 )71.3( 9-Apr-2001 138.3( 9-Apr-2001 188.7( 9-Apr-2001 175.71 9-Apr-2001 )91.2( 9-Apr-2001 158.7( 9-Apr-2001 148.3( 9-Apr-2001 138.7( 9-Apr-2001 )37.4( 9-Apr-2001 )69.1( 19-Jun-2001 )95.7( 9-Apr-2001 )30.6( 9-Apr-2001 )21.9( 9-Apr-2001 )48.4( 9-Apr-2001 )78.5( 9-Apr-2001 )98.5( 9-Apr-2001 )108.5( 9-Apr-2001 )118.5 9-Apr-2001 )128.5 14-Mar-2001 )158.5 9-Apr-2001 )168.5 17-Apr-2001 )178 6 14-Mar-2001 )188 5 9-Apr-2001 )198 5 9-Apr-2001 )208 5 9-Apr-2001 )218 5 9-Apr-2001 )228 5 19-Jun-2001 )238 4 9-Apr-2001 )248 5 9-Apr-2001 )258 5 9-Apr-2001 )268 5 9-Apr-2001 )278 6 9113.0 9113.0 312.5 8880.0 562.5 8300.0 988.9 988.9 362.5 362.5 287.5 287.5 500.0 5O0.0 1860.0 1860.0 300.0 300.0 400.0 400.0 287.5 1840.0 1780.0 2280.0 1655.6 1655.6 512.5 8240.0 1366.7 1366.7 1078.1 1078.1 300.0 8420.0 275.0 275.0 275.0 9060.0 275.0 275 0 275.0 7580 0 275.0 8340 0 275.0 275 0 275.0 275 0 262.5 262 5 275.0 275 0 275.0 8840 0 275.0 275 0 275.0 275 0 275.0 275 0 275.0 275 0 275.0 275 0 275.0 275 0 275.0 275 0 262.5 262 5 Ofii iiVAL CD2-10 Version#3,,10,CD#2 CD2-9 Vers#4,,9,CD#2 CD2-8 Vers#4,,8,CD#2 CD2-7 Version#3,,7,CD#2 CD2-6 Vers#4,,6,CD#2 CD2-43 Leg#1 Vers#2,,43,CD#2 CD2-5 Version#5,,5,CD#2 CD2-32 Version#6,,32,CD#2 CD2-30 Vers#5,,30,CD#2 CD2-41 Vers#5,,41,CD#2 CD2-40 Version#3,,40,CD#2 MWD <8715 - 14301'>,,24,CD#2 MWD <0-10054'>,,24PH,CD#2 MWD <0-9507'>,,42PH,CD#2 MWD <8480 - 13138'>,,42,CD#2 CD2-46 Version#5,,46,CD#2 CD2-47 Version#3,,47,CD#2 CD2-38 Version#3,,38,CD#2 33 Version#ll,,33,CD#2 MWD w/IFR <0 - ???>,,33,CD#2 CD2-37PB1 Version#4,,37PB1,CD#2 PMSS <0-7170'>,,Neve #1,Neve #1 PMSS <1805 - 9940'>,,AlplA,Alpine #1 PMSS <1863-8850'>,,AlplB,Alpine #1 PMSS <1876-9940'>,,AlplA,Alpine #1 PMSS <0-3161'>,,Alpl,Alpine #1 PMSS <1868-8850'>,,A1D1B,Alpine #1 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 8-May-2001 19-Jun-2001 19-Jun-2001 8-Jun-200! 9-Apr-2001 9-Apr-2001 26-Jun-2001 18-Jun-2001 27-May-2001 2-Jul-2001 9-Apr-2001 14-Mar-2001 9-Apr-2001 20-Jun-2001 Il-Jul-2001 12-Jul-2001 16-Dec-1999 21-Sep-1999 21-Sep-1999 21-Sep-1999 21-Sep-1999 21-Sep-1999 )288.6( )298.5( )308.6( )318 6 )328 6 )38 4 )338 5 )68 3 )88 5 )14 8 )6.9 )148.3 )148.3 25.5 25.5 56.5 77.8 )8.5 59.1 57.9 18.2 )6421.3 )1796.0( )2198.5( )1796.0( )2423.1( )2201.0( 262.5 275.0 262.5 262.5 262.5 350.0 262.5 275.0 275.0 500.0 375.0 287.5 287.5 512.5 512.5 712.5 425.0 287.5 275.0 325.0 387.5 9113.0 4800.0 9113.0 4800.0 5060.0 9113.0 262.5 275.0 262.5 262.5 262.5 350.0 262.5 275.0 275.0 500 0 375 0 287 5 287 5 512 5 8700 0 8360 0 425 0 287 5 275 0 325 0 387 5 9113 0 4800.0 9113.0 4800.O 5O60.0 9113.0 ORIGINAL Phillips Alaska, Inc. CD~2 39 slot #39 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : CD2-39 Versional2 Our ref : prop4416 License : Date printed : 13-Jul-2001 Date created : 17-Jan-2001 Last revised : 13-Jul-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 17.885,w151 2 27.216 Slot Grid coordinates are N 5974403.278, E 371721.844 Slot local coordinates are 1953.61 8 1514.68 W Projection tyDe: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL Phillips Alaska, Inc. CD#2,39 Alpine Field,North SloDe, Alaska PROPOSAL LISTING Page 1 Your ref : CD2-39 Version#12 Last revised : 13-Jul-2001 Measured Inclin Azimuth True Vert R E C T A N G U L A R G R I D C O O R D S G E 0 Depth Degrees Degrees Depth C O 0 R D I N A T E S Easting Northing C 0 0 0.00 0.00 0.00 0.00 0.00N 0.00E 371721.84 5974403.28 n70 20 100.00 0.00 113.00 100.00 0.00N 0.00E 371721.84 5974403.28 n70 20 200.00 0.00 113.00 200.00 0.00N 0.00E 371721.84 5974403.28 n70 20 250.00 0.00 113.00 250.00 0.00N 0.00E 371721.84 5974403.28 n70 20 350.00 2.00 113.00 349.98 0.68S 1.61E 371723.44 5974402.57 n70 20 450.00 4.00 113.00 449.84 2.73S 6.42E 371728.22 5974400.44 n70 20 550.00 6.00 113.00 549.45 6.13S 14.45E 371736.18 5974396.90 n70 20 650.00 8.00 113.00 648.70 10.89S 25.66E 371747.32 5974391.95 n70 20 750.00 10.00 113.00 747.47 17.01S 40.06E 371761.61 5974385.60 n70 20 800.00 11.20 117.89 796.61 20.97S 48.35E 371769.83 5974381.49 n70 20 900.00 13.78 125.03 894.24 32.36S 66.69E 371787.98 5974369.80 n70 20 1000.00 16.50 129.90 990.77 48.30S 87.34E 371808.35 5974353.51 n70 20 1100.00 19.30 133.42 1085.92 68.77S 110.24E 371830.90 5974332.66 n70 20 1200.00 22.15 136.06 1179.44 93.71S 135.33E 371855.56 5974307.30 n70 20 1300.00 25.03 138.13 1271.08 123.05S 162.54E 371882.27 5974277.51 nT0 20 1400.00 27.94 139.79 1360.57 156.70S 191.80E 371910.95 5974243.37 n70 20 1500.00 30.86 141.16 1447.68 194.58S 223.02E 371941.52 5974204.97 n70 20 1600.00 33.80 142.31 1532.17 236.58S 256.12E 371973.90 5974162.42 n70 20 1700.00 36.75 143.30 1613.80 282.59S 291.00E 372008.01 5974115.84 n70 20 1750.43 38.23 143.75 1653.82 307.27S 309.25E 372025.83 5974090.85 n70 20 2000.00 38.23 143.75 1849.85 431.83S 400.57E 372115.03 5973964.77 n70 20 2500.00 38.23 143.75 2242.59 681.38S 583.54E 372293.73 5973712.19 n70 20 3000.00 38.23 143.75 2635.34 930.93S 766.51E 372472.44 5973459.60 n70 20 3500.00 38.23 143.75 3028.08 1180.48S 949.47E 372651.15 5973207.02 n70 20 4000.00 38.23 143.75 3420.83 1430.03S 1132.44E 372829.86 5972954.43 n70 20 4500.00 38.23 143.75 3813.57 1679.58S 1315.41E 373008.56 5972701.84 n70 20 5000.00 38.23 143.75 4206.32 1929.13S 1498.37E 373187.27 5972449.26 n70 19 5500.00 38.23 143.75 4599.06 2178.68S 1681.34E 373365.98 5972196.67 n70 19 6000.00 38.23 143.75 4991.81 2428.22S 1864.30E 373544.68 5971944.08 n70 19 6500.00 38.23 143.75 5384.55 2677.77S 2047.27E 373723.39 5971691.50 n70 19 7000.00 38.23 143.75 5777.30 2927.32S 2230.24E 373902.10 5971438.91 n70 19 7500.00 38.23 143.75 6170.04 3176.87S 2413.20E 374080.80 5971186.33 n70 19 8000.00 38.23 143.75 6562.79 3426.42S 2596.17E 374259.51 5970933.74 n70 19 8500.00 38.23 143.75 6955.53 3675.97S 2779.14E 374438.22 5970681.15 n70 19 8541.26 38.23 143.75 6987.94 3696.56S 2794.23E 374452.96 5970660.31 n70 19 8600.00 43.44 145.12 7032.36 3727.81S 2816.55E 374474.74 5970628.69 n70 19 8627.61 45.90 145.68 7052.00 3743.79S 2827.57E 374485.49 5970612.53 n70 19 8700.00 52.34 146.94 7099.35 3789.32S 2857.89E 374515.03 5970566.49 n70 19 8742.17 56.10 147.58 7124.00 3818.10S 2876.38E 374533.04 5970537.41 n70 19 8800.00 61.26 148.37 7154.05 3859.97S 2902.56E 374558.51 5970495.10 n70 19 8814.77 62.58 148.56 7161.00 3871.08S 2909.38E 374565.13 5970483.88 n70 19 8866.65 67.22 149.19 7183.00 3911.29S 2933.66E 374588.72 5970443.28 nT0 19 8900.00 70.20 149.57 7195.11 3938.03S 2949.48E 374604.09 5970416.28 n70 19 9000.00 79.14 150.64 7221.52 4021.56S 2997.48E 374650.67 5970331.95 n70 19 9100.00 88.08 151.65 7232.64 4108.51S 3045.39E 374697.10 5970244.21 n70 19 9121.60 90.01 151.86 7233.00 4127.54S 3055.61E 374706.99 5970225.01 n70 19 9121.62 90.02 151.86 7233.00 4127.55S 3055.62E 374707.00 5970225.00 n70 19 9500.00 90.02 151.86 7232.89 4461.22S 3234.05E 374879.75 5969888.39 n70 19 10000.00 90.02 151.86 7232.75 4902.14S 3469.83E 375108.02 5969443.58 n70 19 10500.00 90.02 151.86 7232.61 5343.06S 3705.61E 375336.30 5968998.78 n70 19 GRAPHIC R D I N A T E S 17.88 w151 2 27.22 17.88 w151 2 27.22 17.88 w151 2 27.22 17.88 w151 2 27.22 17.88 w151 2 27.17 17.86 w151 2 27.03 17.82 w151 2 26.79 17.78 wlS1 2 26.47 17.72 w151 2 26.05 17.68 w151 2 25.80 17.57 w151 2 25.27 17.41 w151 2 24.66 17.21 w151 2 24.00 16.96 w151 2 23.26 16.68 w151 2 22.47 16.34 w151 2 21.61 15.97 w151 2 20.70 15.56 wlS1 2 19.73 15.11 w151 2 18.72 14.86 w151 2 18.18 13.64 w151 2 15.51 11.18 w151 2 10.17 08.73 w151 2 04.83 06.28 w151 1 59.48 03.82 w151 1 54.14 01.37 w151 1 48.80 58.91 w151 1 43.45 56.46 w151 1 38.11 54.01 w151 1 32.77 51.55 w151 1 27.43 49.10 w151 1 22.08 46.64 w151 1 16.74 44.19 w151 1 11.40 41.73 w151 1 06.06 41.53 w151 1 05.62 41.22 w151 1 04.97 41.07 w151 i 04.65 40.62 w151 1 03.76 40.33 w151 1 03.22 39.92 w151 1 02.46 39.81 w151 1 02.26 39.42 w151 1 01.55 39.15 w151 1 01.09 38.33 w151 0 59.69 37.48 w151 0 58.29 37.29 w151 0 57.99 37.29 w151 0 57.99 34.01 w151 0 52.79 29.67 w151 0 45.91 25.33 w151 0 39.03 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #39 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 8663.42 on azimuth 146.91 degrees from wellhead. Total Dogleg for wellpath is 92.25 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 151.86 degrees. Grid is alaska - Zons 4. Grid coordinates in FEET and computed using the Clarke - 1866 sDheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD#2,39 Alpine Field,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 11000.00 90.02 151.86 7232.47 5783.97S 3941.39E 11500.00 90.02 151.86 7232.33 6224.89S 4177.17E 12000.00 90.02 151.86 7232.19 6665.81S 4412.95E 12500.00 90.02 151.86 7232.05 7106.72S 4648.73E 12671.93 90.02 151.86 7232.00 7258.34S 4729.81E 12671.95 90.02 151.86 7232.00 7258.35S 4729.82E PROPOSAL LISTING Page 2 Your ref : CD2-39 Version#12 Last revised : 13-Jul-2001 GRID C 0 OR D S GEOGRAPHIC Easting Northing C O 0 R D I N A T E S 375564.57 5968553.98 n70 19 21.00 w151 0 32.15 375792.85 5968109.17 n70 19 16.66 w151 0 25.28 376021.12 5967664.37 n70 19 12.32 w151 0 18.40 376249.40 5967219.57 n70 19 07.99 wl51 0 11.53 376327.89 5967066.62 n70 19 06.49 w151 0 09.16 376327.90 5967066.60 n70 19 06.49 w151 0 09.16 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #39 and TVD from RKB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 8663.42 on azimuth 146.91 degrees from wellhead. Total Dogleg for wellpath is 92.25 degrees. Vertical~ section is from N 0.00 E 0.00 on azimuth 151.86 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD#2,39 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CD2-39 Versional2 Last revised : 13-Jul-2001 Con~nents in wellpath ==================== MD TVD Rectangular Coords. Comment 8541.26 6987.94 3696.56S 2794.23E KOP - Sidetrack Pt . 8627.61 7052.00 3743.79S 2827.57E LCU 8742.17 7124.00 3818.10S 2876.38E Miluveach A 8814.77 7161.00 3871.08S 2909.38E Alpine D 8866.65 7183.00 3911.29S 2933.66E Alpine 9121.60 7233.00 4127.54S 3055.61E Target-EOC-Csg Pt 9121.62 7233.00 4127.55S 3055.62E CD2-39 Heel Rvsd 1-Jun-01 12671.93 7232.00 7258.34S 4729.81E TD - Csg Pt 12671.95 7232.00 7258.35S 4729.82E CD2-39 Toe Rvsd 10-Jul-01 Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2700.39 2400.00 781.39S 656.87E 9 5/8" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised CD2-39 Heel Rvsd 1-J 374707.000,5970225.000,2.0000 7233.00 4127.55S 3055.62E27-Jun-2001 CD2-39 Toe Rvsd 10-J 376327.900,5967066.600,0.0000 7232.00 7258.35S 4729.82E9-Jul-2001 Phillips Alaska, Inc. CD#2 39 slot #39 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD2-39 Version#12 Our ref : prop4416 License : Date printed : 13-Jul-2001 Date created : 17-Jan-2001 Last revised : 13-Jul-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 17.885,w151 2 27.216 Slot Grid coordinates are N 5974403.278, E 371721.844 Slot local coordinates are 1953.61 S 1514.68 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-11984'>,,35,CD#2 MWD <8715 - 14301'>,,24,CD#2 MWD <0-10054'>,,24PH,CD~2 MWD <0-9507'>,,42PH,CD~2 MWD <8480 - 13138'>,,42,CD#2 MWD w/IFR <0 - 777>,,33,CD#2 PMSS <1868-8850'>,,AlplB,Alpine #1 PMSS <1876-9940'>,,AlplA,Alpine #1 PMSS <1863-8850'>,,AlplB,A1Dine ~1 PMSS <0-3161'>,,Alpl,Alpine #1 PMSS <1805 - 9940'>,,AlplA,Alpine ~1 PMSS <0-7170'>,,Neve #1,Neve #1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 17-May-2001 39.0 287.5 287.5 26-Jun-2001 149.8 262.5 262.5 18-Jun-2001 149.8 262.5 262.5 27-May-2001 28.3 500.0 500.0 2-Jul-2001 28.3 500.0 500.0 il-Jul-2001 60.1 275.0 275.0 21-Sep-1999 1304.7 11260.0 11260.0 21-Sep-1999 1969.3 4740.0 4740.0 21-Sep-1999 1303.6 11260.0 11260.0 21-Sep-1999 2517.6 5000.0 5000.0 21-Sep-1999 1969.3 4740.0 4740.0 16-Dec-1999 6200.3 11360.0 11360.0 ORIGINAL Phillips Alaska, Inc. CD~2 39 slot #39 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : CD2-39 Version#12 Our ref : proD4416 License : Date printed : 13-Jul-2001 Date created : 17-Jan-2001 Last revised : 13-Jul-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 i 42.976 Slot location is n70 20 17.885,w151 2 27.216 Slot Grid coordinates are N 5974403.278, E 371721.844 Slot local coordinates are 1953.61 S 1514.68 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEAP3~NCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpa~h Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging 8-Feb-2001 )620.6 CD2-35A Vets. #2,,35A-61,CD#2 PMSS <0-11984'>,,35,CD92 CD2-50 Vers#7,,50,CD#2 CD2-48 Version~3,,48,CD#2 CD2-25 Version#3,,25,CD#2 CD2-58 Vers#3,,58,CD#2 CD2-57 Vers#3,,57,CD#2 CD2-56 Version#2,,56,CD#2 CD2-55 Vers~3,,55,CD~2 CD2-54 Vers#5,,54,CD#2 CD2-53 Vers#5,,53,CD~2 CD2-52 Vers#5,,52,CD~2 CD2-51 Vers~6,,51,CD~2 CD2-49 Version#6,,49,CD#2 CD2-45 Vers~4,,45,CD#2 CD2-44 Vers~4,,44,CD~2 CD2-34 Vers#5,,34,CD~2 CD2-31 Vers#5,,31,CD#2 CD2-29 Version~3,,29,CD#2 CD2-28 Vers#6,,28,CD#2 CD2-27 Vers#6,,27,CD#2 CD2-26 Version#4,,26,CD#2 CD2-23 Vers#8,,23,CD#2 CD2-22 Version#3,,22,CD#2 CD2-21 Version #? (Old 1-18),,21,CD#2 CD2-20 Version#5,,20,CD#2 CD2-19 Vers#4,,19,CD#2 CD2-18 Vers#4,,18,CD#2 CD2-17 Version#3, 17,CD#2 CD2-16 Version#5, 16,CD#2 CD2-15 Version#5, 15,CD#2 CD2-14 VersionS3, 14,CD#2 CD2-13 Version#3, 13,CD#2 CD2-12 Version#3, 12,CD#2 CD2-11 Vers~5,,ll,CD~2 17-May-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 19-Jun-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 14-Mar-2001 9-Apr-2001 17-Apr-2001 14-Mar-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 19-Jun-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-Apr-2001 )37.4 )103.3 )71.3 )138.3 )188.7 )175.7 )91.2 )158.7 )148 3 )0 0 )37 4 )69 1 )95 7 )3O 6 )21 9 )48 4 )78 5 )98 5 )108 5 )118 5 )128 5 )158 5 )168 5 )178 6 )188 5 )198 5 )208 5 )218 5 )228 5 )238 4 )248 5 )258 5 )268 5 )278 6 12320.0 312.5 562.5 988.9 362.5 287.5 500.0 1860.0 300.0 400.0 12672.0 1780.0 1655.6 512.5 1366.7 1077.8 300.0 275.0 275.0 275.0 275.0 275.0 275.0 275.0 262.5 275.0 275.0 275.0 275.0 275.0 275.0 275.0 275.0 275.0 262.5 from M.D. 12320.0 11520.0 8300.0 12400.0 362.5 12240.0 12672.0 12672.0 12672.0 400.0 12672.0 12000.0 10800.0 8240.0 12520.0 12672.0 8946.7 275.0 8872.2 275 0 10400 0 8340 0 275 0 275 0 262 5 275 0 8730 1 275 0 275 0 275 0 275 0 275 0 275 0 275 0 262 5 ORIGINAL CD2-10 Version#3,,10,CD#2 CD2-9 Vers#4,,9,CD#2 CD2-8 Vers#4,,8,CD#2 CD2-7 Version#3,,7,CD#2 CD2-6 Vers#4,,6,CD#2 CD2-43 Leg#l Vers#2,,43,CD#2 CD2-5 Version#5,,5,CD#2 CD2-32 Version#6,,32,CD#2 CD2-30 Vers#5,,30,CD#2 CD2-41 Vers#5,,41,CD#2 CD2-40 Version#3,,40,CD#2 MWD <8715 - 14301'>,,24,CD#2 MWD <0-10054'>,,24PH,CD#2 MWD <0-9507'>,,42PH,CD#2 MWD <8480 - 13138'>,,42,CD#2 CD2-46 Version#5,,46,CD#2 CD2-47 Version#3,,47,CD#2 CD2-38 Version#3,,38,CD#2 33 Version#11,,33,CD#2 MWD w/IFR <0 - ???>,,33,CD#2 CD2-37PB1 Version#4,,37PBl,CD#2 CD2-39PB1 Version#12,,39PB1,CD#2 PMSS <0-7170'>,,Neve #1,Neve #1 PMSS <1876-9940'>,,AlplA,Alpine #1 PMSS <1868-8850'>,,AlplB,Alpine #1 PMSS <1863-8850'>,,AlplB,Alpine #1 PMSS <0-3161'>,,A1pl,A1Dine #1 PMSS <1805 - 9940'>,,AlplA,Alpine #1 9-Apr-2001 9-Apr-2001 9-Apr-2001 9-ADr-2001 9-Apr-2001 8-May-2001 19-Jun-2001 19-Jun-2001 8-Jun-2001 9-Apr-2001 9-Apr-2001 26-Jun-2001 18-Jun-2001 27-May-2001 2-Jul-2001 9-Apr-2001 14-Mar-2001 9-Apr-2001 20-Jun-2001 il-Jul-2001 12-Jul-2001 13-Jul-2001 16-Dec-1999 21-Sep-1999 21-Sep-1999 21-Sep-1999 21-SED-1999 21-Sep-1999 )288.6( 262.5 )298.5( 275.0 )308.6 262.5 )318.6 262.5 )328.6 262.5 )38.4 350.0 )338 5 262.5 )68 3 275.0 )88 5 275.0 )14 8 500.0 )6 9 375.0 )148 3 287.5 )148 3 287.5 )25 5 512.5 25 5 512.5 56.5 712.5 77.8 425 0 )8.5 287 5 59.1 275 0 57.9 325 0 18.2 387 5 )0.0 8926 7 )5810.4 11640.0 )1796.0( 4800.0 )790.4( 11340.0 )789.7( 11320.0 )2423.1( 5060.0 )1796.0( 4800.0 262.5 275.0 262 5 262 5 262 5 350 0 262 5 275 0 275 0 12280 0 10300.0 9040.0 9040.0 8554.3 8706.0 8360.0 12672.0 12160.0 9086.7 325.0 9300.0 8926.7 11640.0 4800.0 11340.0 11320.0 5060.0 4800.0 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 23, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-39 (& CD2-39 PH) Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD2 drilling pad. The intended spud date for this well is August 15, 2001. It is intended that Doyon Rig 19 be used to drill the well. The CD2-39 PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 38.2°. This will allow evaluation of the reservoir interval. It will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 7" intermediate casing, the horizontal section will 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 completion of well work and facilities work that will allow the well to be put on production. Note that CD2-39 was previously permitted in March of 2000 (permit #200-028). This permit was for a different bottom hole location than the current plan, and was cancelled in March, 2001. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed pilot hole schematic. 6. Proposed completion diagram. 7. Proposed completion diagram with open hole isolation options. 8. Pressure information as required by 20 ACC 25.035 (d)(2). 9. CD2-39 Pilot Hole Cementing Requirements. 10. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: , Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). A descr!,ption of the drilling fluids handling system. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. Veto Job Drilling Engineer Attachments CC; CD2-39 Well File / Sharon AIIsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin ATO 153O ATO 868 ATO 848 ATO 844 Anadarko - Houston Kuukpik Corporation e-mail: Tommy_Thompson@anadarko.com RECEivED JUL 8 1 2001 Alaska Oil & Gas Cons. Commission Anchorage ~" AANSMITAL LETTER CHECK L( CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 CHECK WHAT APPLIES STANDARD LETTER "CLUE" DEVELOPMENT ADD-ONS (OPTIONS) MULTI LATERAL (If api number last' two (2) digits are between 60-69) DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL PILOT HOLE~ ANNULAR DISPOSAL ( ) NO ANNULAR.,~,~SPOSAL (~ y~S ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUSJ , ( v/)..y~s + SPACING EXCEPTION The permit is for a new wellbore segment of existing well , Permit No,. ·API No. ~. Production should continue to be reported as a function of the original AP1 number stated above. In accordance with 20 AAC 25.005(0, ali records, data and logs acquired for the' pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested... Annular Disposal. of drilling wastes will not be approved... , : Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conserVation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive~jody\templates American Express' PAY TO THE ORDER OF Cash Advance Draft 157 Issued by InteS~ Payment Systen~ Inc. Enillewoed, Colorado NOT VALID FOR AMOUNT OVER $1000 ,:~O~OO~OO~:~5 ,,,D~?50005~,'D~57 w ,c COM,^.¥ FIELD & POOL , o/z INiT CLAS ' G~ ADMINISTRATION 1. GEOLOGY WELL NAME..~0.~..- ~.~ Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in drilling unit ............ 8. If deviated, is wellbore plat included ............. ... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... PROGRAM: exp dev ~ redrll AREA ~? ~ UNIT# N N N N N N N N N '. N N N N 14. Conductor string.provided .................. . . N 15. Surface casing protects all known USDWs..... ....... N 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 ............ ..... (~.f,.~-~....~._ ~l t~'E3 ~-'%~,.~'~ i~"' 21. If a re-dH,, has a 10-403 for abandonment been approved... 22. Adequate weilbore Separation proposed ....... ~ ...... 23. If diverter required, does it meet regulations ....... . . . 24. Drilling.fluid program schematic & equip list adequate..... .~.N, . BOPEs, do they meet regulation ............. ~ . . "(~-Y, JN ~ _'~"~'~--"-~ ~i 25. 26. BOPE press rating appropriate; test to ~ ~ psig. 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. P~rmit can be issued wlo hydrogen sulfide measures .... '~. Y N .~/ ' 31. Data presented on potential overpressure zones ....... Y N 32. Seismic analysis of shallow gas zones ........ ; . . '.. ..~N ,,~//~-'~/, .. 33. Seabed condition survey (if off-shore)... .......... 34. Contact name/phOne for weekly progress reports [explorato~_/e~nly] Y N serv wellbore sag ann. disposal para req ~ ~o-~'~ONIOFF SHORE ANNULAR DISPOSAL35. With proper cementing records, this plan ~:~:~.~..~'~-.-c.~,~,'--O,W~:::~'~,3,,:.~ ,,~ ,-,/ ~-~~'.~,,- (A) will~ntainwasteinasuitablere~ivingzone~ ..... ... Y N ~~~ ~PP~V.~ ~/P1O ~Pp~'r o~. APPR DATE (B) ~11 not ~ntaminate freshwater; or ~use d~lling waste... Y N to su~a~; ~ '~ ~ ~ ~ 0 1 (C) will not impair mechani~l integH~ 0f the well used for disposal; Y N (D) will not damage producing fo~ation or impair recove~ from a Y N' pool; and ' (E) will not circumvent 20 ~C 25.252 or 20 ~C 25.412. Y N GEOLOGY: ENGINEERING: ' UICIAnnular COMMISSION: Commen~llnstructions: ~~ ~~ WM '~S ~z ./~ ~ -~ ~t~~ "~ O Z O --I c:~nsoffice\wordian~dian~checklist (rev. 111011/00)