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Home My WebLink About199-038Originated: Delivered to:8-Sep-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 CD1-33 50-103-20357-00 908071484 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 26-Aug-22 0 12 CD1-35 50-103-20297-00 908071486 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 28-Aug-22 0 13 CD1-41 50-103-20328-00 908072045 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 29-Aug-22 0 14 CD2-02 50-103-20513-00 907988867 Colville River Multi Finger Caliper Field & Processed 12-Jul-22 0 15PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:CD1-33 PTD:200-212 T36990CD1-35 PTD:199-038 T36991CD1-41 PTD:200-017 T36992CD2-02 PTD:205-109 T36993Electromagnetic Pipe2CD1-3550-103-20297-00908071486Colville RiverXaminer Record (EPX-V)Field & Processed28-Aug-2201Kayla JunkeDigitally signed by Kayla Junke Date: 2022.09.09 09:43:03 -08'00' Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization {done) [] Two-Sided · ~Rescan Needed RESCAN DIGITAL DATA GOlOr items: [] Diskettes, No, rayscale items: [] Other, No/Type (,,~- Poor Quality.O_riginals: [] Other: OVERSIZED (Scannable) r~ Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES: {~) NOTES' ORGANIZED BY; BEVERLY BRENi~~)SHERYL MARIA LOWELL [] Other DATE: /~/ Project Proofing [] By: Staff Proof Date: PROOFED BY: BEVERLY BREN.,~~I~HERYL MARIA LOWELL PAGES: q0 (at the time of scanning) . SCANNED BY: (BEVERLY"Y~BREN VINCENT SHERYL MARIA LOWELL Is/ ReScanned (done) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd STATE OF ALASKA RECEIVED ALASilk AND GAS CONSERVATION COMMIS ON REPORT OF SUNDRY WELL OPERATIONS JAN 0 3 ?D12 1. Operations Performed: Abandon " Re r Plug Perforations ` " Stimulat q g Scale I Repair w ell { r o uh & tiil4 L +,TSt .mission Alter Casing r Pull Tubing J Perforate New Pool f ' Waiver `T ime Extensbn Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended 1 '' h P i n g 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J;r• Exploratory r - 199 -038 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service E . 50 103 20297 - 00 r Qd 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25558 ,, „ CD1 - 9. Field /Pool(s): ,, Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 13450 feet Plugs (measured) None true vertical 7011 feet Junk (measured) 9000 Effective Depth measured 13450 feet Packer (measured) 7222 true vertical 7011 feet (true vertucal) 6944 Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 121 121 SURFACE 2359 9.625 2396 2388 PRODUCTION 8123 7 8158 7055 Perforation depth: Measured depth: open hole 8158' 13450' fj JAN 2, 4 Zb12: True Vertical Depth: 7055-7011' Tubing (size, grade, MD, and TVD) 4.5, L - 80, 7311 MD, 6983 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 7222 MD and 6944 TVD SSSV - CAMCO BAL-0 SSSV NIPPLE @ 1703 MD and 1695 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8158' - 13450' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 341 2308 5488 -- 223 Subsequent to operation 317 2754 6528 -- 252 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development i P Service r Stratigraphic r 15. Well Status after work: • Oil r✓ Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ E SUSP r SPLUG E 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Nelson la. 265 -6859 Printed Name Tim N n Title Staff Production Engineer Signature Phone: 265 -6859 Date 29 Dec. t 1 RSDMS JAN 0 3 1011 / � Form 10-404 Revised 10/2010 Submit Original Only WNS CDI -35 0 ConocoPhillips ' Well Attributes ax Angle & MD TD Alaska. Inc Wel!bore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) conomPhill,ps 501032029700 ALPINE PROD 94.09 7,966.01 13,450.0 ' Comment H2S (ppm) Date Annotation iEnd Date KB-Grd (ft) Rig Release Date ••• Well C08fiq.- C01 -38 12/3/201110x03.39 AM SSSV:WRDP Last WO: 43.61 7/24/2000 Schematic. Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: Rev Reason: RESET WRDP ninam 12/3/2011 Casing Strings ' , Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER. 32 CONDUCTOR 16 15 062 38.0 121.0 121.0 62.58 H WELDED III i, , Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 37.0 2,396.1 2,387.9 36.00 J - 55 BTC - MOD Mg Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 34.7 8,157.9 7,054.6 26.00 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd OPEN HOLE 61/8 6.125 8,158.0 13,450.0 7,011.0 1 Ir Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 1 4 1/2 I 3.958 I 3 2.5 I 7,310.6 I 6,983.1 1 12.60 I L -80 I IBTM I I Completion Details Top Depth I CONDUCTOR. (TVD) Top Inc! Nomi... 38-121 Top (ftKB) (ftKB) ( °) Rem Description Comment ID (In) 32.5 32.5 -0.20 HANGER FMC TUBING HANGER 4.500 1,702.8 1,694.7 1.18 SAFETY VLV CAMCO BAL-0 SSSV NIPPLE 3.812 7,167.6 6,915.5 58.50 NIPPLE HES X NIPPLE 3.813 IND 7,222.0 6,943.7 58.58 PACKER BAKER S-3 PACKER 3.875 II 7,298.4 6,978.0 67.77 NIPPLE HES XN NIPPLE 3.725 WRDP, 1,703 7,309.3 6,982.6 69.03 WLEG BAKER WIRELINE ENTRY GUIDE 3.875 sAPETV1.70 P... Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) in Top Depth (TVD) Top Inc! Top (ftKB) (RKB) ( °) Description Comment Run Date ID (!n) 1,703 1,694.7 1.18 WRDP WRDP -2 (S/N: HSS -243) 11/28/2011 1.250 9,000 7,021.7 92.59 FISH FISH Lower half of fullbore spinner cage for SWS PSP 5/18/2001 logging tools left in well. DEPTH UNKNOWN. Length approx. 24 ". Composition: 4 arms and a bullnose 5/18/2001 Stimulations & Treatments Bottom SURFACE, A ■ Min Top Max Btm Top Depth Depth 37 -2,396 Depth Depth (TVD) (TVD) (RKB) (ftKB) (ftKB) (ftKB) Type Date Comment 8,158.0 13,450.0 7,054.6 7,011.0 C -SAND FRAC 2/25/2008 PLACED 348,6808 16/30 BADGER SAND IN OPEN I HOLE 8 ppa IN FORMATION GAS LIFT. - Notes: General & Safety 3,388 End Date Annotation i i 8/17/2010 NOTE: VIEW SCHEMATIC w /Alaska Schemalc9.0 GAS LIFT os .4 H GS 1 - -- - 1 PACKER 7.2.^.2 NIPPLE 7,298- - WLEG 7.309 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top (ftKB) MB) (1 Make Model (!n) Sory Type Type ON (psi) Run Date Corn... 1 3,388.1 3,379.8 0.19 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 2/24/2008 2 5,204.7 5,196.4 3.08 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 1/4/2009 3 7,107.1 6,883.2 55.94 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 1/5/2009 PRODUCTION, • ' 35-8,158 O • C -SAND FRAC • . FISH, 9,000 , 8,158 OPEN HOLE, 0 8,158 - 13.450 • TD, 13,450 CD1 -35 Scale Inhibition Treatment: 11/27/2011 Initial pressure TBG /IA /OA — 325/1625/875; Facility pumped 50 bbls SW preflush; LRS pumped 6 bbls WAW5206 (248 gal) at 0.41 bpm and facility pumped 54 bbls SW, 315/1575/840; LRS pumped 59 bbls SCW3001WC (2475 gal) at 0.6 bpm and facility pumped 334 bbls of SW, 225/1575/775; LRS pumped 6 bbls WAW5206 (248 gal) at 0.41 bpm and facility pumped 54 bbls SW, 195/1575/775; facility pumped 1579 bbls of SW over - displacement STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ~` Repair w ell Plug Perforations ~ Stimulate ~ Other Alter Casing Pull Tubing ~ Perforate New Pbol Waiver ~' Time Extension Change Approved Program ~~ Operat. Shutdown ~' Perforate Re-enter Sus ended Well P 2. Operator Name: 4. Current Well Status: ~5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory 199-038 3. Address: Stratigraphic Service .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20297-00 7. Property Designation: ~~ 8. Well Name and Number. ADL 25559 ,~ ~ ~ CD1-35 , 9. Field/Pool(s): o Colville River Field /Alpine OiI Pool 10. Present Well Condition Summary: Total Depth measured 13450. feet Plugs (measured) None true vertical 7011 feet Junk (measured) 9000 Effective Depth measured 13450 feet Packer (measured) 7222 true vertical 7011 feet (true verucal) 6944 Casing Length Size MD TVD Burst Collapse CONDUCTOR 85 16 121 121 SURFACE 2360 9.625 2396 2388 PRODUCTION 8124 7 15 ,.. ~ 5 Perforation depth: Measured depth: open hole completion from 8158'-13450' l~Il ~, ~ 2~7~ True Vertical Depth: 7055'-7011' IA,18ska ~i'I & G>~s Cetts~ ~~nmission j~nct-~r~gE Tubing (size, grade, MD, and TVD) 4.5, L-80, 7310 MD, 6983 TVD Packers & SSSV (type, MD, and TVD) PACKER -BAKER 'S-3' PACKER @ 7222 MD and 6944 TVD WRDP - CAMCO WRDP (HPS-372) @ 1702 MD and 1694 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Set attachment Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 642 1937 3124 -- 210 Subsequent to operation 483 1492 3684 -- 202 13. Attachments 14. Well Class after proposed work: \ Copies of Logs and Surveys run Exploratory ~' Develop e t Sence 15. Well Status after work: Oil Gas r° WDSPL Daily Report of Well Opera#ions XXX GSTOR WAG ~"" GASINJ (~` WINJ ~ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact David Neville aC~. 265-6402 Printed Name David Neville Title WNS Engineer '''~~~111 Signature ~ r j Phone: 265-6402 Date ~~~~~~0~ /~ RB~MS .tUt 2 8 q - ~ 2~ l~ Form 10-404 Revised 7/2009 / Submit Original Only CD1-35 Well Events Summary • DATE SUMMARY 7/23/10 Scale squeeze job pumped 8:46 hrs o 15:12 hrs on 7/23/2010. Aqueous Squeeze: 50 bbls SW pre- flush followed by 41 bbls SW /WAW 5206 mixture (187 gal. WAW 5206) at 5 BPM on a vacuum on the tbg; then pumped 252 bbls SW /SCW 3001 WC mixture (34 drums SCW 3001 WC) at 5.8 BPM with tbg on VAC; followed by 41 bbls SW /WAW 5206 mixture (187 gal. WAW 5206) at 5.5 BPM with tbg on VAC; then over displaced with 1521 bbls S/W at 5 BPM with tbg on VAC. SI for 12 hours and returned to production. .- Cbll~~~ll~~t~f5 fi~aska, ir,C. ... _„~_ _, IV~C nfig CDt-3$ ?[f12~ Sd~erial c-Aqi CONDUCTOR, 121 NIPPLE, 1,]02 SAFETY VLV, 1.7oz SURFACE, 2.396 GAS LIFT, 3,388 GAS LIFT, 5.204 GAS LIFT, 7,10] N IPPLE. 7.166 SACKER, 7.222 NIPPLE. ],296 WLEG. ],310 20DUCTION, 8,158 FISH, 9,000 SAND FRAC, 8.158 OPEN HOLE, 13,450 TD, 13,450 WNS ' CD1-35 _~_ -- Well Attributes Max Angle 8 MD ~TD Wellbore APVUWI Field Name Well Status Prod/lnj Type Inc! (°) MD(ftK6) Act Bhn (ftKB) 501032029700 ALPINE (PROD 9409 7,96601 ~ 13450.0 -__ (Comment IH2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date iISSSV~ WRDP (Last WOt I. ~._ 7/24/2000 End Date (Annotation (Depth (ftKB) '~~End Date Annotation ( ( iLast Tag' Il Rev Reason: GLV C/O, set WRDP 1/6/2009 -___ LCasing Strings String OD String ID Set Depth Set Depth (ND) String Wt String ~ Casing Description '~ (in1 (in) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Gratle String TOp Thrd CONDUCTOR '~ 16 15.062 0.0 121.0 121.0 6258 H-40 WELDED SURFACE 9 5!8 8.697 0.0 2,396 0 2,387.8 36.00 J-55 BTC-MOD PRODUCTION 7 6.151 0.0 8,158.0 7,054.6 26.00 L-80 BTCM OPEN HOLE 6 1/8 6.125 8,158.0 13,450.0 7,011.0 Tubing. Strings _ ' String OD String ID Set Depth Set Depth (ND) String Wt String Tubing Description i (in) (in) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Grade String Top ThM __ 12.60 L80 IBTM TUBING i 41/2 3958 0.0 7,370.0 6,982.91 . Other In Hole All Jewel : Tubin Run & Retrievable, Fish, etc. Top Depth i '. (TVD) Top Inc! Top (ftKB) (ftKB) (°) Descr pt on Common[ Run D t ID (in) 1,702.0 1,693.9 1.18 NIPPLE CAMCO BAL-O NIPPLE ~ 7/24/2000 3.812 1,702.0 1,693.9 1.18 SAFETY VLV CAMCO WRDP (HSS-130) 1/5/2009 2.125 3,388.0 3,379.8 0.19 GAS LIFT CAMCOIKBG-2/1/DMY/BK/// Comment: STA 1 2/24/2008 3.938 5,2040 5,795.6 3.06 GAS LIFT CAMCO/KBG-2/1/DMYBK//J Comment STA2 1/4/2009 3.938 7,166.0 6,914.7 58.51 NIPPLE HES 'X'NIPPLE 7/24!2000 7,222.0 6,943.7 58.58 PACKER BAKER'S-3' PACKER 7/24/2000 7298.0 6,977.8 67.72 NIPPLE HES 'XN'NIPPLE 7/24!2000 7,3100 69829 69.11 WLEG BAKER WIRELINE RE-ENTRY GUIDE 7/24/2000 9,000.0 7,021.7 92.59 FISH FISH LOwer half of fullbore spinner cage forSWS PSP 5/18/2001 logging tools left in well. DEP7H UNKNOWN. Length approx. 24". Composition: 4 arms and a bullnose 5/18/2001 rbmulations 8 Treat men[s _ _ ~..; Bottom Min Top Max Btm Top Depth Depth i Depth Depth (ND) (TVD) (ftKB) (ftKB) 'i (ftKB) (t<KB) Type Date Comment 8,158.0 13,450.01 7,054 6 7,011.OiCSAND FRAC 2/25!2008 (PLACED 348,680# 16/30 BADGER SAND I I (HOLE 8 ppa IN FORMATION • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~Q~ ~ ~ ~^~ REPORT OF SUNDRY WELL OPERATIONSgtaska Olt ~ has C€rt~s. t;ommi~= 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate Q Other Af~®rage Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^~ Exploratory ^ 199-038 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20297-00- 7. KB Elevation (ft): 9. Well Name and Number: RKB 3T - CD1-35 8. Property Designation: ~ ~ S 5~ ~ L~ ~ 3 z~ ~ 10. Field/Pool(s): ADL 2 , ALK 4717 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 13450' feet true vertical 7011' - feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse CONDUCTOR 85' 16" 121' 121' SURFACE 2360' 9-5/8" 2396' 2388' PRODUCTION 8124' 7" 8158' 7055' Perforation depth: Measured depth: Open Hole Completion from 8158' - 13450' ' true vertical depth: ° ' ~~~~ Tubing (size, grade, and measured depth) 4.5" L-80 @ 7310' MD Packers &SSSV (type & measured depth) Baker S3 Packer @ 7222' Camco SSSV @ 1702' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volume s 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 2101 3466 2768 1266 244 Subsequent to operation 1532 4221 4619 1509 264 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 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: N/A contact Tim Schneider Printed Name Tim S hneider Title Production Engineer Signature r • Phone 265-6859 Date ~ - ~~( -L~, ~~, o ! ~'~"~+L J Pre b anne L. Haa 263-4470 Form 10-404 Revised 04/2006 ,''~. ~ ,~.....~ ~~.. r~~~ `~ 7sip" Submit Original O lye/ WSR -Well Service Report Page 1 of 1 Well Service Report Well Job Scope CPAI Rep CD1-35 Scale Inhibition Freeborn, Mike llate Daily Work [)nit Number 3/18/2009 44 Initial & TBG/IA/OA start Final 575/1150/700 End Field: ALPINE Pressures: 0/1200/750 2~t hr , Sommary Pump 551 bbls total fluid for Scale Inhibition. STARTTIME OPERATION 12:00 PM Stage 1 - 193 bbls SW w/62 gal WAW-5206 7 bbl/min Stg 2-22 bbls SW w/ 22 gal WAW-5206, 3-148 bbls SW w/935 gal SCW-3001WC, 12:30 PM 4-22 bbls SW w/22ga1 WAW-5206, 148 bbls 7 bbUmin 12:49 PM Stg 5 551 bbls SW 7 bbl/min Fluid Type To From Non- Note Well Well recoverable SEAWATER, WAW- 237 Includes 106 gal WAW5206 5206 SEAWATER 148 Includes 935 gal SCE3001 WC http://akapps.conocophillips.netlalaskawelleventquery/worklog.aspx?ID=BF6B 8A... 3/24/2009 Cc~no~oPf~iffips ~r~.''. ~-~~K~l ~Ilr.:. CONDUCTOR. 121 NIPPLE. 1,]02 SAFETY VLV, '..]02 SURFAC=. lays GAS LIFT, 3,388 GAS LIFT, 5.204 GAS LIFT. 7.107 NIPPLE, ],168 SACKER. 7.222 NIPPLE, ],256 WLEG, 7,310 iODUCTION. 8.' S8 FISH. 9.000 SAND FRAC, 8.158 OPEN FIOLE, 13,450 TD, 13.450 WNS -~~~~~~ Last Tag: Casin Strin s so-itlg Casing Description (in', CONDUCTOR I I J SURFACE PRODUCTION OPEN HOLE E , Tubing Strings String Tubing Description (in', . TUBING 4 Other In Hole A II Je v Top Depth ~ _ _ Too (kK81 (FVD) (ftKBI Top Incl (<I ?.'028 ~ _'.69^.9 ^_,8 1,7020{I 1693.9 7.18 Date LIFT Max Btm '., Top Depth Daplh Depth (ND) (TVDI (ftKel (ftKB) (ftK8) • 'S-3' PACKER J' NIPPLE WIRELINE RE-ENTRY GUIDE >wer half of fullbore spinner cage for SWS PSP tools left in well. DEPTH UNKNOWN. Length 24". Composition: 4 arms antl a bulinose 5/182007 _ Date CommaM RAC 2/25/2008 PLACED 348,G80p 16/30 BADG HOLE 8 ppa IN FORMATION CD1-35 A 6 trn (ftK8) 13,450.0 Rig Release Date 7/24/2000 Entl Date I 1/6/2009 1 /5/2009 2/24/2001 1 /412009 a aaraaav i/vuav iv a~uvvi.~..~ • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, September 15, 2008 10:26 AM To: 'Schneider, Tim S.' Cc: Haas, Jeanne L; Kemner, Maria R Subject: RE: Alpine Scale Squeezes Tim, et al, It is acceptable to perform these operations without submitting a sundry. Be sure that the work is documented by submitting a 404 with appropriate attachments. Call or message with any questions. Tom Maunder, PE AOGCC From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophillips.com] Sent: Monday, September 15, 2008 9:54 AM To: Maunder, Thomas E (DOA) Cc: Haas, Jeanne L; Kemner, Maria R ~~~ ~~~ ~ ~~ Subject: RE: Alpine Scale Squeezes Tom, Per our conversation, here is our preliminary list of we{Is we'd like to perform scale squeezes on. CD2' 34 (201-191) CD1-27 (200-006) GD1-35 (199-038)~+c- CD1-43 (200-106) CD2-50 (202-049) a ~~,., We'll incorporate in our plans to submit 10-404's to provide AOGCC with a summary of the treatments: Thanks Tim From: Schneider, Tim S. Sent: Monday, September 15, 2008 9:2b AM To: 'Maunder, Thomas E (DOA)' Subject: RE: Alpine Scale Squeezes Tom, We will be treating the producers: Rough volumes: Producers with watercut < 25% • 60 bbl inhibitor pill (85% MEG, 15% scale inhibitor) • Flush will be with dead Alpine crude (350-450 bbis) • Will attempt to stay below frac gradient (varies from 0.5-0.6) We need to treat as much of the OH as is possible due some GR logs run in August that indicate the presence of Barium scale within the reservoir. This will require that we stay below the frac gradient. Even distribution is the 9/15/2008 l11rI1t1V IJVGLIV Vl~1.LVVLVJ • • n i t'1 ;„; =~ ,i, ,'y.~iE ¢k! 1 ?~~ vGl' di,; ~iv~;i gv~ , ~. : o ~,.ra= ~ ~ i;y ti i ~ 'v,i ii i=or ~rvu? ~`CvrS ~,1,}!i? ?~IatvrC~1+ > ~~% w~`~i r e~`lace the ~l~~v `/~t i Se~~rjl~t?r ~S ~~~Oel ~S ~~~e 315;"3. a u~vv vav We plan to perform ~5 wells prior to the ice road season to evaluate results and impro1.re upon our procedures for up to 20 treatments during ice road {dependent on I;U time-simops, etc.) The scale inhibitor designs are based on core work done in 2002-2004 to determine a scale inhibitor that would not damage the Alpine reservoir and we were able to identify a product {acrolyte vs. a phosphonate {used at Gi~A)} that doesn't damage the reservoir. Afield test has not been performed, but the scale inhibitor product is currently being used for surface scale management. Hope this helps explain our plans. Let me know if further information is needed. Thanks, Tim From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, September 15, 2008 9:13 AM To: Schneider, Tim S. Subject: RE: Alpine Scale Squeezes Tim, Can you give me an idea of the number of welts, injectors or producers and general procedure? Thanks, Tom Maunder, PE AOGCC From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophillips.com~ Sent: Monday, September 15, 2008 9:12 AM To: Maunder, Thomas E (DOA) Subject: Alpine Scale Squeezes Tom, We are planning to perform scale squeezes at Alpine to control barium sulfate scale deposition. Our goat will be to inject below parting pressure. Is a 10-403 required to perform these? Thanks, Tim 5. Schneider Subsurface Development Staff Production Engineer WNS- Alpine '~ Phone: 907-265-6859 ~ Fax: 907-2656472 ~ Mobile: 907-632-8136 D Email: film,sschneider@conocophillips.com 9/15/2008 r~ ff 1/'~L~ LE~dE.7 ~/'f~f Va7//r-~ g~_ ProActive Diagnostic Services, Inc. • To: State of Alaska - ACGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ~~~~~ S.EP ~ ~ 2008 RE : Cased Hole/Open Hote/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 following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 13Q West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907 245-8952 1) Depth Correlation 23-Aug-08 GD1 ~5 EDE 2) Depth Determination 22 Aug-08 CD1-18 EDE arx-l 20~ ~ ~~~ ~ Signed Print Name: ~n~ 'rte ~ _~~~ H ~ a,, 50-103-20297-00 50.103-20502-00 ~a°iv~~ ~~: 4 '0 ~` Date ~„ E p PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 ' E-MAIL : pdsanchorage(ir)memorvlog.com WEESITE : www.memorylog.com C:\Documents and Settings\OvmetlBesktop\Tcansmit Conovo.doc ~ ~~..~..._~ ..-_,R E~~E I VE D STATE OF ALASKA MAR 2 6 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIQ~~a Oil & Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^/ OtherAnC~1C~@ 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: ConOCOPhilllps Alaska, InC. Development ^~ - Exploratory ^ 199-038 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20297-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB = 3T ., CD1-35 • 8. Property Designation: 10. Field/Pool(s): • ADL 25558 • Colville River Field /Alpine Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 13450' ~' feet true vertical 7011' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' SURF CASING 2396' 9-5/8" 2396' PROD CASING 8158' 7" 8158' OPEN HOLE 5292' 6-114" 13450' fl D {~ ~ HF ~ ~ ~ ~~U~ Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7310' MD. Packers &SSSV (type & measured depth) pkr= BAKER 'S-3' PACKER pkr= 7222' SSSV= NIP SSSV= 1702' 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 2701 2206 891 1314 208 Subsequent to operation 4156 5000 2455 253 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: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 308-032 Contact Printed Name Tim Scll~eider Title: Production Engineer Signature ~~ ~; ? Phone 265-6859 Date L- ~~ ~ ~f:f.D~3 -40 4 ~ 3 ~1 ~ l~ ~ ~ ~ ~` I y~'~(` /~ Sub 'Original Only r~ _ 3~~~,~8' • • CD1-35 Stimulation Results Summary of stimulation job: 2-25-08: Pump frac in one stage: The frac ramped from 2-8 ppa; 2755 bbls slurry, 56 bbls diesel for freeze protect and 87 bbls SW flush. Frac: AIR-40 BPM, AIP-2242 psi, ISIP-1580 psi, 348,680 lbs. 16/30 Badger sand placed. Well test: 3/22/08: 4156 bopd, 2455 bwpd, 5 mmcfpd, 253 WHP • ;. :. i ^F, .t 4. ~ «: ~ A___ ~: F t - ~w.. .,) ! ~~~ t~ t dw _ S ~ ~ "~ AI.ASSA OII, .A.11TD (irg5 COI~T5ERQATIOi1T COMDIISSIOI~T Tim Schneider Production Engineer ConocoPhillips Alaska, Inc. Po Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD1-35 Sundry Number: 308-032 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99507-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~:~~1 FEB t~ ~ 20~ 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. ~;r,.o..,.,_. DATED this .~ day of Encl. tqS --b3~ ~~~ • /jj STATE OF ALASKA ~/ ALASKA OIL AND GAS CONSERVATION COMMISSION P i ~.~~~~~~ JAN 2 9 2008 APPLICATION FOR SUNp DRY APPROV~~a ~~~ ~ Gas Cans. Carnmi,,xiun 20 AAC 25.200 AnwMnreney 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate 0 Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Weit ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development Q Exploratory ^ 199-038 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20297-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO Q CD1-35 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25558 RKB = 37' Colville River Field /Alpine Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13450' 7011' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' SURF CASING 2396' 9-5/8" 2396' PROD CASING 8158' 7" $158' OPEN HOLE 5292' 6-1/4" 13450' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 7310' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER'S-3' PACKER pkr- 7222' SSSV= NIP SSSV= 1702' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 15, 2008 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider Printed Name Tim S n 'der Title: Production Engineer Signature ``A ~ ~,, Phone 265-6859 Date j' ~~-~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representat ive may witness ~0 Q~ ~. Plug Integrity ^ BOP Test ^ Mechanical Integrity Test [] Location Clearance ^ Other: y y~ tt yy}}yy ~ ie~~' 9.z. ~ _+~ l~ ti L.UUU Subsequent Form Required: , `O~ APPROVED BY ~ Approved by: C M E D T E COMMISSION Date: Form 10-403 Revised 06/2006 ~ ~/ ~ ~ IV H L Submit in Duplicate • Overview: CD1-35: A hydraulic fracture treatment will be performed in the openhole horizontal section to establish communication vertically and longitudinally through the Alpine "C" sand. This will increase the wells production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU 8 clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment} °'"""" 2. Rig up Schlumberger equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 100 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 40 BPM with a maximum pressure of 6000 psi, add breaker as per lab results. Maintain 2000-3000 psi on the IA during the 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 stick diesel. . . ~ ConocoPhillips Alaska j P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~ 'L-f. March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCAN,NED APR 1 () 2007 lG\9-0Ô~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 ?!16!200? Alpine Field March 31,2007 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Permit to Drill 1990380 Well Name/No. COLVILLE RIV UNIT CD1-35 Operator PHILLIPS ALASKA INC. APl No. 50-103-20297-00-00 MD 13450 ']'VD 7011 Completion Dat 7/24/2000''~ Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N__~o Sample N__9o Directional Survey N._9o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Me ' ' Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments 2346 8167 Open 6/10/1999 09211 C,23'46-8167 2346 8167 Open 11/23/1999 09387 ~'2'3:~6-8167 2346 13450 Open 9/15/2000 09714~6-13450 ~A~DT~/CDR-MD 2/5 FINAL 2396 13405 OH 9/15/2000 2396-13405 5/8/99 THRU C'~CDR-'I-VD 2/5 FINAL 2396 7000 OH 9/15/2000 2396-7000 5/8/99 THRU 9714~''' 1-4 OH 9/15/2000 9714~SSCHLUM IMP- GPJCDPJADN SRVY RPT 0 13450 OH 8/10/2000 SCHLUM 0-13450. .~PT 115 8095 OH 5/26/1999 SCHLUM 115-8095.69 ~-'~DR-TVD 2 FINAL 2400 7065 OH 6/10/1999 2400-7065 ,~D~-MD 2 FINAL 2396 8130 OH 6/10/1999 2396-8130 (,~:I'VD 2 FINAL 6100 7060 OH 6/10/1999 6100-7060 ~MD 2 FINAL 6197 8076 OH 6/10/1999 6197-8076 9211 1,2 OH 6/10/1999 921 lt~SCHLUM CDP,/ADN/GR ~ 2/5 FINAL 6100 7050 OH 11/23/1999 6100-7050 ~"_~D 2/5 FINAL 6197 8076 OH 11/23/1999 6197-8076 9387 2 OH 11/23/1999 9387~SCHLUM CDR/ADN-PDC REV 2 Production Profile 1,2,5 FINAL 7200 10330 CH 6/15/2001 7200-10330 BL, Sepia Well Cores/Samples Information: Name Interval Dataset Start Stop Sent Received Number Comments Permitto Drill 1990380 MD 13450 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. COLVILLE RIV UNIT CD1-35 Operator PHILLIPS ALASKA INC. 7011 Completion Dat 7/24/2000 Completion Statu 1-OIL APl No. 50-103-20297-00-00 Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis Daily History Received? Formation Tops Comments: Compliance Reviewed By: Date: · Ms. Wendy Mahan AOGCC Second Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the second quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-19 33933 100 0 34033 Open, Freeze Protected 1C-25 34836 100 0 34936 Open, Freeze Protected 7- CD1-40 32777 100 0 32877 Open, Freeze Protected 1C-23 34470 100 0 34570 Open, Freeze Protected ~-' 1C-18 0 0 0 0 Open, Freeze Protected CD1-35 217 100 0 317 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Doug Chester Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _X Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 37' feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__ Colville River Unit 4. Location of well at surface 8. Well number 464' FNL, 2944' FEL, Sec. 5, T11 N, R5E, UM (asp's 385760, 5975665) CD1-35 At top of productive interval 9. Permit number / approval number 278' FSL, 1605' FWL, SEC. 32, T12N, R5E, UM (asp's 385037, 5976419) 199-038 At effective depth 10. APl number 50-103-20297 At total depth 11. Field / Pool 4910' FNL, 1332' FEL, Sec. 30, T12N, R5E, UM (asp's 382165, 5981835) Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured 13450 feet Plugs (measured) true vertical 7011 feet Effective depth: measured 13450 feet Junk (measured) true vertical 7011 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 10 cu yds Portland Type 3 121' 121' SURF CASING 2396' 9-5/8" 744 Sx AS III, 230 Sx Class G 2396' 2388' PROD CASING 8158' 7" 215 Sx c~ass G 8158' 7054' OPEN HOLE 6.125" 8158'-13450' OPEN HOLE Perforation depth: measured None ~ECE/~ED true vertical None "~ ~ ~' Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 Tbg @ 7310' MD. Packers & SSSV (type & measured depth) BAKER 'S-3' PACKER @ 7222' MD. CAMCO BAL-O @ 1702' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: May 1,2001 16. If proposal was verbally approved Oil __X Gas __ Suspended _ Name of approver Date approved Service 17. I hereby certihj that the loregoing is true and correct to the best el my knowledge. Questions? Call Michael Erwin @ 265-1478. Signe~~.,~ ~ '~ ~ Title: Alpine Production Engineer Date Michael Erwin Prepared bi/Sharon Al/sup-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. / Plug integrity_ BOP Test__ Location clearance --~tI ~ Mechanical Integrity Test__ Subsequent form required 10- 'v--~ ~ ORIGINAL SIGNED ~',. ,,~ Approved b7 order of the Commission D Taylor Re~_m~,,n, Commissioner Date ~._.. ' 0 / Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Stimulation Procedure Colville River Field CD1-35 Conversion operations will commence following ice road construction on or about April 1, 2001. Completion is expected on or about April 15, 2001. This procedure is designed to clean out and stimulate a newly drilled producer. The goal is to remove filtercake, drilled solids, and polymer from the openhole completion. 1. RU coil tubing unit. GIH with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with diesel. 2. Spot +/-250 bbl. of DS 8% formic acid mixed in a 6% KCL base fluid in the openhole interval. --------,_-._~~ 3. POOH and RD coil tubing. 4. Allow the breaker to soak for 4-6 hours. 5. Return the well to production. CTD BOP Detail ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol Injection ~ I I I onnect ' I I I I I 1 Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Hydril Model B HCR Flanged Fire Resistant Kelly Hose to Dual Choke Manifold I 2 3/8" Slips 2 3/8" Pipes Kill line check valve Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpip manifold 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic 2' Side outlets I Blind/Shear I 2" Combi Pipe/Slip Single or Double Manual Master Valves xo spool 3 1/8' x 71/6' ~ or as necessary I ! ) Spool 2 flanged gate valves 7" Annulus 9 5/8" Annulus MEMORANDUM State of Alaska THRU: Tom Maunder, P. I. Supervisor Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ~?~ \.~- Commissioner ~-~ ~\ DATE: FROM: Chuck Scheve; SUBJECT: Petroleum Inspector March 30, 2001 Safety Valve Tests Colville River Unit CD1 Pad Friday, March .30, 2001: I traveled to the Phillips Alaska's Alpine Field and witnessed a portion of the safety valve system tests on CD1. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 8 wells and 24 components with no failures observed. The Rosemount Iow-pressure switches (located in the manifold building) performed very well tripping at the set point on all wells tested. The surface safety valves on these wells operate very slowly ~probably due to ~being exposed to the elements and the length of the control line from the hyd panel to the wellhead. Gary Saltenreick conducted the testing today he demonstrated a good working knowledge of the system and was a pleasure to work with. summa,fy: I Witnessed a portion of the semi-annual SVS testing at the CD1 Pad in the Alpine Field. CRU CD1 Pad, 8 wells, 24 components, 0 failures Attachment: SVS CRU CD1 Pad 3-30-01 CS .... X, Unclassified Confidential (Unclassified if doc. Removed) SVS CRU CD1 3-30-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: p.b. illips ,. Operator Rep: Jack Kralick AOGCC Rep:,, Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: .Alp'm. e/CRU/CD 1 Separator psi: LPS .... ,143,, Date: 3/30/01 HPS I II I i I i iii ! i ii ii Il .... i ill iii . ! i I I _1 ii LI ~ t.ii ~')! i~:~V:,~-: ~ :; ;.: :ReteSt ~ ..:i Well:~ ,Ype~:~'::~ Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE ..... ., , , ,. .... .......... . , ,,,, ........... CD1-01 1990460 , , , t~ , ,, , , , ,, ,., , ~ , , , , r , ,, ,. , , ,,, . , , ~ ,, CD 1-06 2000830 " ,r_ . , ~ ....... ,, , ,. ,,. , , ~ , , , ,, . ~ , , ~ , ~ ' ' ' ' CD 1-09 2000710 , i , ,, , , , lj , . ,, , , , , , , ! , , t,~, , c01. 3 990s20 ~,,~ , ,~ ,I ~ ,, , ,.. , , , , ~,~ i , ~1, ~,~, ~, , ,. ,, , , ! . ~ ,, CDI-16 19909401 Cm; 75oo :iso 'i: 3 ..... .... P' p" P .......... oIL iSD1-52A" '200i1001 143'I' 'i'0i3' '100'"P ' 'P P..... 0iL~ cD1-24 'i990260"' 143 "'100:' 100 p "P "P' ....... oil , , ~ , ~, ,,I , , J ! , , , , ,, ~ ' ' '" ' ' ' ' CD1..5~ "2000080 143 lOO lOO p' P p OIL CD1-27 '20000601 ' .......... , ,J . . t. ~, , ~,,,i, , , , ., , ~, ,~ , ~ ~ , , ~ "' '' ' ''~ CD1-30 2001320 cD1'.52 "i99'104o ............................... , . , ~, , . . , .,,,~ [,,,, ,, , , , , ~ ,, , , . ,,,,,,, ~,, ,., ,, ,, , ~,~ ~ CD1-34 2000430 i , t , , , , , , ,, ,, ~ ~ , , . , , , ,, , ,' " ~~~ ............ ,O,,'!£': .i~i~!=!~ 1990380 143 100 .10,0 P P P 2000030 c'DI'40' ' 1990440 ..................... , ,, ~ , , . , , , , , CD1-41 2000170 , ~ , i . [, , , , ~. , , ,, CD1-43 2001060 · , .,, .~ i ~ ~ , , , , , , , , ~ '~ ~ ! ' ' ' ' CD1-44 200055'0 Ci~1-o4 2001170! ' 1;43 "1o0 100 ' P P ' P .... OiL' , _ ,, , , , , , , ~ , ~ ,, . . , cDI-10 ~2001;710 '143 "100 100 P P P OIL cDl"-2'~ ....... 143 '100 "100 ' P' P ' P ..... 0IL, · · , , ,~, ,, t . , _. Wells: --_ . 8 Components: .. 24 Failures: O. Failure Rate: 0.00% Remarks: RJF 1/16/01 Page 1 ofl 010330-SVS CRU CD1-CS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classilicatlon of Service Well Oil [~ Gas D Suspended [~ Abandoned D Service D 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 199-38 3. Address l.~,,,a~l~,~'~,~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ¥~ 50-103-20297-00 4. Location of well at surface ~.p~-~~ 9. Unit or Lease Name 466' FNL, 2335' FWL, Sec. 5, T11N, R5E, UM (ASP: 385760, 5975665) i ;' ~' ' : ' Colville River Unit At Top Producing Interval ! : -': ' 10. Well Number 278' FSL, 1605' FWL, Sec 32, T12N, R5E, UM (ASP: 385037, 5976419) i-"/'~/'".~'~ i CD1-35 ~ . At Total Depth ! .... '" ~,~: } 11. Field and Pool 368' FSL, 1331' FEL, Sec. 30, T12N, R5E, UM (ASP: 382165, 5981835) Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. Alpine Oil Pool 37' RKB feetJ ADL 25558 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. J 15. Water Depth, if of/shore 16. No. of Completions May 6, 1999 July 22, 2000 July 24, 2000J N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey J20. Depth where SSSV set 21. Thickness et Permafrost 13450' MD /7011' TVD 13450' MD /7011' TVD YES ['~ No I 1 703' feet MD 860' 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 121' 42" lO cu yds Portland Type3 ~'.:? F 9.625" 36# J-55 Surface 2396' 12.25" 744 sx AS III, 230 sx Class G 7" 26# L-80 Surface 8158' 8.5" 215 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 7310' 7222' 6.125" open hole completion from 8158'-13450' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST f'", !'3 I r~ I t,, I /t I Date First Production Method of Operation (Flowing, gas lift, etc.) U I~ I D I I~J/~ L Waiting on Facility Start-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Pedod > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A ion Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. Alpine D Base Alpine NAME GEOLOGIC MARKERS MEAS. DEPTH 7308' 7788' TRUE VERT. DEPTH 6983' 7061' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 Signed ~>.~ ~. ~'~'~ Title Ddllin,q Team Leader Date ___?i r~ .~' G. C. Alvord Prepared by Sharon Al/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 Date: 08/10/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CD1-35 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: ALPINE SPUD:05/06/99 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20297-00 05/05/99 (D1) TD/TVD: 121/121 SUPV: MW: 8.7 VISC: 50 PV/YP: 0/ 0 APIWL: 0.0 ( 121) MIX SPUD MUD, LAY INJECTION LINE TO CDI-19 Safety meeting. Move rig from CD1-24 to CD1-35. Accept rig @ 2130 hrs. 5/5/99. Test diverter. UPCOMING OPERATIONS:SPUD CD1-35 05/06/99 (D2) MW: 9.4 VISC: 120 PV/YP: 11/51 APIWL: 14.0 TD/TVD: 1537/1528 (1416) DRILLING @ 2175 SUPV: Function test diverter. Pre-spud meeting. Drill 12.25" hole from 121' to 1537' UPCOMING OPERATIONS:RUN 9 5/8" SURFACE CSG 05/07/99 (D3) MW: 9.5 VISC: 145 PV/YP: 17/51 APIWL: 10.0 TD/TVD: 2406/2397 ( 869) CEMENTING SUPV:MIKE WHITELEY Drill from 1537' to 2406'. Circ and condition mud and hole to run 9-5/8" surface casing. Run 9-5/8" casing. UPCOMING OPERATIONS:NU / DRILL OUT 05/08/99 (D4) MW: 9.6 VISC: 40 PV/YP: 8/14 APIWL: 9.0 TD/TVD: 2406/2397' ( 0) DRILLING AHEAD AT 2,492' SUPV:MIKE WHITELEY Circ and condition mud and hole for cement job. Pump cement job. Test BOPE to 250/2500 psi. Drill safety meeting. Clean out plugs, float collar, cement to 2385' UPCOMING OPERATIONS:DRILL / SHORT TRIP 05/09/99 (D5) MW: 9.6 VISC: 42 PV/YP: 9/27 TD/TVD: 4487/4479 (2081) DRILLING AHEAD AT 5,000' SUPV:MIKE WHITELEY APIWL: 6.0 Drill shoe and 20' new hole to 2426' Performed FIT to 16.0 EMW. Unable to pump in at 800 psi. Drill to 2446' Perform FIT test to 16.3 ppg EMW. Unable to pump in at 850 psi. Drill from 2446' to 2476' Performed LOT, EMW=13.5 ppg. Drill from 2476'-4487' UPCOMING OPERATIONS:DRILLING SEn ., ........ 0.;~:, ,;l .... OP, Alaska, Oi! & O~; r'"""~'~ ..... Date: 08/10/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 05/10/99 (D6) MW: 9.6 VISC: 44 PV/YP: 9/29 TD/TVD: 6115/6070 (1628) DRILLING AHEAD AT 6,480' SUPV:MIKE WHITELEY Drill from 4487'-6115' UPCOMING OPERATIONS:DRILL / TRIP FOR BHA APIWL: 4.4 05/11/99 (D7) MW: 9.7 VISC: 47 PV/YP: 8/21 APIWL: 4.8 TD/TVD: 6805/6663 ( 690) DRILLING AHEAD AT 7,085' SUPV:MIKE WHITELEY Drill from 6115' to 6738'. Pump sweep around. Circ hole clean. MAD pass from 6289'-6664' Wash to bottom. Drill from 6738'-6805' UPCOMING OPERATIONS:DRILL 05/12/99 (D8) MW: 9.7 VISC: 45 PV/YP: 11/31 APIWL: 4.6 TD/TVD: 7830/7066 (1025) DRLG AT 7978' SUPV:LUTRICK / ROBERTSON Drilling from 6805' to 7830' UPCOMING OPERATIONS:TD AT 8168', WIPERTRIP, RUN CSG 05/13/99 (D9) MW: 9.7 VISC: 45 PV/YP: 11/27 APIWL: 4.5 TD/TVD: 8168/7054 (338) RIH W/ CSG AT 6500' SUPV:LUTRICK / ROBERTSON Drilling from 7830' to 8168'. PJSM. Run 7" casing. UPCOMING OPERATIONS:CEMENT CSG 05/14/99 (D10) TD/TVD: 8168/7054 ( SUPV:DONALD LUTRICK MW: 0.0 VISC: 0) MOVE RIG TO CD1-40 0 PV/YP: 0/ 0 APIWL: 0.0 Pump cement for 7" casing. Had minor flow out annulus after shut down. Shut well in as precaution. Well static. ND BOPE. NU tree and test to 3500 psi. UPCOMING OPERATIONS:MOVE 05/15/99 (Dll) MW: 0.0 VISC: 0 PV/YP: 0/ 0 TD/TVD: 8168/7054 ( 0) RIG RELEASED SUPV:DONALD LUTRICK Secure well. Rig release @ 0230 hrs. 5/15/99. UPCOMING OPERATIONS:MOVE APIWL: 0.0 07/17/00 (D12) MW: 9.2 VISC: 50 PV/YP: 11/23 APIWL: 3.9 TD/TVD: 8168/7054 ( 0) TAG FLOAT COLLAR @ 8158' PERFORM 7" CIT. SUPV:REYNOLDS/REILLY Move rig off CD1-40 and spot rig over CD1-35. Accept rig @ 1600 hrs. 7/17/00. NU BOPE and test to 250/3500 psi. RECEIVED /',r~c, hora~e Date: 08/10/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 07/18/00 (D13) MW: 9.2 VISC: 45 PV/YP: 10/24 TD/TVD: 9025/7054 ( 857) DRILLING AHEAD @ 9400' SUPV:SCOTT REYNOLDS APIWL: 4.0 RIH. Displace diesel with brine. RIH. Wash thru cement stringers from 7878' to 8073' Displace brine with Flopro. Tag up @ 8074' Drill float collar, cement, float shoe. Drill 20' new hole from 8168' to 8188' Circulate and condition mud for LOT. Perform LOT, EMW=12.3 ppg. Drill from 8188' to 9025' 07/19/00 (D14) MW: 9.2 VISC: 49 PV/YP: 11/25 APIWL: 4.0 TD/TVD:10300/7010 (1275) DRILLING AT 10625' SUPV:DONALD LUTRICK Drilling from 9025' to 10232' Circ hi vis sweep. Pump out to shoe. Tight spot at 8700', 8558' and 8256' to 8258' Ream out OK. CBU while rotate and reciprocate. RIH to 10232'. No problems. Drilling from 10232' to 10300' 07/20/00 (D15) MW: 9.2 VISC: 49 PV/YP: 10/23 TD/TVD:l1680/7004 (1380) POH AT 11747' (MWD FAILURE) SUPV:DONALD LUTRICK Drilling from 10300' to 11680' APIWL: 4.0 07/21/00 (D16) MW: 9.2 VISC: 52 PV/YP: 9/23 TD/TVD:12215/7000 ( 535) DRLG AT 12690' SUPV:DONALD LUTRICK APIWL: 4.0 Drilling from 11680' to 11747'. MWD failed. Circ lo/hi vis sweeps. Pump out to shoe. CBU at shoe while reciprocate and rotate. Pump out to 7044' POH. Change out MWD tools. RIH. Check shot at 11650'. Ream from 11650' to 11747' Drilling from 11747' to 12215' 07/22/00 (D17) MW: 9.2 VISC: 49 PV/YP: 11/27 APIWL: 3.6 TD/TVD:13450/7011 (1235) CIRC AND PREP FOR BRINE DISPLACEMNET. SUPV:DONALD LUTRICK ~ Drilling from 12215' to 13450'. Circ lo/hi vis sweep. Rotate and reciprocate pipe. Pump out of hole to 11270' CBU while rotate and reciprocate. Flow check. OK. 07/23/00 (D18) TD/TVD:13450/7011 ( SUPV:DONALD LUTRICK MW: 9.2 VISC: 27 PV/YP: 0/ 0 APIWL: 0.0 0) TEST HANGER SEALS TO 5000 PSI. PREP TO NIPPLE DOWN. Continue to pump out of hole to shoe at 8158' Check flow. No problems. RIH to 13450' Circ lo/hi vis sweep while rotate and reciprocate pipe. PJSM. Displace well to brine. Monitor well. Initial loss - 95 bph. POH to 10770' Spot hi vis pill with nut plug. POH to 8230'. SPot hi vis pill with nut plug. POH to 7300'. CBU. Monitor well, loss rate 12 bph. POH. RU to run 4.5" tubing. PJSM. RIH w/4.5" completion equipment. 07/24/00 (D19) TD/TVD:13450/7011 ( SUPV:DONALD LUTRICK MW: 9.6 VISC: 0) RIG RELEASED 0 PV/YP: 0/ 0 APIWL: 0.0 Continue RIH w/4.5" completion equipment. ND BOPE. NU tree and test to 5000 psi. Set packer. PJSM. Pump brine and diesel. Had small leak at 4" horizontal flange. Set TWC. Tighten flange bolts. Test tree to 5000 psi. Set BPV. Secure well. Releaserig at 1500 hrs. 7/24/00. SURV CALCU TI0N AND FIELD WORKSHEET Job.o ii ~ O451-O4917 Sidetrack No~ . .............................. Page ...... ~ .... of ........ ~ ........ COmpany A__RCO ALASKA, INC. Rig Contractor & No. Doyon Drilling- Rig: #19 Field ALPINE ~ Well Name & No. CD#1/35 w~j,,r~~ Survey Section Name ANADRILL MWD BHI Rep. HARSTAD / CHRISTENSEN WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -464.92 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SS~ Target Description Target Coord. E/W Slot CO0rd. E/W 2336.57 Magn. Declination 26.360 Calculation Method MINIMUM CURVATURE Target Direction (DD) Bulld\Walk\DL per: 10Oft[~ 30m~] 10m~ Vert. Sec. Azim. 317.11 Magn, to Map Corr. 26.360 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 (FT) (DD) (DD) (FT) . (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 06-MAY-99 MWD 115.00 0.00 0.00 115.00 115.00 0.00 0.00 0.00 0.00 0.00 9 1/2" M1C 1.2 DEG AKO ~- 06-MAY-99 MWD 185.03 0.17 138.60 70.03 185.03 -0.10 -0.08 0.07 0.24 0.24 06-MAY-99 MWD 293.56 1.64 259.90 108.53 293.55 0.58 -0.47 -1.35 1.60 1.35 06-MAY-99 MWD 379.89 3.44 255.50 86.33 379.79 2.48 -1.34 -5.08 2.10 2.09 06-MAY-99 MWD 471.08 3.40 274.50 91.19 470.82 5.77 -1.81 -10.42 1.24 -0.04 06-MAY-99 MWD 562.69 5.05 293.10 91.61 562.18 11.45 -0.01 -16.84 2.32 1.80 20.30 06-MAY-99 MWD 650.74 6.16 287.20 88.05 649.81 19.09 2.90 -24.92 1.42 1.26 -6.70 06-MAY-99 MWD 740.83 7.24 277.20 90.09 739.28 27.63 5.04 -35.17 1.76 1.20 -11.10 06-MAY-99 MWD 826.72 8.44 269.30 ~ 85.89 824,37 36.02 5.65 -46.84 1.87 1.40 -9.20 06-MAY-99 MWD 915.91 8.98 266.30 89.19 912.53 44.81 5.12 -60.33 0.79 0.61 -3.36 06-MAY-99 MWD 1005.97 8.72 264.80 90.06 1001.52 53.43 4.04 -74.15 0.39 -0.29 -1.67 06-MAY-99 MWD 1096.13 8.68 266.50 90.16 1090.64 61.92 3.01 -87.74 0.29 -0.04 1.89 06- MAY-99 MWD 1191.70 8.41 266.00 95.57 1185.15 70.89 2.08 -101.91 0.29 -0.28 -0.52 ',~ 06-MAY-99 MWD 1286.52 7.42 267.30 94.82 1279.07 79.19 1.31 -114.95 1.06 -1.04 1.37 06-MAY-99 I~WD 1382.80 4.33 272.90 96.28 1374.83 85,81 1,20 -124.79 3.26 -3,21 06-MAY-99 MWD 1477.21 1.97 281.60 94.41 1469.09 89.69 1.71 -129.94 2.54 -2.50 -- 07-MAY-99 MWD 1572,35 0.74 340.50 95.14 1564,21 91.58 2.62 -131.74 1.80 -1.29 07- MAY-99 MWD 1666.92 0.79 337.30 94.57 1658.77 92.75 3.79 -132.20 0.07 0.05 07- MAY-99 MWD 1762.39 1.22 113.70 95.47 1754.23 92.44 3.99 -131.52 1.96 0.45 07-MAY-99 MWD 1858.84 1.28 115.60 96.45 1850.66 90.49 3.11 -129,61 0.08 0.06 07-MAY-99 MWD 1953.81 0.51 119.40 94.97 1945.62 89.10 2.45 -128.29 0.81 -0.81 -- 07-MAY-99 MWD 2049.12 0.37 129,40 95.31 2040.93 88.40 2.04 -127.68 0,17 -0.15 09-MAY-99' MWD 2144.14 0.52 110.40 95.02 2135.94 87.71 1.70 -127.04 0.22 0.16 6 3/4" M1/XL 1.2 DEG AKO I SURVEY CALCULATION AND FIELD WORKSHEET ~ Job No. 0451-O4917 Sidetrack No. ~ Page ..... · -' [!,r~_' I::~--"~J Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling - Rig: #19 Field ALPINE Well Name & No. CD#1/35 Survey Section Name ANADRILL MWD BHI Rep. HARSTAD / CHRISTENSEN WELL DATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -464.92 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SSE~ Target Description Target Coord. E/W Slot Coord. E/W 2336.57 Magn. Declination 26.360 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m{-] 10m~ Vert. Sec. Azim. 317.11 Magn. to Map Corr. 26.360 MaP North to: OTHER i 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 (FT) (DD) (DD) (F-r) . (F'r) (F'I~ (FT) (Per 100 FT) Drop (-) Left (-) 09-MAY-99 MWD 2240.02 0.40 93.70 95.88 2231.82 87.07 1.53 -126.30 0.19 -0.13 09-MAY-99 MWD 2334.97 0.57 105.90 94.95 2326.77 86.43 1.37 -125.51 0.21 0.18 09-MAY-99 MWD 2348.84 0.59 115.70 13.87 2340.64 86.30 1.32 -125.38 0.73 0.14 09-MAY-99 MWD 2426.38 0.21 108.60 77.54 2418.17 85.81 1.11 -124.89 0.49 -0.49 09-MAY-99 MWD 2521.31 0.26 52.70 94.93 2513.10 85.63 1.18 -124.55 0.24 0.05 09-MAY-99 MWD 2616.65 0.32 71.50 95.34 2608.44 85.50 1.40 -124.13 0.12 0.06 09-MAY-99 MWD 2712.98 0.26 49.20 96.33 2704.77 85.38 1.62 -123.70 0.13 -0.06 09-MAY-99 MWD 2808.06 0.24 77.90 95.08 2799.85 85.27 1.81 -123.35 0.13 -0.02 09-MAY-99 MWD 2903.42 0.23 48.30 95.36 2895.21 85.17 1.98 -123.01 0.13 -0.01 09-MAY-99 MWD 2998.11 0.26 66.10 94.69 2989.90 85.09 2.19 -122.67 0.09 0.03 09-MAY-99 MWD 3094.14 0.09 35.70 96.03 3085.93. 85.04 2.34 -122.43 0.20 -0.18 09-MAY-99 MWD 3188.73 0.08 54.60 94.59 3180.52 85.04 2.44 -122.33 0.03 -0.01 09-MAY-99 MWD 3282.78 0.19 351.70 94.05 3274.57 85.16 2.63 -122.30 0.18 0.12 09-MAY-99 MWD 3378.21 0.20 16.20 95.43 3370.00 85.38 2.95 -122.28 0.09 0.01 09-MAY-99 MWD 3473.47 0.06 111.70 95.26 3465.26 85.42 3.09 -122.18 0.22 -0.15 09-MAY-99 MWD 3568.14 0.09 69.50 94.67 3559.93 85.35 3.10 -122.07 0.06 0.03 09-MAY-99 MWD 3663.58 0.04 311.90 95.44 3655.37 85.35 3.14 -122.02 0.12 -0.05 09-MAY-99 MWD 3759.63 0.06 326.00 96.05 3751.42 85.43 3.21 -122.07 0.02 0.02 09-MAY-99 MWD 3854.51 0.09 277.10 94.88 3846.30 85.54 3.26 -122.18 0.07 0.03 09-MAY-99 MWD 3947.45 0.09 138.90 92.94 3939.24 85.52 3.21 t -122.20 0.18 0.00 09-MAY-99 MWD 4042.67 0.19 146.60 95.22 4034.46 85.29 3.02 -122.06 0.11 0.11 09-MAY-99 MWD 4137.73 0.09 170.30 95.06 4129.52 85.07 2.82 -121.97 0.12 -0.11 09-MAY-99 MWD 4232.60 0.03 121.00 94.87 4224.39 84.99 2.73 -121.93 0.08 -0.06 09-MAY-99 MWD 4326.83 0.03 5.30 94.23 4318.62 84.98 2.75 -121.91 0.05 0.00 r SURVEY CALCULATION AND FIELD WORKSHEET i ~ Job No. O_.4~57___-?~91__7___ Sidetrack No~ Page 3 .of 5 !l -= |l,r~-= I Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling - Rig: #19 Field ALPINE [] Well Name & No. CD#1/35 Survey Section Name ANADRILL MWD BHI Rep. HARSTAD / CHRISTENSEN J~lll~Jl'~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -464.92 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SS~] Target Description Target Coord. E/W Slot CoOrd. E/W 2336.57 Magn. Declination 26.360 Calculation Method MINIMUM CURVATURE Target Direction (DD) Butld\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 317.11 Magn. to Map Corr. 26.360 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 (FT) (DD) (DD) (FT) , (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 09-MAY-99 MWD 4422.42 0.09 2.20 95.59 4414.21 85.05 2.85 -121.90 0.06 0.06 10- MAY-99 MWD 4518.11 0.11 29.10 95.69 4509.90 85.13 3.00 -121.86 0.05 0.02 10-MAY-99 MWD 4613.69 0.00 26.40 95.58 4605.48 85.16 3.08 -121.81 0.12 -0.12 10- MAY-99 MWD 4709.37 0.11 229.50 95.68 4701.16 85.16 3.02 -121.88 0.11 0.11 10-MAY-99 MWD 4804.69 0.09 236.00 95.32 4796.48 85.18 2.92 -122.01 0.02 -0.02 10-MAY-99 MWD 4899.83 0.29 239.60 95.14 4891.62 85.24 2.76 -122.28 0.21 0.21 10-MAY-99 MWD 4997.25 0.17 169.90 97.42 4989.03 85.18 2.49 -122.47 0.29 -0.12 10-MAY-99 MWD 5091.70 O. 18 97.10 94.45 5083.48 84.94 2.33 -122.30 0.22 0.01 10- MAY-99 MWD 5187.07 2.51 307.60 95.37 5178.83 86.89 3.59 -123.80 2.80 2.44 10-MAY-99 MWD 5282.48 5.37 313.20 95.41 5274.00 93.41 7.92 -128.71 3.02 3.00 5.87 10-MAY-99 MWD 5376.94 8.15 317.90 94.46 5367.80 104.51 15.92 -136.43 3.00 2.94 4.98 10-MAY-99 MWD 5473.16 10.47 321.10 96.22 5462.74 120.06 27.78 -146.49 2.47 2.41 3.33 10-MAY-99 MWD 5568.29 13.07 320.40 95.13 5555.86 139.42 42.80 -158.78 2.74 2.73 -0.74 -- 10-MAY-99 MWD 5663.50 14.20 317.60 95.21 5648.39 161.85 59.72 -173.51 1.37 1.1 9 -2.94 -- 10-MAY-99 MWD 5758.72 16.30 316.00 95.22 5740.25 186.89 77.96 -190.67 2.25 2.21 -1.68 10-MAY-99 MWD 5851.16 17.85 318.40 92.44 5828.62 214.02 97.89 -209.09 1.84 1.68 2.60 10-MAY-99 MWD 5946.09 20.20 318.00 94.93 5918.35 244.96 120.95 -229.72 2.48 2.48 -0.42 10-MAY-99 MWD 6041,17 24.17 317.00 95.08 6006.38 280.85 147.39 -253.99 4.19 4.18 -1.05 11 - MAY-99 MWD 6136.37 28.80 316.30 95.20 6091.56 323.30 178.24 -283.14 4.87 4.86 -0.74 11 -MAY-99 MWD 6231.92 31.70 315.10 95.55 6174.10 371.41 212.67 -316.77 3.10 3.04 -1.26 11-MAY-9~ MWD 6327.05 32.61 316.10 95,13 6254.63 422.02 248.85 -352.19 1.11 0.96 1.05 11 -MAY-99 MWD 6424.12 32.48 317.00 97.07 6336.46 474.24 286.76 -388.10 0.52 -0.13 0.93 11 -MAY-99 MWD 6519.20 31.92 318.90 95.08 6416.92 524,89 324.37 -422.04 1.22 -0.59 2.00 11 -MAY-99 MWD 6613.12 31.45 318.40 93.92 6496.84 574.20 361.40 -454.63 0.57 -0.50 -0.53 , SURVEY CALCU TiON AND FIELD WORKSHEET ~ Job No. 0451-04917 Sidetrack No. Page 4 of 5 Company ARCO ALASKA, INC. Rig Contractor & No. Doyen Drilling- Rig: #19 Field ALPINE -- Well Name&No. CD#1/35 Survey Section Name ANADRILL MWD BHI Rep. HARSTAD ! CHRISTENSEN I~ WELL DATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -464.92 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ $S~ Target Description Target Coord. E/W Slot Coord. E/W 2336.57 Magn. Declination 26.360 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 317.11 Magn. to Map Corr. 26.360 MaP North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (DD) (DD) (FT)'i (FT) (F'r) (FT) (Per m0 FT) Drop (-) Left (-) 11 -MAY-99 MWD 6673.87 31.27 318.30 60.75 6548.71 605.81 385.03 -475.64 0.31 -0.30 -0.16 11-MAY-99 MWD 6727.44 30.92 317.90 53.57 6594.59 633.47 405.62 -494.11 0.76 *0.65 -0.75 ~, 12-MAY-99 MWD 6822.75 31.14 319.70 95.31 6676.26 682.58 442.58 -526.47 1.00 0.23 1.89 12-MAY-99 MWD 6856.38 32.07 319.90 33.63 6704.90 700.18 456.05 -537.85 2.78 2.77 0.59 12-MAY-99 MWD 6888.30 34.87 321.90 31.92 6731.53 717.74 469.71 -548.94 9.43 8.77 6.27 12-MAY-99 MWD 6918.97 38.12 323.50 30.67 6756.18 735.89 484.23 -559.98 11.04 10.60 5.22 12-MAY-99 MWD 6951.98 41.88 325.10 33.01 6781.46 756.94 501.46 -572.35 11.81 11.39 4.85 12-MAY-99 MWD 6983.67 44.80 326.50 31.69 6804.51 778.43 519.45 -584.57 9.70 9.21 4.42 12-MAY-99 MWD 7014.26 47.18 326.80 30.59 6825.76 800.13 537.83 -596.66 7.81 7.78 0.98 12-MAY-99 MWD 7046.53 50.60 327.50 32.27 6846.98 824.06 558.25 -609.84 10.72 10.60 2.17 12-MAY-99 MWD 7078.67 53.54 327.50 32.14 6866.73 849.00 579.63 -623.46 9.15 9.15 0.00 12-MAY*99 MWD 7109.10 56.07 326.40 30.43 6884.27 873.50 600.47 -637.03 8.82 8.31 -3.61 12-MAY-99 MWD 7141.26 58.17 325.90 32.16 6901.73 900.17 622.90 -652.07 6.66 6.53 -1.55 12-MAY-99 MWD 7173.41 58.48 325.50 32.15 6918.61 927.22 645.50 -667.49 1.43 0.96 -1.24 12-MAY-99 MWD 7204.68 58.35 326.10 31.27 6934.99 953.55 667.53 -682.46 1.69 -0.42 1.92 12-MAY-99 I~IWD 7236.76 60.12 326.00 32.08 6951.40 980.78 690.40 -697.86 5.52 5.52 -0.31 12-MAY-99 MWD 7268.72 63.47 325.70 31.96 6966.50 1008.62 713.70 -713.67 10.51 10.48 -0.94 12-MAY-99 MWD 7297.41 66.98 326.20 28.69 6978.52 1034.35 735.28 -728.25 12.34 12.23 1.74 12-MAY-99 MWD 7332.25 71.69 327.10 34.84 6990.81 1066.49 762.51 -746.16 13.73 13.52 2.58 12-MAY-99 MWD 7363.23 75.28 328.70 30.98 6999.62 1095.66 787.66 -761.94 12.60 11.59 5.16 12-MAY-S~9 MWD 7394.08 76.39 329.50 30.85 7007.17 1124.92 813.33 -777.30 4.39 3.60 2.59 12-MAY-99 MWD 7427.10 78.19 329.90 33.02 7014.43 1156.35 841.14 -793.55 5.58 5.45 1.21 12-MAY-99 MWD 7459.34 80.05 331.50 32.24 7020.52 1187.13 868.75 -809.04 7.55 5.77 4.96 12-MAY-99 MWD 7489.14 80.13 331.50 29.80 7025.65 '1215.56 894.55 -823.05 0.27 0.27 0.00 :::: : : ~ = Sidetrack No. Page 5 of 5 ~Wel~;;ame;~~ . Rig Contractor & No DoyonDrllng-Rg'~lOsu~eyS;c~~ ~~ Field BHI Rep. HARSTAD / CHRISTENSEN ~~ WELL DATA Target ~D (~ Target Coord. N/S Slot Coord. N/S -464.92 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS~ Target Descriptien Target Coord. E~ Siot ChOrd. ~ 2336.57 Magn. Declination 26,360 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build~Walk~DL per: 10~ 30m~ lOm~ Ve~. Sec. Azim. 317.11 Magn. to Map Corr. 26.360 Map No~h to: OTHER I SURVEY DATA Su~ey Su~ey Incl. Hole Course VeRical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length ~D Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (~ (DD) (DD) (~ , (~ (~ (~ (Per 100 ~ Drop (-) Left (-) 12-MAY-99 MWD 7523.17 80.78 330.70 ~34.03 7031.29 1248.12 923.92 -839.27 3.00 1.91 -2.35 12-MAY-99 MWD 7554.56 83.25 331 ;30 31.39 7035.65 1278.30 951.11 -854.34 8.09 7.87 1.91 12-MAY-99 MWD 7584.46 83.85 331.70 29.90 7039.01 1307,08 977.22 -868.51 2.41 2.01 1.34 12-MAY-99 MWD 7617.45 83.88 331.40 32.99 7042.53 1338.84 1006.06 -884.14 0.91 0.09 -0.91 12-MAY-99 MWD 7649.98 83.77 331.30 32.53 7046.03 1370.19 1034.44 -899.64 0.46 -0.34 -0.31 12-MAY-99 MWD 7679.40 83.65 332.60 29.42 7049.26 1398.45 1060.25 -913.40 4.41 -0.41 4.42 12-MAY-99 MWD 7713.20 83.62 332.40 33.80 7053.00 1430.84 1090.05 -928.91 0.59 -0.09 -0.59 12-MAY-99 MWD 7745.22 83.57 332.30 32.02 7056.58 1461.54 1118.23 -943.67 0.35 -0.16 -0.31 12-MAY-99 MWD 7775.03 83.33 332.50 29.81 7059.98 1490.11 1144.48 -957.39 1.05 -0.81 0.67 12-MAY-99 MWD 7808.66 83.44 332.30 33.63 7063.85 1522.33 1174.08 -972.87 0.68 0.33 -0.59 13- MAY-99 MWD · 7839.87 85.65 331.20 31.21 7066.82 1552.39 1201.45 -987.58 7.90 7.08 -3.52 13-MAY-99 MWD 7869.91 88.31 330.50 30.04 7068.40 1581.53 1227.64 -1002.19 9.16 8.85 -2.33 13-MAY-99 MWD 7903.03 91.48 329.90 33.12 7068.46 1613.78 1256.38 -1018.64 9.74 9.57 -1.81 13-MAY-99 MWD 7935.01 93.65 329.40 31.98 7067.03 1644.97 1283.95 -1034.79 6.96 6.79 -1.56 13-MAY-99 MWD 7966.00 94.09 330.90 30.99 7064.94 1675.09 1310.76 -1050.17 5.03 1.42 4.84 13-MAY-99 MWD 7998.27 94.00 330.60 32.27 7062.66 1706.37 1338.85 -1 ~5,90 0.97 -0.28 -0.93 13-MAY-99 MWD 8030.36 93.~ 330.20 32.09 7~0.49 1737.53 1 ~6.69 -1081.72 1.44 ~.72 -1.25 13-MAY-99 MWD 8061.52 93.43 330.50 31.16 7058.53 1767.80 1393.71 -1097.10 1.45 -1.09 0.96 13-MAY-99 MWD 8095.69 92.45 329.10 34.17 7056.78 1801.09 1423.21 -1114.27 5.~ -2.87 -4.10 13-MAY-99 MWD 8168.00 92.~ 329.10 72.31 7053.97 1871.77 1485.21 -1151.37 0.62 -0.62 0.00 Projected Data - NO SURV~ AND FIELD WOR Job No. 0451'04917 Sidetrack No. Page .1 of 3 Company PHILLIPS ALASKA, INC'. Rig Contractor & No. Doyon Drilling- Rig: #19 Field ALPINE Well Name & No. CD#1/35 Survey Section Name ANADRILL MWD BHI Rep. B HENDERSON/D NEWLON i IN"r~~ WELL DATA ~Target TVD . (FT) Target Coord. N/S Slot Coord, N/S -464.92 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~] SS[- Target Description Target Coord, E/W Slot Coord, E/W 2336,57 Magn, Declination 26,360 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert, Sec, Azim, 331,96 Magn, to Map Corr, ' 26.360 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) (FT) (FT) (FT) l(Per lO0 ET) Drop (-) Left (-) MWD 8095.69 92.45 329.10 7056.78 1780.96 1423.21 -1114.27 TIE IN POINT 18-JUL-O0 MWD 8209.47 92.74 330.36 113.78 7051.63 1893.53 1521.37 -1171.56 1.14 0.25 1111 4-3/4"M1X 1.2 DEG AKO 18-JU L-O0 MWD 8302.00 91.71 331.85 92.53 7048.04 1985.98 1602.32 -1216.24 1.96 -1.11 1.61 18-J U L-O0 MWD 8398.23 92.78 331.89 96.23 7044.27 2082.13 1687.12 -1261.57 1.11 1.11 0.04 18-JUL-O0 MWD 8492.53 91.37 332.71 94.30 7040.85 2176.37 1770.55 -1305.38 1.73 -1.50 0.87 18-JUL-O0 MWD 8585.67 92.74 332.58 93.14 7037.51 2269.44 1853.22 -1348.15 1.48 1.47 -0.14 18-J U L-O0 MWD 8678.48 91.65 333.54 92.81 7033.96 2362.16 1935.90 -1390.16 1.56 -1.1 7 1.03 18-JUL-O0 MWD 8773.56 92.37 330.33 95.08 7030.62 2457.17 2019.73 -1434.86 3.46 0.76 -3.38 18-J UL-O0 MWD 8866.32 91.61 331.50 92.76 7027.40 2549.86 2100.75 -1479.92 1.50 -0.82 1.26 18-J U L-O0 MWD 8960.79 93.19 330.56 94.47 7023.44 2644.23 2183.32 -1525.64 1.95 1.67 -1.00 , -- 19-JUL-O0 MWD 9053.67 91.78 330.88 92.88 7019.42 2736.99 2264.26 -1571.02 1.56 -1.52 0.34 19-J U L-O0 MWD 9148.25 91.47 332.47 94.58 7016.74 2831.53 2347.48 -1615.88 1.71 -0.33 1.68 19-J U L-O0 MWD 9242.05 92.50 330.85 93.80 7013.49 2925.27 2429.98 -1660.37 2.05 1.10 -1.73 19-JUL-O0 MWD. 9336.50 89.90 330.55 94.45 7011.51 3019.67 2512.32 -1706.58 2.77 -2.75 -0.32 .. 19-JUL-O0 MWD 9432.12 89.11 331.71 95.62 7012.33 3115.27 2596.05 -1752.75 1.47 -0.83 1.21 19-JUL-O0 MWD 9525.78 89.79 330.61 93.66 7013.23 3208.92 2678.09 -1797.92 1.38 0.73 -1.17 19-JUL-O0 MWD 9618.05 90.86 330.24 92.27 7012.71 3301.15 2758.34 -1843.46 1.23 1.16 -0.40 19-JUL-O0 MWD 9713.44 89.35 330.74 95.39 7012.54 3396.51 2841.35 -1890.45 1.67 -1.58 0.52 19-JUL-O0 MWD 9804.54 90.10 331.48 91.10 7012.97 3487.59 2921.11 -1934.46 1.16 0.82 0.81 . -- 19-JUL-O0 ' MWD 9900.41 89.42 329.77 95.87 7013.37 3583.43 3004.65 -1981.48 1.92 -0.71 -1.78 19-JUL-O0. MWD 9992.00 90.21 333.85 91.59 7013.67 3675.00 3085.36 -2024.74 4.54 0.86 4.45 19-JUL-O0 MWD :10087.00 90.96 334.01 95.00 7012.70 3769.94 3170.69 -2066.49 0.81 0.79 O. 17 19-JUL-O0 MWD 10179.90 90.00 334.10 92.90 7011.92 3862.77 3254.22 -2107.13 1.04 -1.03 O. 10 19-JUL-O0 MWD 10273.50 90.89 334.54 93.60 7011.20 3956.29 3338.57 -2147.69 1.06 0.95 0.47 i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-04917 Sidetrack No. Page 2 of 3 I Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling - Rig: #19 Field ALPINE Well Name & No. CD#1/35 Survey Section Name ANADRILL MWD BHI Rep. B HENDERSON/D NEWLON l,~kr~g~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -464,92 Grid CorreCtion 0,000 Depths Measured From: RKB ~ MSL~] SS~ Target Description Target Coord. E/W Slot Coord. E/W 2336,57 Magn, Declination 26,360 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ft~ 30ml~ 10m0 Vert, Sec, Azim. 331.96 Magn, to Map Corr, ' 26.360 Map North to: OTHER i SURVEY DATA Su~ey 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 lO0 F-r)Drop (-) Left (-) 20-JUL-00 MWD 10365.41 89.97 329,74 91.91 7010.51 4048.17 3419.80 -2190.63 5,32 -1.00 -5.22 20-JUL-00 MWD 10459.42 90,69 332.92 94.01 7009,96 4142.16 3502.27 -2235,72 3,47 0,77 3.38 -- 20-JUL-00 MWD 10552.46 90,41 328,76 93,04 7009.07 4235.16 3583,50 -2281,04 4,48 -0,30 -4,47 20-JUL-00 MWD 10649.04 89.35 331.03 96.58 7009.27 4331,67 3667,04 -2329,48 2.59 -1.10 2,35 20-JUL-O0 MWD 10743.00 90.45 331.05 93.96 ?009.44 4425,61 3749,25 -2374,98 1,17 1.17 0,02 20-JUL-00 MWD 10837.00 89,21 331,48 94.00 7009.72 4519,60 3831.67 -2420,17 1,40 -1 °32 0,46 20-JUL-O0 MWD 10930.00 89.59 331,36 93.00 7010.69 4612,59 3913.34 -2464,66 0.43 0,41 -0,13 20-JUL-O0 MWD 11023.00 89.83 331,29 93,00 :7011,16 4705.59 3994,93 -2509,28 0,27 0,26 -0.08 20-JUL-00 MWD 11118.00 90.31 332,14 95,00 7011.04 4800.58 4078.59 -2554,30 1,03 0,51 0,89 20-JUL-00 MWD 11214.00 89.59 332,00 96.00 7011.13 4896.58 4163.40 -2599,26 0.76 -0,75 -0.15 20-JUL-O0 MWD 11308,00 89,83 332.02 94.00 7011,60 4990.58 4246,41 -2643,38 0,26 0.26 0.02 20-JUL-00 MWD 11406.00 90.55 332.41 98.00 7011,28 5088,58 4333,11 -2689.06 0,84 0,73 0,40 20-JUL-00 MWD 11502,00 91.44 333.52 96,00 7009.61 5184,55 4418.60 -2732,69 1.48 0.93 1.16 -- 20-JUL-00 MWD 11599.00 91.78 334.45 97.00 7006,89 5281.45 4505.74 -2775.21 1.02 0,35 0.96 21-JUL-00 MWD 11695.00 92.06 334,83 96.00 7003,67 5377,29 4592.44 -2816.31 0.49 0.29 0.40 21 -JUL-00 MWD 11792.00 89.97 331.44 97.00 7001.95 5474,23 4678.94 -2860.13 4.11 -2.15 -3.49 4 3/4" MlX 1.2 DEG AKO ! 21 -JU L-00 MWD 11888.00 90.72 333.28 96,00 7001.37 5570,22 4763.98 -2904,66 2.07 0,78 1.92 21-JUL-00 MWD 11985.00 90.41 331,22 97.00 7000.42 5667,21 4849,81 -2949.82 2.15 -0.32 -2.12 21-JUL-00 MWD 12081,00 90.41 330.74 96.00 6999.73 5763.20 4933.76 -2996.39 0,50 0.00 -0,50 · 21 -J U L-00 MWD 12177.00 90.62 330.49 96.00 6998.87 5859.17 5017.40 -3043.49 0.34 0,22 -0.26 22-JUL-O0 MWD 12274.00 89.28 331.59 97.00 6998.95 5956.15 5102.27 -3090.46 1,79 -1,38 1.13 22-JUL-00 MWD -~3~01~30-~ 89.97 331.45 96.00 6999.58 6052,14 5186.65 -3136.24 0.73 0.72 -0.15 __ 22-J UL-00 MWD 12466.00 90.38 329.70 96.00 6999,29 6148.11 5270.26 -3183.40 1.87 0,43 -1.82 22-JUL-00 MWD' -1'~'563100 9-0-~7-~- 331.23 97.00 6998,30 6245.07 5354.65 -3231.21 1,63 0.42 1.58 i ii1! II I II III1! II I II I sURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-04917 Sidetrack No. " Page 3 of 3 I Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling - Rig: #19 Field ALPINE Well Name & No. CD#1/35 Survey Section Name ANADRILL MWD BHI Rep. B HENDERSON/D NEWLON WELL DATA Target I'VD __ (F'r) Target Coord. N/S Slot Coord. N/S -464.92 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SS~ Target Description Target Coord. E/W Slot Coord. E/W 2336.57 Magn. Declination 26.360 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mi-) 10m~ Vert. Sec..Azim. 331.96 Magn. to Map Corr. 26.360 Map North to: OTHER sURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate' Date Tool Depth Angle Direction Length I'VD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'~ (Fl] (FT) (FT) (Per 100 FT) Drop (-) Left (-) 22-JUL-00 MWD 12660.00 89.59 329.12 97.00 6997.97 6342.02 5438.79 -3279.45 2.50 -1.24 -2.18 22-JUL-00 MWD 12755.00 90.27 329.58 95.00 6998.09 6436.92 5520.52 -3327.88 0.86 0.72 0.48 22-J U L-OO MW D 12849.00 90.86 329.19 94.00 6997.16 6530.82 5601.41 -3375.75 0.75 0.63 -0.41, -- 22-J U L-00 MWD 12943.00 89.35 329.04 94.00 6996.99 6624.70 5682.08 -3424.00 1.61 -1.61 -0.16 22-JU L-00 MWD 13038.00 90.10 327.39 95.00 °6997.45 6719.49 5762.83 -3474.03 1.91 0.79 -1.74 22-J U L-00 MWD 13132.00 88.28 329.25 94.00 6998.78 6813.28 5842.81 -3523.39 2.77 -1.94 1.98 22-JUL-00 MWD 13227.00 87.91 328.47 95.00 7001.93 6908.09 5924.08 -3572.49 0.91 -0.39 -0.82 22-JUL-00 MWD 13323.00 88.42 328.93 96.00 7005.01 7003.89 6006.06 -3622.34 0.72 0.53 0.48 22-J UL-00 MWD 13394.00 86.84 328.74 71.00 7007.94 7074.72 6066.76 -3659.05 2.24 -2.23 -0.27 22-JUL-00 MWD 13450.00 86.84 328.74 56.00 7011.03 7130.54 6114.56 -3688.07 0.00 0.00 0.00 Projected Data - NO SURVEY -- .. , . ANADRILL SCHLUMBERGER Survey report Client ................... : PHILLIPS Alaska, Inc. Field .................... : Alpine Well ..................... : CD1-35 API number ............... : 50-103-20297-00 Engineer ................. : A. Nutter 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 .......... : GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 55.72 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: 331.96 degrees 22-Jul-2000 20:40:29 Page Spud date ................ : 17-July-00 Last survey date ......... : 22-Jul-00 Total accepted surveys...: 172 MD of first survey ....... : 0.00 ft MD of last survey ........ : 13450.00 ft 1 of 7 Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 17-Jul-2000 Magnetic field strength..: 1147.14 HCNT Magnetic dec (+E/W-) ..... : 25.69 degrees Magnetic dip ............. : 80.54 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.14 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 -o Magnetic dec (+E/W-) ..... : 25.74 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.74 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6 lB 48] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0.00 2 115.00 0.00 0.00 3 185.03 0.17 138.60 4 293.56 1.64 259.90 5 379.89 3.44 255.50 Course length (ft) 22-Jul-2000 20:40:29 6 471.08 3.40 274.50 7 562.69 5.05 293.10 8 650.74 6.16 287.20 9 740.83 7.24 277.20 10 826.72 8.44 269.30 Page 11 915.91 8.98 266.30 12 1005.97 8.72 264.80 13 1096.13 8.68 266.50 14 1191.70 8.41 266.00 15 1286.52 7.42 267.30 TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 16 1382.80 4.33 272.90 17 1477.21 1.97 281.60 18 t572.35 0.74 340.50 19 1666.92 0.79 337.30 20 1762.39 1.22 113.70 0.00 0.00 0.00 0.00 0.00 0.00 115.00 115.00 0.00 0.00 0.00 0.00 70.03 185.03 -0.10 -0.08 0.07 0.10 108.53 293.55 0.22 -0.47 -1.35 1.43 86.33 379.79 1.21 -1.34 -5.08 5.25 21 1858.84 1.28 115.60 22 1953.81 0.51 119.40 23 2049.12 0.37 129.40 24 2144.14 0.52 110.40 25 2240.02 0.40 93.70 91.19 470.82 3.30 -1.81 -10.42 10.58 91.61 562.18 7.90 -0.01 -16.84 16.84 88.05 649.81 14.28 2.90 -24.92 25.09 90.09 739.28 20.98 5.04 -35.17 35.53 85.89 824.37 27.00 5.65 -46.84 47.18 26 2334.97 0.57 105.90 27 2348.84 0.59 115.70 28 2426.38 0.21 108.60 29 2521.31 0.26 52.70 30 2616.65 0.32 71.50 89.19 90.06 90.16 95.57 94.82 [(c)2000 Anadrill IDEAL ID6 lB 48] _ -- 96.28 94.41 95.14 94.57 95.47 912.53 32.88 5.12 1001.52 38.42 4.04 1090.65 43.90 3.01 1185.15 49.75 2.08 1279.07 55.19 1.31 1374.83 59.72 1.20 1469.09 62.59 1.71 1564.21 64.24 2.62 1658.77 65.49 3.79 1754.23 65.35 3.99 1850.66 63.68 3.11 1945.62 62.47 2.45 2040.93 61.82 2.04 2135.94 61.22 1.70 2231.82 60.72 1.53 2326.77 60.21 1.37 2340.64 60.11 1.32 2418.17 59.68 1.11 2513.10 59.59 1.18 2608.44 59.58 1.40 96.45 94.97 95.31 95.02 95.88 -60.33 -74.15 -87.74 -101.91 -114.95 -124.79 -129.94 -131.74 -132.20 -131.52 -129.61 '128.29 -127.68 -127.04 -126.30 -125.51 -125.38 -124.89 -124.55 -124.13 94.95 13.87 77.54 94.93 95.34 60.55 74.26 87.79 101.93 114.95 124.79 129.95 131.77 132.25 131.58 129.65 128.31 127.70 127.05 126.31 125.52 125.39 124.89 124.56 124.13 2 of 7 DLS Srvy Tool (deg/ tool qual 100f) type type 0.00 0.00 TIP 0.00 0.00 MWD M -- 138.60 0.24 MWD M 250.81 1.60 MWD M 255.26 2.10 MWD M -- 260.15 269.95 276.65 278.16 276.87 274.85 273.12 271.96 271.17 270.65 270.55 270.75 271.14 271.64 271.74 271.38 271.09 270.92 270.77 270.69 270.63 270.61 270.51 270.54 270.64 1.24 MWD M 2.32 MWD M 1.42 MWD M -- 1.76 MWD M 1.87 MWD M -- 0.79 MWD M 0.39 MWD M 0.29 MWD M 0.29 MWD M -- 1.06 MWD M -- 3.26 MWD M -- 2.54 MWD M 1.80 MWD M -- 0.07 MWD M 1.96 MWD M -- 0.08 MWD M -- 0.81 MWD M 0.17 MWD M 0.22 MWD M -- 0.19 MWD M 0.21 MWD M 0.73 MWD M -- 0.49 MWD M 0.24 MWD M 0.12 MWD M -- RECEIV ED AUG 1 0 2000 Alaska Oil & G-~s Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 31 2712.98 0.26 49.20 32 2808.06 0.24 77.90 33 2903.42 0.23 48.30 34 2998.11 0.26 66.10 35 3094.14 0.09 35.70 36 3188.73 0.08 54.60 37 3282.78 0.19 351.70 38 3378.21 0.20 16.20 39 3473.47 0.06 111.70 40 3568.41 0.09 69.50 41 3663.58 0.04 311.90 42 3759.63 0.06 326.00 43 3854.51 0.09 277.10 44 3947.45 0.09 138.90 45 4042.67 0.19 146.60 46 4137.73 0.09 170.30 47 4232.60 0.03 121.00 48 4326.83 0.03 5.30 49 4422.42 0.09 2.20 50 4518.11 0.11 29.10 51 4613.69 0.00 26.40 52 4709.37 0.11 229.50 53 4804.69 0.09 236.00 54 4899.83 0.29 239.60 55 4997.25 0.17 169.90 56 5091.70 0.18 97.10 57 5187.07 2.51 307.60 58 5282.48 5.37 313.20 59 5376.94 8.15 317.90 60 5473.16 10.47 321.10 Course length (ft) __ 96.33 95.08 95.36 94.69 96.03 94.59 94.05 95.43 95.26. 94.94 95.17 96.05 94.88 92.94 95.22 95.06 94.87 94.23 95.59 95.69 95.58 95.68 95.32 95.14. 97.42 94.45 95.37 95.41 94.46 96.22 [(c)2000 Anadrill IDEAL ID6 lB 48] TVD depth (ltl 2704.77 2799.85 2895.21 2989.90 3085.93 3180.52 3274.57 3370.00 3465.26 3560.20 3655.37 3751.42 3846.30 3939.24 4034.46 4129.52 4224.39 4318.62 4414.21 4509.90 4605.48 4701.16 4796.48 4891.62 4989.03 5083.48 5178.83 5274.00 5367.80 5462.74 22-Jul-2000 20:40:29 Page Vertical Displ Displ Total At section +N/S- +E/W- disp1 Azim (ft) (ft) (ft) (ft) (deg) 59.59 1.63 -123.70 123.72 270.75 59.58 1.81 -123.35 123.36 270.84 59.57 1.98 -123.01 123.02 270.92 59.60 2.19 -122.67 122.69 271.02 59.62 2.34 -122.43 122.45 271.10 59.66 2.44 -122.33 59.81 2.63 -122.30 60.08 2.95 -122.28 60.16 3.09 -122.18 60.12 3.10 -122.07 60.14 3.14 -122.02 60.22 3.21 -122.07 60.31 3.26 -122.18 60128 3.21 -122.20 60.05 3.03 -122.06 59.82 2.82 -121.97 59.73 2.73 -121.93 59.73 2.75 -121.91 59.82 2.85 -121.90 59.93 3.00 -121.86 59.98 3.08 -121.81 59.96 3.02 -121.88 59.93 2.92 -122.01 59.92 2.76 -122.28 59.77 2.49 -122.47 59.55 2.33 -122.30 61.37 3.59 -123.80 67.50 7.92 -128.71 78.18 15.92 -136.43 93.38 27.78 -146.49 122.35 122.33 122.31 122.22 122.11 122.06 122.12 122.22 122.24 122.10 122.00 121.96 121.94 121.94 121.89 121.85 121.92 122.05 122.31 122.49 122.32 123.86 128.96 137.35 149.10 271.14 271.23 271.38 271.45 271.45 3 of 7 DLS Srvy (deg/ tool 100f) type 0.13 MWD M 0.13 MWD M 0.13 MWD M 0.09 MWD M 0.20 MWD M 0.03 MWD M 0.18 MWD M 0.09 MWD M 0.22 MWD M 0.06 MWD M 271.48 0.12 MWD M 271.51 0.02 MWD M 271.53 0.07 MWD M 271.51 0.18 MWD M 271.42 0.11 MWD M 271.32 271.28 271.29 271.34 271.41 0.12 MWD M 0.08 MWD M 0.05 MWD M 0.06 MWD M -- 0.05 MWD M -- Tool qual type 271.45 0.12 MWD M -- 271.42 0.11 MWD M 271.37 0.02 MWD M -- 271.29 0.21 MWD M 271.16 0.29 MWD M -- 271.09 271.66 273.52 276.65 280.74 0.22 MWD M - -- 2.80 MWD M - -- 3.02 MWD M - 3.00 MWD M - 2.47 MWD M - RECEIVED AUG 1 0 2000 .~,laska Oil & G~s C,o~s, Oommissior~ kr~c..,horage ANADRILL SCHLUMBERGER Survey Report 22-Jul-2000 20:40:29 Page 4 of 7 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 61 5568.29 13.07 320.40 62 5663.50 14.20 317.60 63 5758.72 16.30 316.00 64 5851.16 17.85 318.40 65 5946.09 20.20 318.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) I00f) 95.13 5555.86 112.41 42,.80 95.21 5648.39 134.28 59.72 95.22 5740.25 158.44 77.96 92.44 5828.62 184.69 97.89 94.93 5918.35 214.74 120.95 66 6041.17 24.17 317.00 95.08 6006.38 67 6136.37 28.80 316.30 95.20 6091.56 68 6231.92 31.70 315.10 95.55 6174.10 69 6327.05 32.61 316.10 95.13 6254.63 70 6424.12 32.48 317.00 97.07 6336.46 71 6519.20 31.92 318.90 95.08 6416.92 72 6613.12 31.45 318.40 93.92 6496.84 73 6673.87 31.27 318.30 60.75 6548.71 74 6727.44 30.92 317.90 53.57 6594.59 75 6822.75 31.14 319.70 95.31 6676.26 76 6856.38 32.07 319.90 33.63 6704.90 77 6888.30 34.87 321.90 31.92 6731.53 78 6918.97 38.12 323.50 30.67 6756.18 79 6951.98 41.88 325.10 33.01 6781.46 80 6983.67 44.80 326.50 31.69 6804.51 81 7014.26 47.18 326.80 82 7046.53 50.60 327.50 83 7078.67 53.54 327.50 84 7109.10 56.07 326.40 85 7141.26 58.17 325.90 86 7173.41 58.48 325.50 87 7204.68 58.35 326.10 88 7236.76 60.12 326.00 89 7268.72 63.47 325.70 90 7297.41 66.98 326.20 -158.78 -173.51 -190.67 -209.09 -229.72 164.44 183.50 205.99 230.87 259.62 [(c)2000 Anadrill IDEAL ID6 lB 48] 249.49 147.39 -253.99 293.66 290.42 178.24 -283.14 334.57 336.62 212.67 -316.77 381.54 385.20 248.85 -352.19 431.23 435.54 286.76 -388.10 482.55 484.69 324.37 -422.04 532.29 532.70 361.40 -454.63 580.77 563.42 385.03 -475.64 611.95 590.29 405.62 -494.11 639.28 638.12 442.59 -526.47 687.79 655.35 456.05 -537.85 672.63 469.71 -548.94 690.63 484.23 -559.98 711.65 501.46 -572.35 733.27 519.45 -584.57 30.59 6825.76 755.18 537.83 32.27 6846.98 779.40 558.25 32.14 6866.73 804.67 579.63 30.43 6884.27 829.44 600.47 32.16 6901.73 856.31 622.90 -596.66 -609.84 -623.46 -637.03 -652.07 -667.49 -682.46 -697.86 -713.67 -728.25 32.15 6918.61 883.51 645.50 31.27 6934.99 909.99 667.53 32.08 6951.40 937.41 690.40 31.96 6966.50 965.41 713.70 28.69 6978.52 991.31 735.28 Srvy tool type 285.09 2.74 MWD M 288.99 1.37 MWD M 292.24 2.25 MWD M -- 295.09 1.84 MWD M 297.77 2.48 MWD M 300.13 4.19 MWD M 302.19 4.87 MWD M -- 303.88 3.10 MWD M 305.24 1.11 MWD M 306.46 0.52 MWD M 705.16 722.47 740.31 760.95 782.01 307.55 1.22 MWD M -- 308.48 0.57 MWD M 308.99 0.31 MWD M 309.38 0.76 MWD M 310.05 1.00 MWD M 803.28 826.77 851.28 875.42 901.77 310.30 2.78 MWD M 310.55 9.43 MWD M 310.85 11.04 MWD M -- 311.22 11.81 MWD M 311.62 9.70 MWD M -- 928.55 954.65 981.66 1009.30 1034.88 312.03 7.81 MWD M -- 312.47 10.72 MWD M -- 312.91 9.15 MWD M 313.31 8.82 MWD M 313.69 6.66 MWD M Tool quat type 314.04 1.43 MWD 'M - 314.37 1.69 MWD M - -- 314.69 5.52 MWD M - -- 315.00 10.51 MWD M - 315.28 12.34 MWD M - REC-EIVED AUG 0 2000 Alaska Oil & Gas Cons. C, ommission Anchorage ANADRILL SCHLUMBERGER Survey Report 22-Jul-2000 20:40:29 Page 5 of 7 Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 91 7332.25 71.69 327.10 34.84 6990.81 92 7363.23 75.28 328.70 30.98 6999.62 93 7394.08 76.39 329.50 30.85 7007.17 94 7427.10 78.19 329.90 33.02 7014.43 95 7459.34 80.05 331.50 32.24 7020.52 96 7489.14 80.13 331.50 97 7523.17 80.78 330.70 98 7554.56 83.25 331.30 99 7584.46 83.85 331.70 100 7617.45 83.88 331.40 101 7649.98 83.77 331.30 102 7679.40 83.65 332.60 103 7713.20 83.62 332.40 104 7745.22 83.57 332.30 105 7775.03 83.33 332.50 29.80 34.03 31.39 29.90 32.99 32.53 29.42 33.80 32.02 29.81 7025.64 7031.29 7035.65 7039.01 7042.53 7046.03 7049.26 7053.00 7056.57 7059.97 106 7808.66 83.44 332.30 33.63 7063.85 107 7839.87 85.65 331.20 31.21 7066.82 108 7869.91 88.31 330.50 30.04 7068.40 109 7903.03 91.48 329.90 33.12 7068.46 110 7935.01 93.65 329.40 31.98 7067.03 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qua! (ft) (ft) (ft) (ft) (deg) i00f) type type 1023.76 762.51 -746.16 1066.85 315.62 1053.39 787.66 -761.94 1095.88 315.95 1083.26 813.33 -777.30 1125.03 316.30 1115.44 841.14 -793.55 1156.39 316.67 1147.09 868.75 -809.04 1187.13 317.04 1176.45 894.55 -823.05 1215.57 317.38 1210.00 923.93 -839.27 1248.20 317.75 ~241.08 951.11 -854.33 1278.48 318.07 1270.79 977.22 -868.51 1307.39 318.37 1303.59 1006.06 -884.14 1339.35 318.69 1335.93 1034.44 -899.64 1370.92 318.9'9 1365.17 1060.25 -913.39 1399.44 319.26 1398.76 1090.05 -928.91 1432.15 319.56 1430.58 1118.23 -943.67 1463.20 319.84 1460.20 1144.48 -957.39 1492.12 320.09 1493.60 1524.67 1554.66 1587.76 1619.68 111 7966.00 94.09 330.90 30.99 7064.94 1650.58 112 7998.27 94.00 330.60 32.27 7062.66 1682.76 113 8030.36 93.77 330.20 32.09 7060.48 1714.77 114 8061.52 93.43 330.50 31.16 7058.53 1745.85 115 8095.69 92.45 329.10 34.17 7056.78 1779.95 116 8210.15 92.74 330.36 114.46 7051.59 117 8302.00 91.71 331.85 91.85 7048.03 118 8398.23 92.78 331.89 96.23 7044.26 119 8492.53 91.37 332.71 94.30 7040.84 120 8585.87 92.74 332.58 93.34 7037.50 [(c)2000 Anadrill IDEAL ID6 lB 48] -- -- 1894.21 1985.97 2082.13 2176.36 2269.63 1174.08 -972.87 1201.45 -987.57 1227.64 -1002.19 1256.38 -1018.64 1283.95 -1034.78 1310.77 -1050.17 1338.85 -1065.90 1366.69 -1081.72 1393.72 -1097.10 1423.21'-1114.27 1521.96 -1171.90 1602.31 -1216.25 1687.11 -1261.58 1770.54 -1305.39 1853.39 -1348.25 1524.78 1555.24 1584.77 1617.44 1649.03 13.73 MWD M -- 12.60 MWD M 4.39 MWD M -- 5.58 MWD M 7.55 MWD M 1679.57 1711.34 1742.97 1773.72 1807.51 0.27 MWD M -- 3.00 MWD M 8.09 MWD M -- 2.41 MWD M 0.91 MWD M 1920.86 2011.63 2106.64 2199.74 2291.90 0.46 MWD M 4.41 MWD M -- 0.59 MWD M 0.35 MWD M 1.05 MWD M 320.35 0.68 MWD M 320.58 7.90 MWD M 320.77 9.16 MWD M 320.97 9.74 MWD M -- 321.13 6.96 MWD M -- 321.30 5.03 MWD M 321.48 0.97 MWD M -- 321.64 1.44 MWD M 321.79 1.45 MWD M 321.94 5.00 MWD M 322.40 322.80 323.21 323.60 323.97 1.13 IMP 6-axis 1.97 IMP 6-axis 1.11 IMP 6-axis 1.73 IMP 6-axis 1.47 IMP 6-axis AUG !0 2000 Alaska 0[[ & G~~s Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Repozt 22-Jul-2000 20:40:29 Page 6 of 7 Seq Measured Incl Azimuth Course % depth angle, angle length - (ft) (deg) (deg) (ft) 121 8678.48 91.65 333.54 122 8773.56 92.37 330.33 123 8866.32 91.61 331.50 124 8960.79 93.19 330.56 125 9053.67 91.78 330.88 126 9148.25 91.47 332.47 127 9242.05 92.50 330.85 128 9336.50 89.90 330.55 129 9432.12 89.11 331.71 130 9525.78 89.79 330.61 92.61 95.08 92.76 94.47 92.88 94.58 93.80 94.45 95.62 93.66 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) lOOf) 7033.95 7030.61 7027.39 7023.44 7019.41 7016.73 7013.48 7011.50 7012.33 7013.23 2362.16 2457.16 2549.85 2644.22 2736.99 2831.53 2925.27 3019.66 3115.27 3208.91 131 9618.05 90.86 330.24 92.27 7012.70 3301.15 132 9713.44 89.35 330.74 95.39 7012.53 3396.50 133 9804.88 90.10 331.48 91.44 7012.97 3487.93 134 9900.41 89.42 329.77 95.53 7013.37 3583.43 135 9992.00 90.21 333.85 91.59 7013.66 3675.00 95.00 92.90 93.60 91.91 94.01 136 10087.00 90.96 334.01 137 10179.90 90.00 334.10 138 10273.50 90.89 334.54 139 10365.41 89.97 329.74 140 10459.42 90.69 332.92 141 10552.46 90.41 328.76 142 10649.04 89.35 331.03 143 10743.00 90.45 331.05 144 10837.00 89.21 331.48 145 10930.00 89.59 331.36 146 11023.00 89.83 331.29 147 11118.00 90.31 332.14 148 11214.00 89.59 332.00 149 11308.00 89.83 332.02 150 11406.00 90.55 332.41 [(c)2000 Anadrill IDEAL ID6 lB 48] __ -- 7012.69 7011.91 7011.19 7010.50 7009.96 7009.06 7009.26 7009.43 7009.71 7010.68 7011.15 7011.04 7011.12' 7011.60 7011.27 93.04 96.58 93.96 94.00 93.00 93.00 95.00 96.00 94.00 98.00 3769.94 3862.77 3956.29 4048.16 4142.15 4235.15 4331.66 4425.61 4519.60 4612.59 4705.58 4800.58 4896.58 4990.58 5088.57 1935.89 -1390.17 2019.72 -1434.87 2100.74 -1479.94 2183.31 -1525.65 2264.24 -1571.03 2347.46 -1615.89 2429.97 -1660.38 2512.31 -1706.59 2596.04 -1752.76 2678.08 -1797.93 2758.32 -1843.47 2841.34 -1890.46 2921.39 -1934.63 3004.64 -1981.49 3085.35 -2024.75 3170.68 -2066.50 3254.21 -2107.14 3338.56 -2147.70 3419.79 -2190.63 3502.26 -2235.73 3583.49 -2281.05 3667.03 -2329.49 3749.24 -2374.99 3831.67 -2420.18 3913.33 -2464.66 3994.92 -2509.29 4078.58 -2554.30 4163.39 -2599.27 4246.40 -2643.38 4333.10 -2689.07 2383.33 324.32 1.57 2477.53 324.61 3.46 2569.69 324.84 1.50 2663.54 325.06 1.95 2755.89 325.25 1.56 2849.86 325.46 1.71 2943.06 325.66 2.05 3037.13 325.81 2.77 3132.35 325.97 1.47 3225.63 326.12 1.38 3317.64 326.24 1.23 3412.77 326.36 1.67 3503.91 326.49 1.15 3599.19 326.60 1.93 3690.39 326.73 4.54 3784.65 326.91 0.81 3876.84 327.08 1.04 3969.71 327.25 1.06 4061.26 327.36 5.32 4155.04 327.45 3.47 4247.89 327.52 4.48 4344.38 327.57 2.59 4438.17 327.65 1.17 4531.99 327.72 1.40 4624.79 327.80 0.43 4717.62 4812.41 4908.16 5001.94 5099.69 327.87 327.94 328.02 328.10 328.18 Srvy Tool tool qual type type IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis 0.27 IMP 6-axis 1.03 IMP 6-axis 0.76 IMP 6-axis 0.26 IMP 6-axis 0.84 IMP 6-axis RECEIVED AUG 1 0 2000 Alaska Oil & ANADRILL SCHLUMBERGER Survey Report 22-Jul-2000 20:40:29 Page 7 of 7 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 151 11502.00 91.44 333.52 152 11599.00 91.78 334.45 153 11695.00 92.06 334.83 154 11792.00 89.97 331.44 155 11888.00 90.72 333.28 156 11985.00 90.41 331.22 157 12081.00 90.41 330.74 158 12177.00 90.62 330.49 159 12274.00 89.28 331.59. 160 12370.00 89.97 331.45 161 12466.00 90.38 329.70 162 12563.00 90.79 331.23 163 12'660.00 89.59 329.12 164 12755.00 90.27 329.58 165 12849.00 90.86 329.19 TVD depth (ft) Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) I00f) type type 96.00 7009.60 5184.54 4418.59 -2732.69 5195.34 328.27 97.00 7006.88 5281.44 4505.73 -2775.22 5291.83 328.37 96.00 7003.66 5377.28 4592.43 -2816.32 5387.21 328.48 97.00 7001.94 5474.23 4678.93 -2860.13 5483.86 328.56 96.00 7001.36 5570.22 4763.97 -2904.67 5579.65 328,63 7000.41 6999.72 6998.86 6998.94 6999.57 97.00 96.00 96.00 97.00 96.00 5667.21 4849.80 -2949.83 5676.45 328.69 5763.19 4933.75 -2996.40 5772.37 328.73 5859.16 5017.39 -3043.50 5868.31 328.76 5956.15 5102.26 -3090.46 5965.23 328.80 6052.14 5186.64 -3136.24 6061.13 328.84 96.00 6999.28 6148.11 5270.25 -3183.40 6157.08 328.87 97.00 6998.29 6245.07 5354.64 -3231.22 6254.03 328.89 97.00 6997.97 6342.01 5438.79 -3279.45 6351.00 328.91 95.00 6998.08 6436.91 5520.51 -3327.88 6446.00 328.92 94.00 6997.16 6530.81 5601.41 -3375.75 6539.99 328.92 166 12943.00 89.35 329.04 94.00 6996.98 167 13038.00 90.10 327.39 95.00 6997.44 '168 13132.00 88.28 329.25 94.00 6998.77 169 13227.00 87.91 328.47 95.00 7001.93 170 13323.00 88.42 328.93 96.00 7005.00 171 13394.00 86.84 328.74 Projected to TD 172 13450.00 86.84 328.74 6624.69 5682.07 -3424.00 6633.99 328.93 6719.48 5762.82 -3474.04 6728.97 328.92 6813.28 5842.80 -3523.40 6822.95 328.91 6908.09 5924.07 -3572.50 6917.90 328.91 7003.88 6006.05 -3622.35 7013.85 328.91 71.00 7007.94 7074.71 6066.75 -3659.06 7084.78 328.90 7011.02 56.00 7130.54 6114.55 -3688.07 7140.70 328.90 1.48 IMP 6-axis 1.02 IMP 6-axis 0.49 IMP 6-axis 4.11 IMP 6-axis 2.07 IMP 6-axis 2.15 IMP 6-axis 0.50 IMP 6-axis 0.34 IMP 6-axis 1.79 IMP 6-axis 0.73 IMP 6-axis 1.87 IMP 6-axis 1.63 IMP 6-axis 2.50 IMP 6-axis 0.86 IMP 6-axis 0.75 IMP 6-axis 1.61 IMP 6-axis 1.91 IMP 6-axis 2.77 IMP 6-axis 0.91 IMP 6-axis 0.72 IMP 6-axis 2.24 IMP 6-axis 0.00 Projection [(c)2000 Anadrill IDEAL ID6 lB 48] RECE[VED AUG ] 0 Alaska Oi~ a Gas CoF,,$. Commissim', Anchorage Client ................... : ARCO Alaska, Inc. Field .................... : Colville River Well ..................... : CD1-35 API number ............... : 50-103-20297-00 Engineer ................. : Dammeyer Rig: ..................... : Doyon 19 State: ................... : Alaska ANADRILL SCHLUMBERGER Survey report Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Rig Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 56.50 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: 317.11 degrees 13-May-99 13:08:42 Page 1 of 5 Spud date ................ : 06-May-99 Last survey date ......... : 13-May-99 Total accepted surveys...: 114 MD of first survey ....... : 115.00 ft MD of last survey ........ : 8095.69 ft ORIGINAL RECEIVED , r IAy 2 4 1999 Geoma gne t i c da t a ~$ka 0il & Gas C~s. Magnetic model ........... : BGGM version 1997 Magnetic date ............ : 01-Aug-1998 Magnetic field strength..: 1143.99 HCNT Magnetic dec (+E/W-) ..... : 26.36 degrees Magnetic dip ............. : 80.49 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1143.99 HCNT Reference Dip ............ : 80.49 degrees Tolerance of G ........... : (+/-) 3.00 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Corrections Magnetic dec (+E/W-) ..... : 26.36 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.36 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 (c)1999 Anadrill IDEAL ID5 0C 01R] ~ADRILL SCHLUMBERGER Survey Report 13-May-99 13:08:42 Page 2 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 115.00 0.00 0.0 2 185.03 0.17 138.6 3 293.56 1.64 259.9 4 379.89 3.44 255.5 5 471.08 3.40 274.5 6 562.69 5.05 293.1 7 650.74 6.16 287.2 8 740.83 7.24 277.2 9 826.72 8.44 269.3 10 915.91 8.98 266.3 11 1005.97 8.72 264.8 12 1096.13 8.68 266.5 13 1191.70 8.41 266.0 14 1286.52 7.42 267.3 15 1382.80 4.33 272.9 16 1477.21 1.97 281.6 17 1572.35 0.74 340.5 18 1666.92 0.79 337.3 19 1762.39 1.22 113.7 20 1858.84 1.28 115.6 21 1953.81 0.51 119.4 22 2049.12 0.37 129.4 23 2144.14 0.52 110.4 24 2240.02 0.40 93.7 25 2334.97 0.57 105.9 26 2348.84 0.59 115.7 27 2426.38 0.21 108.6 28 2521.31 0.26 52.7 29 2616.65 0.32 71.5 30 2712.98 0.26 49.2 0.00 70.00 108.60 86.30 91.20 91.60 88.00 90.10 85.90 89.20 90.10 90.10 95.60 94.80 96.30 94.40 95.10 94.60 95.50 96.40 95,00 95.30 95.00 95.90 95.00 13.80 77.60 94.90 95.30 96.40 TVD depth (ft) 115.00 185.00 293.59 379.80 470.84 562.19 649.77 739.26 824.35 912.52 1001.55 1090.62 1185.15 1279.05 1374.83 1469.08 1564.16 1658.75 1754.24 1850.62 1945.61 2040.91 2135.90 2231.80 2326.80 2340.60 2418.19 2513.09 2608.39 2704.79 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 0.00 0.00 0 -0.t0 -0.08 0 0.58 -0.47 -1 2.48 -1.34 -5 5.77 -1.81 -10 .00 .07 .35 .08 .42 11.45 -0.01 -16.84 19.08 2.90 -24.91 27.63 5.04 -35.16 36.01 5.64 -46.84 44.81 5.12 -60.33 53.43 4.04 -74.15 61.92 3.01 -87.74 70.89 2.08 -101.91 79.19 1.31 -114.94 85.81 1.20 -124.79 89.68 1.71 91.58 2.61 92.75 3.79 92.44 3.99 90.49 3.11 89.10 2.45 88.39 2.04 87.70 1.70 87.07 1.52 86.43 1.37 86.30 1.32 85.81 1.11 85.63 1.18 85.50 1.40 85.38 1.62 -129 -131 -132 -131 -129 .94 .74 .20 .52 .61 -128 -127 -127 -126 -125 .29 .68 .04 .30 .51 -125 -124 -124 -124 -123 .38 .89 .55 .12 .70 0.00 0.10 1.43 5.25 10.58 0.00 138.60 250.82 255.26 260.15 16.84 25.08 35.52 47.18 60.55 269.95 276.64 278.16 276.87 274.85 74.26 87.79 101.93 114.95 124.79 273.12 271.96 271.17 270.65 270.55 129.95 131.77 132.25 131.58 129.65 270.75 271.14 271.64 271.74 271.38 128.31 127.69 127.05 126.30 125.52 271.09 270.92 270.77 270.69 270.63 125.39 124.89 124.55 124.13 123.71 270.60 270.51 270.54 270.64 270.75 0.00 0.24 1.60 2.10 1.24 2.32 1.42 1.76 1.87 0.79 0.39 0.29 0.29 1.06 3.26 2.54 1.80 0.07 1.96 0.08 0.81 0.17 0.22 0.19 0.21 0.73 0.49 0.24 0.12 0.13 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 -- 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 (c)1999 Anadrill IDEAL ID5 0C 01R] ~ADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 13-May-99 13:08:42 31 2808.06 0.24 77.9 32 2903.42 0.23 48.3 33 2998.11 0.26 66.1 34 3094.14 0.09 35.7 35 3188.73 0.08 54.6 Page 36 3282.78 0.19 351.7 37 3378.21 0.20 16.2 38 3473.47 0.06 111.7 39 3568.41 0.09 69.5 40 3663.58 0.04 311.9 3 of 5 41 3759.63 0.06 326.0 42 3854.51 0.09 277.1 43 3947.45 0.09 138.9 44 4042.67 0.19 146.6 45 4137.73 0.09 170.3 Course TVD Vertical Displ Displ Total At DLS Srvy Tool length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 46 4232.60 0.03 121.0 47 4326.83 0.03 5.3 48 4422.42 0.09 2.2 49 4518.11 0.11 29.1 50 4613.69 0.00 26.4 95.10 95.30 94.70 96.00 94.60 51 4709.37 0.11 229.5 52 4804.69 0.09 236.0 53 4899.83 0.29 239.6 54 4997.25 0.17 169.9 55 5091.70 0.18 97.1 94.10 95.40 95.30 94.90 95.20 56 5187.07 2.51 307.6 57 5282.48 5.37 313.2 58 5376.94 8.15 317.9 59 5473.16 10.47 321.1 60 5568.29 13.07 320.4 96.00 94.90 93.00 95.20 95.00 2799.89 2895.19 2989.89 3085.89 3180.49 3274.59 3369.99 3465.29 3560.19 3655.39 3751.39 3846.29 3939.29 4034.49 4129.49 4224.39 4318.59 4414.19 4509.89 4605.49 4701.19 4796.49 4891.58 4989.08 5083.48 5178.86 5274.02 5367.76 5462.78 5555.87 94.90 94.20 95.60 95.70 95.60 85.27 1.81 85.17 1.98 85.09 2.19 85.04 2.34 85.04 2.44 85.16 2.63 85.38 2.95 85.42 3.09 85.34 3.10 85.35 3.14 85.43 3.21 85.54 3.26 85.52 3.21 85.29 3.02 85.07 2.82 84.99 2.73 84.98 2.74 85.05 2.84 85.13 3.00 85.16 3.08 85.16 3.02 85.18 2.92 85.24 2.76 85.17 2.49 84.94 2.33 86.89 3.59 93.40 7.92 104.50 15.91 120.06 27.79 139.42 42.80 -123.35 -123.01 -122.67 -122.43 -122.33 -122.30 -122.27 -122.18 -122.07 -122.02 -122.07 -122.18 -122.20 -122.06 -121.96 -121.93 -121.91 -121.90 -121.85 -121.81 -121.88 -122.01 -122.28 -122.47 -122.30 -123.80 -128.71 -136.42 -146.49 -158.78 95.70 95.30 95.10 97.50 94.40 123.36 123.02 122.69 122.45 122.35 122.33 122.31 122.22 122.10 122.06 122.12 122.22 122.24 122.10 122.00 121.96 121.94 121.94 121.89 121.85 121.92 122.05 122.31 122.49 122.32 123.85 128.96 137.35 149.11 164.44 270.84 270.92 271.02 271.09 271.14 271.23 271.38 271.45 271.45 271.48 271.51 271.53 271.51 271.42 271.32 271.28 271.29 271.34 271.41 271.45 271.42 271.37 271.29 271.16 271.09 271.66 273.52 276.65 280.74 285.09 95.40 95.40 94.40 96.30 95.10 0.13 0.13 0.09 0.20 0.03 0.18 0.09 0.22 0.06 0.12 0.02 0.07 0.18 0.11 0.12 0.08 0.05 0.06 0.05 0.12 0.11 0.02 0.21 0.29 0.22 2.80 3.02 3.00 2.47 2.74 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 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 (c) 1999 Anadrill IDEAL ID5 0C 01RI ~ADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) Course length (ft) 61 5663.50 14.20 317.6 62 5758.72 16.30 316.0 63 5851.16 17.85 318.4 64 5946.09 20.20 318.0 65 6041.17 24.17 317.0 95.20 95.20 92.50 94.90 95.10 66 6136.37 28.80 316.3 67 6231.92 31.70 315.1 68 6327.05 32.61 316.1 69 6424.12 32.48 317.0 70 6519.20 31.92 318.9 95.20 95.50 95.10 97.10 95.10 71 6613.12 31.45 318.4 72 6673.87 31.27 318.3 73 6727.44 30.92 317.9 74 6822.75 31.14 319.7 75 6856.38 32.07 319.9 93.90 60.80 53.50 95.40 33.60 76 6888.30 34.87 321.9 77 6918.97 38.12 323.5 78 6951.98 41.88 325.1 79 6983.67 44.80 326.5 80 7014.26 47.18 326.8 31.90 30.70 33.00 31.70 30.60 81 7046.53 50.60 327.5 82 7078.67 53.54 327.5 83 7109.10 56.07 326.4 84 7141.26 58.17 325.9 85 7173.41 58.48 325.5 32.20 32.20 30.40 32.20 32.10 86 7204.68 58.35 326.1 87 7236.76 60.12 326.0 88 7268.72 63.47 325.7 89 7297.41 66.98 326.2 90 7332.25 71.69 327.1 31.30 32.10 31.90 28.70 34.90 TVD depth (ft) 5648.39 5740.23 5828.65 5918.36 6006.41 6091.59 6174.08 6254.59 6336.45 6416.92 6496.83 6548.74 6594.56 6676.31 6704.92 6731.53 6756.21 6781.48 6804.54 6825.79 6846.96 6866.75 6884.27 6901.75 6918.61 6935.00 6951.42 6966.50 6978.52 6990.84 13-May-99 13:08:42 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 161.84 59.72 186.88 77.95 214.03 97.89 244.96 120.95 280.86 147.40 323.30 178.25 371.39 212.66 421.98 248.82 474.22 286.74 524.88 324.37 574.18 361.39 605.82 385.03 633.44 405.60 682.60 442.60 700.18 456.05 717.73 469.71 735.90 484.23 756.94 501.46 778.44 519.46 800.14 537.84 824.03 558.22 849.01 579.64 873.48 600.46 900.19 622.91 927.20 645.48 -173.51 183.50 288.99 1.37 -190.67 205.99 292.24 2.25 -209.10 230.88 295.09 1.84 -229.72 259.62 297.77 2.48 -254.00 293.67 300.13 4.19 -283.15 334.58 302.19 4.87 -316.76 381.52 303.88 3.10 -352.16 431.20 305.24 1.11 -388.09 482.53 306.46 0.52 -422.03 532.28 307.55 1.22 -454.61 580.76 308.48 0.57 -475.64 611.95 308.99 0.31 -494.09 639.25 309.38 0.76 -526.48 687.81 310.05 1.00 -537.85 705.17 310.30 2.79 -548.93 722.46 310.55 9.43 -559.98 740.31 310.85 11.03 -572.35 760.95 311.22 11.81 -584.57 782.02 311.62 9.70 -596.67 803.30 312.03 7.81 -609.82 826.74 312.47 10.75 -623.47 851.29 312.91 9.13 -637.02 875.41 313.31 8.83 -652.08 901.79 313.69 6.65 -667.48 928.53 314.04 1.43 -682.46 954.65 314.37 1.68 -697.87 981.68 314.69 5.52 -713.65 1009.27 315.00 10.53 -728.23 1034.86 315.28 12.33 -746.18 1066.88 315.62 13.71 953.56 667.53 980.80 690.41 1008.59 713.67 1034.33 735.26 1066.52 762.53 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 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 (c)1999 Anadrill IDEAL ID5 0C 01R] NADRILL SCHLUMBERGER Survey Report 13-May-99 13:08:42 Page 5 of 5 eq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 7363.23 75.28 328.7 92 7394.08 76.39 329.5 93 7427.10 78.19 329.9 94 7459.34 80.05 331.5 95 7489.14 80.13 331.5 96 7523.17 80.78 330.7 97 7554.56 83.25 331.3 98 7584.46 83.85 331.7 99 7617.45 83.88 331.4 00 7649.98 83.77 331.3 101 7679.40 83.65 332.6 102 7713.20 83.62 332.4 103 7745.22 83.57 332.3 104 7775.03 83.33 332.5 105 7808.66 83.44 332.3 106 7839.87 85.65 331.2 107 7869.91 88.31 330.5 108 7903.03 91.48 329.9 109 7935.01 93.65 329.4 110 7966.00 94.09 330.9 111 7998.27 94.00 330.6 '! 112 8030.36 93.77 330.2 113 8061.52 93.43 330.5 114 8095.69 92.45 329.1 ,asr 115 Survey Projected to TD 8168.00 92.45 329.1 30.90 30.90 33.00 32.20 29.80 34.10 31.40 29.90 33.00 32.50 29.40 33.80 32.00 29.80 33.70 31.20 30.00 33.10 32.00 31.00 32.30 32.10 31.10 34.20 72.30 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 6999.62 1095.62 787.63 -761.91 1095.84 7007.18 1124.92 813.33 -777.30 1125.04 7014.44 1156.34 841.13 -793.54 1156.37 7020.52 1187.07 868.70 -809.01 1187.07 7025.65 1215.51 894.50 -823.02 1215.52 7031.30 1248.14 923.94 -839.27 1248.21 7035.66 1278.32 951.13 -854.34 1278.50 7039.02 1307.10 977.24 -868.52 1307.42 7042.55 1338.87 1006.09 -884.15 1339.38 7046.05 1370.19 1034.45 -899.64 1370.93 7049.27 1398.44 1060.24 -913.39 1399.42 7053.01 1430.83 1090.03 -928.90 1432.14 7056.58 1461.51 1118.20 -943.65 1463.17 7059.98 1490.07 1144.44 -957.37 1492.08 7063.87 1522.36 1174.11 -972.88 1524.80 7066.83 1552.40 1201.46 -987.58 1555.26 7068.41 1581.50 1227.62 -1002.17 1584.74 7068.47 1613.74 1256.34 -1018.62 1617.40 7067.04 1644.94 1283.93 -1034.77 1649.01 7064.95 1675.07 1310.75 -1050.16 1679.56 7062.67 1706.38 1338.86 -1065.91 1711.35 7060.49 1737.55 1366.71 -1081.73 1742.99 7058.54 1767.77 1393.69 -1097.08 1773.68 7056.79 1801.08 1423.20 -1114.26 1807.51 7053.70 1871.74 1485.19 -1151.36 Srvy tool type 315.95 12.63 MWD 316.30 4.38 MWD 316.67 5.58 MWD 317.04 7.56 MWD 317.38 0.27 MWD 317.75 3.00 MWD 318.07 8.09 MWD 318.37 2.41 MWD 318.69 0.91 MWD 318.99 0.46 MWD 319.26 4.41 MWD 319.56 0.59 MWD 319.84 0.35 MWD 320.09 1.05 MWD 320.35 0.67 MWD 320.58 7.91 MWD 320.77 9.17 MWD 320.97 9.75 MWD 321.13 6.96 MWD 321.30 5.03 MWD 321.48 0.97 MWD 321.64 1.43 MWD 321.79 1.46 MWD 321.94 4.99 MWD 1879.20 322.22 0.00 MWD M 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 (c)1999 Anadrill IDEAL ID5 0C 01R] Scb berger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 5OO Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine 9/11/00 Color Well Job # Log Description Date BL Sepia Prints CD CD1-3S ' .'-~'~ I ~ 20348 GR/CDR/ADN/IMPULSE 000723 1 CD1-35 20348 ,/ ft~--CDR"'~'~ i /~O/~J~L~ /'~/~'_~ .,~ 000723 I 1 CD1-35 20348 ~~/ ~ ['''""( IC~ 000723 I 1 .. .~ .. ..... ~. ,. : ~ i~ I~ MWDILWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CD1-35 [C~C~, O~b Date Dispatche 7-Aug-00 Installation/Rig Doyon 19 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 Received By: Please sign and return to: Anaddll LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 rosei~.~anchorage.anad dll.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 · , :~i~,~:~,~ :ii: i'.i~ i: i..:~:!:::: :~. :::. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ '" Suspend _ Operatio'nal shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _ Change approved program _X Pull tubing _ Variance _ Perforate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 37 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Colville River Unit 4. Location of well at surface 8. Well number 466' FNL, 2335' FWL, Sec. 5, T11 N, R5E, UM CD1-35 At top of productive interval 9. Permit number / approval number 645' FSL, 1377' FWL, Sec. 32, T12N, R5E, UM 199-38 / 300-158 At effective depth 10. APl number 50-103-20297-00 At total depth 11. Field / Pool 4913' FNL, 1329' FEL, Sec. 30, T12N, R5E, UM (ASP: 382167, 5981835) Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 13450 feet Plugs (measured) true vertical 7011 feetORIGINAL Effective depth: measured 13450 feet Junk (measured) true vertical 7011 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 77' 16" 10 cu. Yds. Portland Type 3 114' 114' Surface 2359' 9.625" 744 sx AS IIIL, 230 sx Class G 2396' 2388' Production 8121' 7" 215 sx Class G 8158' 7053' Liner Perforation depth: measured N/A ~ true vertical N/A jul_ 2 O Tubing (size, grade, and measured depth N/A Alloh0rsge Packers & SSSV (type & measured depth) N/A 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: July 25, 2000 16. If proposal was verbally approved Oil __X Gas__ Suspended __ r~ame 01' approver Date approved Service__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Brian Robertson 265-6034 Signed ,,~.,'/-,--~- 'U/~'.. ~'~-2 Title: Drilling Team Leader Date G. C. Alvord Prepared by Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity __ BOP Test__ Location clearance --I ~---~0 Mechanical Integrity Test__ Subsequent form required 10- ~ ¢ '1' Apl:)roved by order of the Commission 'O"IGIN,,~L ,.~l~lM,~r'~ ,~ Commissioner Date ~ ]~ l0 0 ............ Form 10-403 Rev 06/15/88 · D Taylor Seamount Approved Copy Returned SUBMIT IN TRIPLICATE PHi ,LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 July 27, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: CD1-35 Application for Sundry Approval Dear Mr. Commissioner: Enclosed is a sundry application to request a change in the original permit to drill to extend the bottomhole location. If there are any questions, please call me at 265-6120 or Brian Robertson at 265-6034. Sincerely, G. C. Alvord Alpine Drilling Team Leader Phillips Drilling GCA/skad file:///Untitled Sharon Allsup-Drake wrote: Dear Mr. Wondzell - this memo is to clarify the Sundry Application for CD 1-35 we sent to you earlier this week. The old bottomhole location was at 2607' FNL, 291' FWL, Sec. 32, T12N, R5E, UM at gi6g' The new bottomhole location we are requesting is 4913' FNL, 1329' FEL, at total depth of 13450' MD. Sec. 30, T12N, R5E, UM I hope this will resolve any questions about the new bottomhole location. thanks, Sharon 1 of 1 8/3/00 11:42 AM CD 1-3 5 TD Extension Subject: CD1-35 TD Extension Date: Mon, 24 Jul 2000 16:54:29 -0900 From: "Chip Alvord" <CALVORD~ppco.com> To: Blair Wondzell <blair_wondzell~admin. state.ak.us> CC: "Brian Robertson" <BROBERT4~ppco.com> Blair, Doyon 19 drilled the 6-1/8" horizontal section of Alpine well CD1-35 to a total depth of 13,450'MD. The original TD of this well was permitted to a depth of 12,163'MD and over the past weekend Phillip's had been granted verbal approval to extend the well by up to 1,500'. Please call if you need additional information regarding this follow up. Regards, Chip Alvord Alpine Drilling Team Leader 1 of 1 8/3/00 11:55 AM Re: CD1-35 TD Extension Subject: Re: CD1-35 TD Extension Date: Tue, 25 Jul 2000 08:28:05 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Chip Alvord <CALVORD~ppco.com> CC: Brian Robertson <BROBERT4~ppco.com>, Tom Maunder <tom_rnaunder~admin. state.ak.us> Good Morning Chip, Thanks for the infromation. We think that for this change you need to file a 10-403 per 20 AAC 25.015(b). Thanks, Blair Chip Alvord wrote: > Blair, > Doyon 19 drilled the 6-1/8" horizontal section of Alpine well CD1-35 to a total > depth of 13,450'MD. The original TD of this well was permitted to a depth of > 12,163'MD and over the past weekend Phillip's had been granted verbal approval > to extend the well by up to 1,500' Please call if you need additional > information regarding this follow up. > Regards, > Chip Alvord > Alpine Drilling Team Leader 1 of 1 7/25/00 9:59 AM Re: CDI,~5 extension of planned TD, Permit # 199,03~8., APl # 50 -103-20297 Subject: Re: CD1-35 extension of planned TD, Permit # 199-038, APl # 50 -103-20297 Date: Thu, 20 Jul 2000 10:55:49 -0900 From: "Brian Robertson" <BROBERT4~ppco.com> To: "Chip Alvord" <CALVORD@ppco.com>, "Douglas G Knock" <DKNOCK~ppco.com> CC: Blair_Wondzell@admin. state.ak.us Chip, No spacing exception needed. The coordinates for the possible extension are in the heart of the Alpine Unit. Please send Blair an update on Monday morning. Regards Brian Forwarded by Brian Robertson/AAI/ARCO on 07/20/2000 10:50 Blair Wondzell <blair wondzell@admin.state.ak.us> on 07/20/2000 09:47:39 AM To: Brian Robertson/AAI/ARCO@Arco cc: Tom Maunder@admin.state.ak.us, Chip Alvord/AAI/ARCO@Arco, Douglas G Knock/AAI/ARCO@Arco Subject: Re: CD1-35 extension of planned TD, Permit # 199-038, API# 50-103-20297 Brian, Thanks for the "heads up". You have our approval provided that a spacing provision is not violated. Please drop me an email line Monday as to where you ended up. Thanks, Blair Brian Robertson wrote: > Blair, > Please be aware that there is a low probability (<20%) that we may wish to > extend the TD length on well CD1-35. The coordinates below, are for a 1000' > extension of the horizontal section. This represents the absolution maximum that > we believe we could still find reservoir section. CD1-35 is 'heading' > approximately north west and it is anticipated that it will encounter the > northern limits of economic Alpine sand. > The well is presently over 2300' into the planned 4000' horizontal section. We > anticipate that we will reach TD tomorrow evening. Please advise, if you would > like us to submit a sundry today to cover this low probability event. > Alternatively, is it possible to obtain provisional approval, and if we do > extend, we can follow up with the paperwork next week? > Regards > Brian Robertson - Alpine Drilling Engineer 10: 14 > AM ........ > Douglas G Knock > 07/20/2000 10:09 AM Forwarded by Brian Robertson/AAI/ARCO on 07/20/2000 1 of 2 7/20/00 11:40 AM Re,: CDI-~5 extension of planned TD, Permit # 199-0~3.8, APl # 50 -103-20297 To: Brian Robertson/AAI/ARCOSARCO CC: Subject: CD1-35 extension of planned TD Brian, the x and y for a possible 1000' extension is x = 382344 and y = 5981607 or S30/T12N/R5E, 5138 FNL, 1150 FEL 2 of 2 7/20/00 11:40 AM STATE OF ALASKA .ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ .............. ~u~p~n~ ........................................ Operational shutdown .~ ....................................................... Re-enter suspended well - ......................................... Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _ Change approved program _X Pull tubing _ Vadance _ Perforate _ Annular Injection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) .P..hillips Alaska, Inc. Development X RKB 56' feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service_ Colville River Unit 4. Location of well at surface ,,/ ,/ ,/ 8. Well number 466' FNL, 2335' FWL, Sec.5, T11 N, RSE, UM CD1-35 At target (Top Alpine)) 9. Permit number / approval number 645' FSL, 1377' FWL, Sec.32, T12N, R5E, UM per APD 199-038 '/ At effective depth 10. APl number !50-103-20297-00 At REVISED total depth 11. Field / Pool 739' FNL, 686' FEL, Sec.31, T12N, RSE, UM requested new TD Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 8168 feet true vertical 7054 feet Effective depth: measured 8158 feet landing collar in 7" casing. true vertical 7053 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114 Surface 2359' 9.625" 744 sx ASL3, 230 sx Class G 2396' 2388' Production 8123' 7" 215 sx Class G 8158' 7053' Per the attached memo. CD1-35 has been temporarily suspended at the 7" casing point. It is requested that the horizontal section be extended past the point proposed in the original APD. In addition, the proposed completion plan has been altered to reflect current completion practices as opposed to what was envisaged at the time of writing the permit. The new TD coordinates for the well will be as indicated above. 0RiGINAL 000 ........... , ~ Gas Cr~, C0n'~fn~SSlOn A~.ch0r~e · !13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: July 12, 2000 16. If proposal was verbally approved Oil X Gas __ Suspended __ i Name of approver Date approved Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~ ,,-Yr ,,,- ~ .... Title- Drilling Team Leader Date FOR COMMISSION USE ONLY Conditions of~proval: Notify Commission so representative may witness lApproval no. Plug integrity BOP Test'~ Location clearance,. I 300 Mechanical Integrity Test __ Subsequent form required 10- q _A__P_proved by orde..r...o.f the Oommission D Taylor Seamounl Commissioner Date .... Form 10-403 Rev 06/15/88 · Approved Gop¥. Returned SUBMIT IN TRIPLICATE . . . . 7. 8. 9. 10. 11. 12. 13. 14. Note: CD1-35 Program ..dtline (Production Hole and Com~..=tion Operations) Move on Doyon 19. Remove the BPV and install the 2-way check. Remove tubing head adapter assembly. Install BOPE. Pressure test BOPE to 3500 psi. Recover the 2-way check. Remove the tubing hanger and single joint of tubing. Make up the drilling assembly. RIH and tag up on the float collar at 8074'. Displace the well to 9.2 ppg 'clean out' mud. Pressure test casing to 3500 psi / 30 mins. Drill out the float equipment and 20' of new formation. Perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off to drill ahead is 11.5 ppg EMW. Displace the well to 9.2 ppg FIo-Pro drill in fluid. Drill 6 1/8" horizontal section to well TD at 12163' MD/7001' TVD. Displace the well to 9.2 ppg brine and pull out of hole. ~,~,~ Run 4 Y2, 12.6 #, L-80 tubing with S-3 packer, gas lift mandrels (bottom with DCK-2 shear valve, others with dummy valves), BAL-O ported SSSV nipple (packing sleeve installed) and control line. M/U hanger and pressure test the control line to 5000 psi. Land hanger. Back out landing joint. Install 2-way check with rods. M/U landing joint and test hanger seals to 5000 psi. Nipple down BOP. Install wellhead adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2-way check with lubricator. Drop RHC ball and set packer. Test tubing to 3500 psi / 30 mins. Test casing annulus to 3500 psi / 30 mins. (hold 2500 psi tubing pressure to avoid shearing out the DCK-2 valve). Bleed off tubing pressure to shear out the DCK-2 valve. Circulate in 9.6 ppg inhibited brine and sufficient diesel to fill the tubing to the lowermost gas lift mandrel plus provide 2000' TVD of diesel freeze protection on the annulus. Set BPV and secure well. Move rig off. A slickline unit will return to the well to remove the packing sleeve and RHC nipple prior to preparing the well for production. This will be done after the rig moves off location. Colville River Field CD1-35 Temporary Suspension Schematic (as built) Wellhead installed with tubing hanger and BPV set and pressure tested to 3500 psi 1 joint of tubing and WEG below hanger Suspended 5/15/99 16" Conductor to 114' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2396' MD / 2388' TVD cemented to surface 9.7 ppg drilling mud in annulus 9.2 ppg brine with diesel freeze protection to 1200' TVD. Landing collar at 8074' (plug not bumped) Suspension TD at 8168' MD / 7054' TVD TOC at 6870' MD 6716' TVD 7" 26 ppf L-80 R3 BTC-Mod Production Casing at 8158' MD / 7053' TVD @ 92 deg Colville River Field CD1-35 Production Well Completion Plan iiiiiiiiiiiii ~ i~iiii~i~i~i 16" Conductor to 114' 9-5/8" Tam Port co arlliiiiil I ,lO45I I I I~il 4-1/2 Camco BAL-O SSSV N,pple (3.8 ID) at 1700' TVD = 1877' MD ! I I I II liiiiiiil ' Isolation Sleeve with DB-6 No-Go Lock (3.812" OD)run in profile ~ I I I I ~ SurfaceCasin~ @ 2396' MD / 2388' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix' 9.6 ppg KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Completion Tubing Supended with diesel to lowest GLM MD TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2" tubing joints (2) HES "X" (3.813" ID) 35' 35' 1708' 1700' 3408' 3400' 5208' 5200' 7073' 6863' 7142' 6902' Calculated TOC at 6870' MD 4-1/2" tubing joint (1) Baker S3 Packer 7174' 6919' 4-1/2" tubing joint (2) , HES "XN" (3 725" ID) 7239' 6953 \ Camco KBG-2 GLM (3.909" ID) · \ & 1" Camco DCK-2 Shear Valve 4-t/2" 10' pup joint \Pinned for casing side shear @ +/- 2000 psi WEG (+/- 62 deg) 7250' 6958' ~set 2 joints above the X landing nipple .~,x ~ Run 1 per joinI Weatherford, thermal centra izers ~,;,~ ~ between 4500 TVD (:4508 MD)and 2396 MD ~ ~ ~ ~- (approx. 68 in total). 12163' MD / 7" 26 ppf L-80 BTC Mod Production Casing @ 8158' MD / 7053' TVD @ 92 deg PHILLIPS Alaska, Inc. Sfruofure : CD#1 Well: 35 Field : Alpine Field Looafion : North Slope, Alaska <- Wesf (feet) 4000 5750 3500 5250 5000 2750 2500 2250 2000 1750 1500 1250 1000 750 500 250 0 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I CD1-55 TD LO CATI 0 N: 739' FNL, 686' FEL SEC. 31, T12N, RSE 7001 TD - Casing Pt 331.96 AZIMUTH 5847' (TO TD) ==*Plane of Proposal=== 69 \ \ %4300 \ \ 690b r-~ ~o 4-1 O0 ~l.~J x \ CD1-55 INTERM PT 7044 ~ \o x. LOCATION: ~70~, \ "% 3900 2012' FS~ 652' ~L ~~ 65~ .. SEC. 52, T12N, SE_ ~ ~ ~ ~ ~ 5700 5 ..... ~ ~900 ~ 610~ % ~5500 Begin ~nol Drp/Trn ~ X 590~. x x~37~ 'x. ~%3300 ~ ~ 570m X ~ ~5700 ~ ~ ~3500 55~ ~ ~ X ~,uu .... X ~ 4900%% &2700 ~ ~.~7054 - ~. 4~00 % 4700x X~5~ ~ x~4500 x .7~ '~-x 2000 55OO 5250 5OOO 4750 45OO 4250 4000 5750 5500 5250 5000 2750 2500 225O 2000 1750 1500 1000 Created by bmichael For: B ROBERTSON Dote plotted: 6-Jun-2000 Plot Reference is 3,5 Vereioni~6. Coordinates ore in feet reference slot ~55. True Ver[;col ~pthe ore r~erence RKB (Doyon ~19). INT~Q PHILLIPS Alaska, Inc. Structure: CD#1 Well: 55 Field : Alpine Field Location: North Slope, Ah3sko 331.96 AZIMUTH 5847' (TO TD) ***Plane of Proposal*** 2.000 6600 6800 7000 7200 FINAL ANGLE .,...,~,.~? 4:,o 90.30 DEG ,~.. ,~.. 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 II I I I I I I I I I I ! I I I I I 1400 1600 1800 2000 2200 2400 2600 2800 3000 ,:3200 5400 5600 5800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 Verticol Section (feet) -> Azirnufh 551.96 with reference 0.00 N, 0.00 E from slot #55 Creoted by bmichoel For: B ROBERTSON Oote plotted: 6-dun-2000 Plot Reference ;e 55 Versional6. Coordinates are in feet reference alot ~135. True Vertical Depths ore reference RKB (Doyon ~!19 INTKQ PHILLIPS Alaska, Inc. Structure: CD#1 Field: Alpine Field Well : 35 Location: North Slope, Alaska PROFILE COMMENT DATA Point MD Inc Dir TVD North East V. Sect Deg/1 O0 KOP - Csg Pt. 81 68.00 92.45 529.10 7053.68 1485.20 -1151.57 1852.11 0.00 EOC 8291.65 92.02 551.54 7048.86 1592.55 -1212.54 1975.60 2.00 Begin Finol Drp/Trn 9121.04 92.02 331.54 7019.59 2321.22 -1607.57 2804.46 0.00 I nterm Pt. - EOC 9298.41 90.30 551.96 7016.00 2477.45 -1691.50 2981.78 1.00 TD - Casing Pt 12165.27 90.50 551.96 7001.00 5006.01 -3058.09 5846.57 0.00 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 13, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Change the Well Program: CD1-357 Permit No. 199-387 APl No. 50-103-20297 Dear Sirs: Phillips Alaska, Inc. hereby requests approval to modify the program on production well CD1-35. These modifications relate to: a. b. An extension of the length of the horizontal section over what was originally proposed. The new planned bottom hole location is 739' FNL, 686' FEL, Sec 31, T12N, R5E. A modified completion configuration. This reflects current completion practices as opposed to what was envisaged at the time the permit was submitted. Please find attached form 10-403 plus the following information: a. An outline program. A suspension schematic showing the current well status. A proposed final completion drawing. Directional drilling information. The well is presently suspended with 7" casing set in the Alpine reservoir at 8158' MD / 7054' TVD. It is estimated that the well will be re-entered around 12 July 2000. Well construction operations will then re-commence and the horizontal production section will be drilled prior to running a 4-1/2" gas lift completion. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robertson Senior Drilling Engineer CC, CD1-35 Well File Sharon AIIsup-Drake Doug Chester Mike Erwin Gracie Stefanescu ATO-1054 ANO-382 ANO-383 Anadarko RECEIVED l,,,;':: 2000 ~aska 0~1 & Gas Cor~s, Commission Anchorsge Colville River Unit CD 1-35, Permit...perwork~_e_quired for Work Stoppage Subject: Colville River Unit CD1-35, Permit No. 99-38, AP1 No. 50-103 -20297 RE: Clarification of Paperwork Required for Work Stoppage Date: Thu, 16 Sep 1999 16:33:57 -0900 From: "Brian Robertson" <BROBERT4@mail.aai.arco.com> To: blair wondzell~admin, state.ak.us CC: "Sharon Allsup-Drake" <SALLSUP~mail.aai.arco.com>, "Douglas K Chester" <DCHESTER~mail.aai.arco.com> Further to your clarification e-mail dated 09/02/99, the suspension details for well CD1-35 are as follows: A. There were both logistical and reservoir damage avoidance reasons for not drilling the horizontal / reservoir section of the well upon the initial rig visit. It was deemed better to suspend the well at the 7" casing point and incur the cost of a move back to the well than leave the reservoir open to wellbore fluid for what would be in excess of 1 year before start up. B. CD1-35 was spudded on 05 May 1999. Rig release date was 15 May 1999. C. Well TD (at intermediate casing point) was 8168' MD / 7054' TVD. D. 7" casing depth was 8158' MD / 7054' TVD. Did not plug bump. Floats held. Diesel freeze protection to 1200' was pumped as part of the cement displacement. E. 9-5/8" x 7" casing was flushed with 300 bbls of fresh water followed by 25 bbls of diesel to freeze protect to the base permafrost at +/- 850' F. 1 joint of 4-1/2" tubing was run and landed off on a tubing hanger. The tubing hanger was pressure tested after installation of the wellhead adapter valves to 3500 psi. A BPV was set in the casing hanger profile. G. The expected date for moving back on to the well is June 2000. At this point the 7" casing will be drilled out and the horizontal section drilled prior to the well being completed (as per the permit submission). If you require further information on this well, please respond to this e-mail or call me on 265-6034. Regards Brian Robertson - Drilling Eng. - Alpine Project 1 of 1 9/17/99 8:07 AM Scblmnberg Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 12935 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 11 / 16/99 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-19 (REPROCESSED) 99199 CDR/~t~ (PDC) .~-- ~ ~-~[~ 990419 1 CD!-19 (REPROCESSED) 99199 ADN 990419 I 1 CD1-19 (REPROCESSED) 99199 ADN TVD 990419 I 1 CD1-35(REPROCESSED) 99218 ~oz~/cD~, (PDc) ~ O~'~t-~ 990513 1 CD1-35 (REPROCESSED) 99218 ~,z)t~ 990513 I 1 . .CD1-35 (REPROCESSED) 99218 mN ~ 9905~.3 I 1 .... i999 daska Oil & Gas iJons. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Ailch01'8~q~ GeoQuest GeoQuesl 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503 ATTN: Sherrie NO. 12608 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine 5/27/99 Well Job # Log Description Date BL Sepia CD-R :CD1-35 _.~ ~',..~ I ~ 99218 CDE/ADN/GR 990513 CD1-35 99218 CDR 990513 CD1-35 99218 CDR TVD 990513 C01-35 99218 ADN 990513 CD1-35 99218 ADN TVD 990513 SIGN !~_~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Anadrill MWD/LWD Log Product Delivery Cu{;tomer Arco Alaska, Inc. ..,__~ Dispatched To: AOGCC Well No CD1-35 Date Dispatche 18-May-99 Installation/Rig Doyon 19 Dispatched By: Joey LeBlanc LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 Anadrill LWD Division 3940 Arctic Blvd Anchorage, Alaska ggs03 Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 1. Type of Request: Abandon__ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Suspend _ Operation Shutdown __ Alter casing __ Repair well _ Plugging __ Change approved program __ Pull tubing __ Re-enter suspen~e'~t~l~Jll~ ?aS. bOii~, ~ulmiua~ Time extension_ Stimulate_ Ancn0rage Variance_ Perforate_ Other X Annular Injection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X_ Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) 57' RKB feet 7. Unit or Property name Colville River Field 4. Location of well at surface 466' FNL, 2335' FWL, Sec. 5, T11N, R5E, UM At target 645' FSL, 1377' FWL, Sec. 32, T12N, R5E, UM At effective depth At total depth 2607' FNL, 291' FWL, Sec. 32, T12N, R5E, UM 8. Well number CD1-35 9. Permit number 99-38 10. APl number 50-103-20297 - 11. Field/Pool Colville River Field/Alpine Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth: 8168' 7054' measured 8074' true vertical 7058' Length Size 84' 16" 2359' 9.625" 8121' 7" Casing Structural Conductor Surface Intermediate Production Liner feet feet feet feet TD prior to well suspension at 7" casing point. Cement displacement plug at float collar ORIGINA Cemented Measured depth True vertical depth 121' 121' 744 sx ASIIILW 2396' 2388' & 230 Class G 215 sx Class G 8158' 7053' CD1-35 is temporarily suspended at the 7" casing point. 6-1/8" horizontal hole will be drilled and the well completed as an open hole producer in March April 2000. It is intended that the 9-5/8" x 7" casing annulus be used for injection of associated drilling waste as per the previously applied for annular waste disposal permit application. 13. Attachments Description summary of proposal __ Detailed operation program BOP sketch __ Contact Brian Robertson at 265-6034 with any questions. LOT test, surface cement details and casing detail sheets X 14. Estimated date for commencing operation June 01, 1999 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Service 17. I hereby certifj( that the foregoing is true and correct to the best of my knowledge. Signed t~~/ ¢. b'~-~. ' Title Alpine Drillinq Team Leader FOR COMMISSION USE ONLY Date Suspended__ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearance Mechanical Integrity Test_ Subsequen~form require 10- I~e~o~' Approved by the order of the Commission Form 10-403 Rev 06/15/88 oly Fli.:;b ,, Commissioner David W, Johnston IIAppr°val SUBMI'FIN TRIF~LICATE Casing Detail 9.625" Surface Ca$in~l WELL:CD1-35 ARCO Alaska, Inc. 5/8/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 19 RKB to landing ring = 37.00', RKB to GL = 36.80' TOPS RT - LANDING RING SHOULDER ( LANDING JT~ 37.00 FMC FLUTTED HANGER 1.98 37.00 jts #36-#62 9 5/8", 36#, J55 BTC 1005.94 38.98 9 5/8" TAM port collar 3.00 1044.92 jts#3-#35 9 5/8" 36# J55 BTC csg 1259.95 1047,92 9 5/8" davis lynch Float Collar 1.44 2307.87 its#l-#2 9 5/8" 40# L-80 BTC csg 85.03 2309,31 9 5/8" davis lynch Float Shoe 1.74 2394.34 9 5/8" CSG SET @ 2396.08 2396.08 2396.08 12 1/4" HOLE TD 2406.00 Run centralizers in center of Jts. 1,2, over stop collars and over casing collars on Jts. 3-12 and over collars of every second it to surface. Total 36 bow spring centralizers. RUN STRAIGHT BLADE CENTRALIZER IN CENTER JTS# 35 &36. Remarks: MADE CSG UP TO BASE OF TRIANGLE AND USE APl MOD DOPE. Doyon 19 Drilling Supervisor: MIKE WHITELEY ARCO Alaska, Inc. Cementing Details Well Name: CD1-40 Report Date: 05117/99 Report Number: 3 Rig Name: Doyen 19 AFC No.: 998523 Field: Alpine T Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: I % washout: 9.625 12.25 52 deg at TD 2976' 2887' I Centralizers: State type used, intervals covered and spacing Com~nei~ts: : M~d Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): comments: CBUat 5 bpm;:lncrease tO 9,5 Gels before: Gels after: Total Volume Circulated: [oPm, 1000 bbls Wash.: 0 Type: Volume: Weight: Comments: FW 75 8.4 ;2.:ppb:BiOzan: .:.. .. . :Spacer: .0 Type: Volume: Weight: :,~ Comments: ARCO Spacer 50 10.5 :Lead Cement. 0 Type: I Mixwtrtemp: No, of Sacks:I Weight: Yield: :C~mments: AS III LW 70 (leg 530 10,7 4,44 · : Additives: · G+30%D053+0.6%D046+1.5%D079+1.5%S001+50%D124+9%D044 I I I Comments:I I 17° deg 230 15.8 1.15 i G · Additives: · G+O.2%D046+0.3%D065+1%S001 ., · DisPlacement: 0 ' Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 9.5 bpm 9.5 bpm 155k i: Reciprocation length: Reciprocation speed: Str. Wt. Down: 20' 10 fpm 130k · Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 225 224.5 Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:5-17-99 yes yes Time:14:30 Remarks:RIH w/no problems. Circ and condition mud. No mud loss. Added Desco and water for thinner. Pumped 75 bbls viscosifled FW w/nut plug ahead of spacer. Switched to tail when nut plug at shakers and MW dropped from 9.9 to 9.4. Had approx 90 bbls 10.7 cement to surface. Cement Company: I Rig Contractor: IApproved By: DS I DOYEN I Donald Lutrick CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1 -35 Date: 5/9/99 Supervisor: MIKE WHITELEY Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,396' 2,388' TVD Hole Depth: 2,446'TMD 2,438' TVD Mud Weight: 9.6 ppg Length of Open Hole: 24' 600 850 psi EMW = 0.052 x TVD + Mud Weight = ~ 9.6 ppg 0.052 x 2,438' EMW = 16.3 ppg Pump output = .101 BPS Jmped = 0.80 bbls BLED BACK = 0.76 BBLS 3,126 psi 2,605 psi 2,084 psi ~ 1,563 psi uJ 1,042 psi 521 psi 0 psi /' i@NE M!NU~E ~!CKS;: / t t / s ! LEAK-OFF TEST' ~CASING TEST LOT SH~ IN TIME CASING ~ST SHUT IN TIME 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 84 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ............... '- ................................................................................... ................... ..0..s.[.k.s. ........ .3..O.._p.s.j .... 0 stks 30 psi ................... .a..?.t..k.?. ...... .a..4..o.£~.L.' 4 stks 480 psi ............... j ............... j ................. ................... ~..s.t..k..s. ...... F.~.o...p. sj_. ................... .s...s. Lk..s_ ...... Z.O..O...p. sj... ................... Z.?.t..k.?. ...... Z.e..o...p. sj._ 8 stks 850 psi 9 stks ! ! ! I Z .;E )EZZZZZ]Z; D.]E ..j...o...m.j.n_ .................. j....8..o.9...p, sj.- __.2...o_.~j.n. ................... j_.Z?.O_.p, sj.._ 3.0 min ! 780 psi ..~._o..~j.n__.~ ............... i__Z.~..o...p, sj... 5.0min ~ ~ 770 psi ,._Z-_O_._mj.n_,~ ............... j__.Z.S..o...p, sj .... ................... .?..s.!.k..s. ...... ~.s..o..R.s.i...j 4 stks 400 psi j ' .............. 'f', ............... ? ............ -.---t ............... i_..5_.s.!.k..s_.L..s..6..o_p..s.:.,i .................. .?_.s.!.k..s. ..... Zj.o..R.s.L ~ ................... ..7..s.!.k..s. ...... .8.J.o..R.s.i..' .................. ..8..s.!.k..s. ...... .9.j.o...p..s.L., .................. ..,..s.!.k..s. ..... j.,_o]..o.p_s.L .................. !.0..s.!.k..s. .... j.,.2..o..o.p..sj.~ .................. ].L.s.!.k..s._ J_,.3..o.9..p..sj _ .................. .!2._s.!.k..s. .... J_,.~..sg..P..sj.. .................. ~.9..s.!.k..s...,. J. ,..4.~..9..P..s.!., 14 stks 1,520 psi ~ .................. !.~..s.!.k_s. .... J_.,_~..4.9..P..s.L .................. !?.?.!.k_s. .... J..,Z.s..°_p..s.L .................. j..7..s.!.k..s. .... ?..29..p..sj_ ................. ..~.?..s.!.k..s..~.~,.s..o..o..p..sj., SHUT IN TIME ....0:.0....m.i..n. .................. .2.,_5_o..o..p..s.L' .._.l...O....m.i..n_ .................... .2_:.4..8..o_.p..s.L' 2.0 min 2,480 psi i. .............. ..i. .............. J- ................ J 3.0 min 2,470 psi _5....o_..mj.n.. ................... Df.?.o..p_s_L' ..9_..o._mLn.. .................... ~,~.99_p..s.L 7.0 min 2,460 psi i.. .............. ..i. .............. ..1. ................ , 8.0 min 2,460 psi _]._o...o....mj.n._ ................... ~:f.?.o..p..sj.. ..J..5:.o....m.i..n. ................ 2,460 psi 8 min J i 760 psi 20.0 min ! 2,460 psi ......... ~ ..... t ............... t ............. ':---i,'- ........... r---F .............. -I- .............. :-t 9 m~n~i I 760 ps, ; i 25.0 m~n ~ ! 2,460 ps, I .............................. '1 .................. i" .............. -i' .............. -I" ................ '1 · i ! · ! · i i · i .... ]..°_.m. Ln._.~ ............... .L_Z.6..°...P.S.! .... L.3..0:.0....mj..n.; .............. _J . .2. , .4. .69. _P_ .S. ! . .,' NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1 -35 Date: 5/9/99 Supervisor: MIKE WHITELEY Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,396' 2,388' TVD Hole Depth: 2,476' TMD 2,468' TVD Mud Weight: 9.6 ppg Length of Open Hole: 24' 800 500 psi EMW = 0.052 x TVD + Mud Weight _ + 9.6 ppg 0.052 x 2,468' EMW = 13.5 ppg Pump output = .101 BPS Pumped =4.2 bbls BLED BACK = 1.07bbls BBLS :~i~E ::E!NE ,, i ~,,,::: i: :.: :: :: ~.:~, 3,126 psi 2,605 psi 2,084 psi ~ 1,563 psi UJ 1,042 psi 521 psi Opsi / ~ , LEAK-OFF TEST CASING TEST SHUT IN TIME TIME LINE .... , , , , , ~ , , , 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 84 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE .................... '6'i~i[CE"i .... §6'~,ii .................... !'"'[:)"~ii~'"'r'"':~'6'~i-"'i ............... * ............... J ................................ .!. ............... L ................ ................... ~ ..~.Lk.?. ...... .2..~..o...~.i... .................... .4...s. Lk..s' ...... ~?..o...p.s_] .... ................... ~_?.t..k..~. ...... .5.1.o...p~L' ................... ~..~.t..k..~. ...... ~!.o...p~L.. ................... Z..~.t..k.?. ...... Z.°.9...P~L.. ................... .8...~.k.?. ...... ZZ.O...p~]... ................... ~.?.Lk..~. ...... ~?..o...p~L. .................. ]_.o...s.t..k..s_ ..... ~.o_..p~]... .................. ].!..s.t..k..s. ..... .S..8..O...p.s..i... .................. ].~__s.t..k..s. ..... .S..8..O_.p.s_j .... ................... ~.?.t..k.?. ..... ~.~..O...~i .... .................. ]..8..?.Lk..~' ..... ~.o_..p~] .... .................. D..?.t..k..~. ..... .S.7..0_..P.S.] .... .................. .2..4_~.t..k..~. ..... ~.~..o...~i .... .................. .2_Z.?.Lk.?- ..... .5.~?_..p~] .... ................... ~.O._?.t..k..~. ..... .5..~..O...p~]...i 33 stks 560 psi ~ 36 stks 550 psi .................. iiii-~'~f~'~ ...... §~6'-!l,'~i'"' .................. _4.~.?.Lk~. ..... ~.~..o...p~i .... 43 stks 550 psi I I SHUT IN TIME ~ SHUT IN PRESSURE 1.0min : 500psi : .._2_._o_._m.j.n_ .................. /_.~.o._o_..~].__l 3.0 min ! 490 psi l ' .......... ~ .... i ............... '1 ............. ~---I 4.0m~n ~ ~ 490 ps, ~ ...6.._o___mj_n_ ................... L._~.~_.o..e~L..! ..Z-_o___mj_n_ ................... j_._.4..~..°_..p~L..[ ................... ..3_~.t.k_~ ...... .2..s..o..R.s.i...j 4 stks 400 psi j .................. ..~.~.t.k.~ ...... .5.~.o._.p..s.L.j .................. .?.~!.k.~ ...... ZZo..R.s.i..., 7 stks 810 psi ................... ..8.~!.k.~ ...... 9Zo...p._s.L.. .................. ..~..s..t.k..s. ..... .!,.o.!.o_.p..s.L .................. !.0..s_!.k_.s. .... .!,.~..°..°_P..s.L ................. .~. ?_!.k..s. _ ..~., .~..O..O..p..s. L ................... ~..s.!.k..s. .... %~..s..o.p_s_L .................. ~.9.~!.k.?. .... .!,.4.!.0..P.~!., ................. .!.4..s.!.k_s. .... .!,.s..~..°..P..S.L. 15 stks 1,640 psi ................... !.6..s.!.k..s._..!,Z_~..o_p..s.L ................... !?_s.!.k..s. .... .!:_~._~..o_.p_.s_L ................. . .2.?..s_!.k_s_ ~ .~ ,.s._O..O..p_s. L, SHUT IN TIME ...g_..9__.m.i..n. .................... .2...5._o. g..p_.s_L., ._]...O....m.i..n. .................... .2., .4..8..O..p..s. !. 2.0 min 2,480 psi L .............. ..I. .............. ,.~ ................ 3.0 min . 2,470 psi . ....4:.O....m.i._n. .................. .2. ,_ .4_ .7_0...p..s. L ....5_..o._..m.i..n. ................... .2. ,.4..6_o..p..s_L ....6.._o_...m.i_.n_ .................... _2. ,_ .4..6_o_..p. _s_ [ _. 7.0 min 2,460 psi i. .............. ..t. .............. ..~ ................. 8.0 rain 2,460 psi _]._O:.O....m.i.n.. ................... .2_:_4._6.o...p..s.L ..!5.:.o...m..Ln.. .................. ~?_.?.o.._p..s.!.. 8.0 min J 490 psi i 20.0 min i 2,460 psi ............... ............... ? .............. -r, ................ ............... ~ ............... ~ ................. , ._2_.5_:.O. _.m. .i.n. ..L ............... ',..2.,.4..69. P_ _s. L ' .... !9_..m. Ln_.! ............... £...4.?_.o_._p~L..! . ..3. g...o._.m.L.n. _" .............. _" ..2. ,_.4. _~.0. _ R.s.L j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Colville River Field CD1-35 Temporary Suspension Schematic (as built) Wellhead installed with tubing hanger and BPV set and pressure , tested to 3500 psi 16" Conductor to 121' Annulus injection zone at +/- 2450' TVD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2396' MD / 2388' TVD cemented to surface 9.7 ppg drilling mud in annulus 9.2 ppg brine with diesel freeze protection to 1200' TVD. 1 TOC at 6870' MD / 6716' TVD (500' MD above top Alpine Landing collar at 8074' (plug not bumped) Updated 5/18/99 Suspension TD at 8168' MD / 7054' TVD 7" 26 ppf L-80 R3 BTC-Mod Production Casing at 8158' MD / 7053' TVD @ 92 deg ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 19, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well' CD1-35 Dear Sirs: ARCO Alaska, Inc. hereby requests that CD1-35 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended that annular injection operations be commenced around 01 June 1999. Please find attached form 10-403 and other pertinent information as follows: . 2. 3. 4. 5. 6. Form 10-403 Surface Casing Description Surface Casing Cementing Report Casing and Formation Test Integrity Report (FIT at surface casing shoe) Casing and Formation Test Integrity Report (LOT at prognosed injection zone) CD1-35 Well Suspension Schematic. Note that on CD1-35 a 16.3 ppg EMW formation integrity test was obtained after drilling 20' out of the casing shoe. This indicated to us that the shoe was set in the shale above the proposed injection zone. The test was repeated at a point 70' out of the casing shoe where a leak off test of 13.5 ppg EMW (at hole depth) was obtained. We interpret this as an indication of the injection zone fracture strength. if you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robertson Senior Drilling Engineer CC. CDI-:J~ Well File Sharon AIIsup-Drake Doug Chester Alpine Files ATO-1 O54 ANO-382 ARCO Alaska Inc is a Subsidiary of AtlanticRichfieldCompalW MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,~ Chairman DATE: May 8, 1999 THRU: Blair Wondzell, ~~ FILE NO: P. I. Supervisor armlehgf.doc FROM: John H Spauldin~,~d,Y,~ SUBJECT: Petroleum Inspect'or BOPE Test Doyon 19 ARCO / Alpine CD1-35 PTD 99-38 May 8, 1999: I traveled to ARCO's Alpine Field CD1-35 location to witness the BOPE test on Doyon Rig 19. The AOGCC BOPE Test Report is attached for reference. As noted on the test report the "grayiok" flange that the BOPE makes up to the wellhead had the wrong APl ring installed by the wellhead service co. and leaked. This was repaired and testing resumed with no further leaks or failures. The pad area-is quite small and has construction as well as drilling rig material using the entire pad. The rig material was well organized and neat. SUMMARY: I witnessed the BOPE Test on; Doyon 19, I failure, 5 hours test time Attachment: armlehgf.xls Not confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Doyon Rig No. Operator: ARCO Well Name: CD 1-35 Casing Size: Set @ Test: Initial Weekly x Other 19 PTD # Rep.: Rig Rep.: Location: Sec. DATE: 5/8/99 99-38 Rig Ph.# 263-2300 Mike Whitely Ron Matteson 5 T. 11N R. 5E Meriaian UMIA T MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location OK Standing Order Posted OK Well Sign OK Drl. Rig OK Hazard Sec. OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 250/2500 P I 250/5, 000 P 1 250/5,000 P 1 250/5,000 P 1 250/5,000 P 2 250/5, 000 P 1 250/5, 000 P NA 250/5, 000 MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan 1 Test Pressure P/F 250/5,000 P 1 250/5,000 P 1 250/5,000 P 1 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 250/5,000 P 36 250/5, 000 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2150 AVG. 3,000 I P 1,475 P minutes 31 sec. minutes 38 sec. x Remote: x Psig. Number of Failures: 0 ,Test Time: 5.0 Hours. Number of valves testecl 20 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: A leak developed on the graylok clamp early in testing, replaced the APl ring resulting in the longer than normal test time Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev.12194) armlehgf. XLS TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION April 28, 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Doug Chester Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Colville River Unit CD1-35 ARCO Alaska, Inc. Permit No: 99-38 Sur Loc: 466'FNL, 2335'FWL, See. 5, T11N, R5E, UM Btmhole Loc. 2607'FNL, 291'FWL, See. 32, T12N, R5E, UM Dear Mr. Chester: Enclosed is thc 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 cemcntcd surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down thc surface/production casing annulus of a well approved for annular disposal on Drill Site CD1 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling xvaste in a volume greater than 35,000 barrels through thc annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by conta~cting the Commission petroleum field inspector on the North Slope pager at 659-3607. nstenson, P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation 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 ~ lb TypeofWell Exploratory StratigraphicTest Development Oil X Re-Entry Deepen! Service Development Gas SingleZone X Multiple Zone 2. ' Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 57' feet Colville River Field 3. Address 6. Property, Designation ._ Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL ~, AL-K--;4-7~7 4. Location of well at surface 7. Unit or property Name 11, Type Bond (see 20 AAC 25.025) 466' FNL, 2335' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 645' FSL, 1377' FWL, Sec. 32, T12N, R5E, UM CD1-35 #U-630610 At total depth 9. Approximate spud date Amount 2607' FNL, 291' FWL, Sec. 32, T12N, R5E, UM 5/01/99 $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 Alpine CD1-24 10,054' MD Crosses line feet 110' @ 250' feet 2560 6,976' TVD feet (T11N to T12N) 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 5200' feet Maximum hole angle 95° Maximum surface 2463 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Len~lth MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 84' 37' 37' 121' 121' Pre-installed 12.25" 9.625" 36# J-55 BTC 2377' 37' 37' 2414' 2407' 354 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 7714' 37' 37' 7751' 6991' 170 sx Class G N/A 4.5" 12.6# L-80 IBT-M 7663' 37' 37' 7700' 6992' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk {measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate LPirn%drUCtion 0 R I GI NA L Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat X BOP Sketch giverter Sketch D~'ililn~Pr°gram X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify tl~t the foregoing is true and correct to the best of my knowledge Signed ~ ~, CH ~-"~*,'"E'Y?-- . Title Drilling Team Leader Date / , Commission Use Only 'erm~:~be~ Z I AP'number I Approval date I See cover letter for '" 50- ,,~(:~ ~'-"' .~_ O ..~ ?'~' ~"~-- ~)" ~;~' Oth~rements Conditions of approval Samples required Yes (~ Mud log required Yes Hydrogen sulfide measures Yes ~ Directional survey required ~ No Required working pressure for BOPE~2M (~ 5M 10M 15M j~"~'r'~ ~t.~o.J~. -~t ~fl~o.~ ~,"~1~ Other: ORIGINAL, SIGNED-BY by order of '~ ~,~ .Approved by Robert N. Cnristenson Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplical EXHIBIT "1" CONFIDENTIAL Well Name: Alpine CD1-35 Surface Location: 466' FNL, 2335' FWL, Sec. 5, TllN, R5E, UM Target Location' 645' FSL, 1377' FWL, Sec. 32, T12N, R5E, UM Bottomhole Location: 2607' FNL, 291' FWL, Sec. 32, T12N, R5E, UM Scale: 1" - 2,000' 4-19-99 99041901A00 ,co .... ............ ' "'/', .' ~?:. i'::!::!',~.'~:':'' ..... .,, -.:~ !:~',Z:!::.2 :.' :':::' .i;:!?7%: !~ "~:.i': ~i: .%~: :L'::~ : ·' ~ ' P::{")~,'.'~'~:::-: "'::':.L';'~[:.(.:'{ ':{ ':i~.{: ..... .::::::: i:I:::.~;:::: ~':' ":':~ :}":, ,.X ' :: ' ' , ~::;.~.:: ~ UTA: 22 / :?}:-:'"::~'f:.{: -:: :: '~.-x.'{?'.::.' (:'..:..:;.:-:'~.,'::;.:'.;~h~:~,¢ · / ..... ":":::' ~::': ::::':~':":"A L025 -.', ';:::::~:.;.'w~ .... ~ ,, · "' "-t :.:::.:.; -':;':);~-i..:::: ;!.:: :.'.::. ~ ....... ~.~,, · ' ' ~ '., ': " . . ~ ~,- '" fi2{':?::.;2: ?~:~:.~ '".'.;t:.:¥:,::::,¥?:... ~.:?:-:..,',.:%:,::~2!.:~.:.::?:~ .... .:..: ..:.?:.:~:..: :....: .:.?.:::'.:::~ , ~?":'~b % :'': ':':~'?:'%':::' I;: :::f::?: ':? :...::,- :.E: :" .- ". ..... . .... ...t~:~. · .!::;::::::.?.?:tf:~-::::.}::~;:::::'.%-.2;...-.~. '.?::~::::~:{:3::'." · , , - ....:.:::.!~: .... ..~s~: :. - -' ?? :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::., .... ;:..-,,~.. ::::::::::::::::::::::::::: _ ~~:-':"::~~ " ~ ~' " ':~:'. ..... -.~ .-: · ........... ,~ ' T ',:.: ::.:.::'x~.::::'~.'-.:.':~ "":"~":~": ~,.'~:[:";~:~¢.!'.:':,..:.'~:~':':.:::;~:~:~;;'t~C:~:"::;; ...... ~i -:~'~' ~ .... . O.. _ · ':':~ {::?}.}?::~:~':.:2:%2: '"::.~?73' !~':::.~/:; .'~!:%' ~::'::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~ ~' .... .: .: ::::'.;~:'d;:;::;::~ ¥:.:.:: , 1 56 ~~/:- ~-;' - -~' ' :":"'"' ~:G.:} :~':':; ...:.::-.2:;%'.,?:/::?:f.`?' :::::::::::::::::::::::::::::/,.....::. · {1, ' x:.~:'..t?~.._ ,, , ,'~,' ~ 14/10/991Mrt aJr ~ A99001 ACS I ALPINE FaCi VICINITY MAP NOT TO SCALE / 70+6 9+° ~ / ,,o+,o ~ / ,,++~o / 39++38 ~++~o LEGEND '~++'~ / - ex~s~o COnDUCtORS 45+044 + NEW CONDUCTOR LOCATION N / o PLAN CONDUCTOR LOCATION ' ~ / C/,5[ ~ ASSOCIATBS, INC. ARCO Alaska, Inc. ~ ALPINE PROJECT ~ CD1 ~LL CONDUCTORS Subsidiory of Atlontic Richfield Compony AS-BUILT LOCA~ONS ~.~ ~,,~,o.I i~,.-,o: i~.~,: i,~v: LK663D1 3/5/99 ,CE-CD10-663D1 l OF 3 1 ALL CONDUCTORS ARE LOCATED IN SEC 5, t 11 N, r 5 E, UMIAT MERIDIAN Sec Line O/S Well 'Y' 'X' Lat. (N) FNL FWL Gnd Pad CD1-1 5,975,904.92 385,999.99 70' 20' ,34.922" 150' 55' ~0.~68" 222' 2,572' 1,3.0' 19.5'.. CD1-2 5,975,897.89 ,385,992.91 70' 20' ,34.852" 150' 55' ,31.071" 229' 2,565' 1,3.0' 19.5' CD1-3 5,975,890.99 ,385,985.82 70' 20' ,34.78,3" 150' 55' 31.275" 2,36' 2,558' 1,3.1' 19.5' CD1-4 5,975,88,3.8,3 ,385,978.79 70' 20' ,34.711" 150' 55' ,31.478" 24,3' 2,551' 1,3.2' 19.5' CD1-5 5,975,876.67 ,385,971.58 70' 20' ,34.640" 150' 55' ,31.685" 251' 2,544' 1,3.,3' 19.5' CD1-6 5,975,869.89 ,385,964.8,3 70' 20' 34.572" 1.50' 55' ,31.879" 258' 2,5,38' 1,3.4' 19.5' CD1-7 CD1-8 CD1-9 5,975,848.42 ,385,943.41 70' 20' `34.,358" 150' 55' ,32.495" 279' 2,517' 1,3.1' 19.5' CDI-IO 5,975,841.,34 ,385,9,36.18 70' 20' .:34.287" 150'. 55' `32.70`3" 286' 2,510' 1`3.0' 19.5' CD1-11 CD1-12 CD1-13 5,975,820.00 `385,915.06 70' 20' `34.074" 150' 55' `3`3.311" ,308' 2,489' 12.7' 19.5' CD1-14 5,975,812.97 ,385,908.00 70' 20' .34.004" 150' 55' `3`3.514" ,315' 2,482' 12.6' 19.5' CD1-15 CD1-16 5,975,798.86 ,385,894.08 70' 20' ,3,3.86,3" 150' 55' ,3,3.914" ,3,30' 2,468' 12.4' 19.5' CD1-17 5,975,791.81 ,385,886.84 70' 20' ,3,3.79,3" 150' 55' 34.12,3" .3,37' 2,461' 12.,3' 19.5' CD1-18 5,975,784.91 385,879.88 70' 20' ,3.3.724" 150' 55' 34.`32,3" ,344' 2,454' 12.2' 19.5' CD1-19 5,975,777.92 ,385,872.81 70' 20' ,33.654" 150' .55' ,34.526" ,351' 2,447' 12.1' 19.5' CD1-20 5,975,770.66 385,865.67 70' 20' ,3,3.581" 150' 55' ,34.732" ,358' 2,440' 12.0' 19.5' CD1-21 5,975,76,3.76 385,858.49 70' 20' 3,3.512" 150' 55' 34.938" ,365' 2,433' 11.9' 19.5' *CD1-22 5,975,756.46 385,851.10 70' 20' ,33.440" 150' 55' ,34.151" 373' 2,426' 11.9' 19.5' CD1-2,3 5,975,749.,31 385,844.44 70' 20' ,33.368" 150' 55' ,35.,342" ,380' 2,419' 12.0' 19.5' CD1-24 5~975,742.40 ,385,8,37.30 70' 20' 3,3.299" 150' 55' ,35.548" ,387' 2,412' 12.2' 19.5' CD1-25 5,975,7,35.,34 ,385,8,30.26 70' 20' ,3,3.229" 150' 55' ,35.750" ,394' 2,405' 12.4' 19.5' CD1-26 5,975,728.10 385,823.14 70' 20' ,3,3.156" 150' 55' ,35.955" 401' 2,,398' 12.6' 19.5' CD1-27 5,975,721.2! 385,816.08 70' 20' ,33.088" 150' 55' ,36.158" 408' 2,391' 12.8' 19.5' CD1-28 5,975,714.15 385,809.10 70' 20' ,33.017" 150' 55' ,36.,359" 416' 2,,384' 1,3.0' 19.5' CD1-29 5,975,707.14 385,802.20 70' 20' ,32.947" 150' 55' ,36.558" 422' 2,377' 13.2' 19.5' CD1-,30 5,975,700.17 385,794.75 70' 20' ,32.877" 150' 55' 36.772" 4,30' 2,,370' 1,3.4' 19.5' CD1 -,31 CD1-32 5,975,685.92 385,780.68 70' 20' 32.7,35" 150' 55' 37.177" 444' 2,,356' 1,3.2' 19.5' CD1 -,33 CD1 -,34 CD1-,35 5,975,664.72 385,759.63 70' 20' 32.524" 150' 55' ,37.782" 466' 2,335' 12.9' 19.5' CD1-,36 5,975,657.49 385,752.52 70' 20' ,32.451" 150' 55' 37.987" 47,3' 2,328' 12.8' 19.5' CD1-,37 5,975,650.51 ,385,745.40 70' 20' 32.,381" 150' 55' ,38.191" 480' 2,,321' 12.7' 19.5' CD1-,38 5,975,643.79 385,738.44 70' 20' 32.315" 150' 55' ,38.391" 487' 2,314' 12.6' 19.5' CD1-,39 5,975,636.34 385,7,31.37 70'~ 20' ,32.240" 150' 55' 38.595" 495' 2,307' 12.5' 19.5' CD1-40 5,975,629.19 385,724.,32 70' 20' ,32.168" 150' 55' ,38.797" 502' 2,,300' 12.4' 19.5' CD1-41 5,975,622..37 .385,717.40 70' 20' ,32.101" 150' 55' ,38.997" 509' 2,293' 12.3' 19.5' CD1-'42 5,975,615.01 385,710.21 70' 20' 32.027" 150' 55' 39.204" 516' 2,286' 12.2' 19.5' CD1-43 5,975,607.63 .385,702.97 70' 20' `31.954" 150' 55' 39.412" 52`3' 2,279' 12.1' 19.5' CD1-44 CD1-45 5,975,59,3.74 385,689.04 70' 20' `31.815" 150' 55' 39.813" 5`38' 2,265' 12.0' 19.5' * CD1-22 CONDUCTOR WAS AS-BUILT 2/11/98. ARCO Alaska, Inc. Subsidiory of Atlontic Richfield Compony CADD FILE NO. I DRAWING NO: LK663D1 3/5/99 I LoUNSBURY ASSOCIATES, INC. E,~NEERS PLANNERS SURVEYORS ALPINE PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCATIONS CE-CD10-663D1 ISHEET: I REV: 2 OF5 1 REVI DATE I BY I C~ I APP I NOTES 1. ALL COORDINATES ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS ARE INTERPOLATED FROM MICHAEL BAKER JR. DWG. CE-CDIO-102, SHT 1, REV. O. 5. BASIS OF LOCATION AND ELEVATION ARE TEMPORARY ALPINE MONUMENTS 3 & 4 BY LOUNSBURY & ASSOCIATES. 4. DATE OF SURVEY: WELL CONDUCTORS 10, 13, 14, & 16-19 WERE AS-BUILT 3/10/99, REF. FIELD BOOK L99-20, PAGES 3-11. CONDUCTORS' 1-3 WERE AS-BUILT 3/25/99, REF: FIELD BOOK L99-24, PG. 28-.31, CONDUCTORS 4-6, 9, 20, 21, 23-.30, & .35 WERE AS-BUILT 3/29/99, REF: FIELD BOOK L99-23, PG. 65, 67-73. CONDUCTORS 36-43, & 45 WERE AS-BUILT 4/6, 4/9/99, REF: FIELD BOOK L99-26, PG. 35-38, & 48, 'mmmmm~mm! ARCO Alaska, Inc. Subsidiory of Atlontic Richfield Company CADD FILE NO. ~ DRAWING NO: I SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 4/09/99. LOUNSBURY & ASSOCIATBS, INC. E~NEERS PLANNERS SURVEYORS CE-CD10-663D1 ALPINE PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCATIONS ISHEET:3 OF3 I REV: Alpine - CD1-35 PROPOSED DRILLING PROGRAM . . 3. 4. 5. 6. 7. . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Procedure Move in drilling rig. Install diverter and function test. (16" conductor pre-installed) Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 1/2 hole to the intermediate casing point in the Alpine Reservoir. Note LWD will be run over this section. Run and cement 7 inch casing as per program. Displace cement with brine. Top of cement 500 feet above Alpine reservoir as per Rule 20 AC 25.030. Freeze protect casing annulus and casing. Suspend well and move off rig. Move in drilling rig. Install and test BOPE to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test. Drill 6 1/8" horizontal section to well TD. Contingency- set ECP scab liner or slotted liner if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). - See Note 1. Displace well to weighted brine and pull out of hole. Run liner hanger (without liner) with flapper valve and 2 7/8" displacement string. Displace horizontal section to diesel. POH. Run 4 Y=, 12.6 #, L-80 tubing and sting into liner hanger. Freeze protect completion with diesel. Test tubing and tubing-casing annulus separately to 3500 psi. Nipple down BOP. Nipple up x-tree. Pressure test to 5000 psi. Set BPV and secure well. Move rig off. Note 1 :The Alpine development wells will have open hole completions. Rock mechanic studies have indicated that there is sufficient rock strength to maintain wellbore stability throughout the life of the well. However this assumes that a. the 6-1/8" horizontal well stays within the sand section over it's full length and b. the well does not cross any weaker formations (e.g. faulted or fractured zones). In the event that the conditions described in either a. or b. are seen while drilling the horizontal section, it will be necessary to cover these sections. The proposed methods for doing this is utilize ECP liner assemblies. The attached drawing shows the various options for formation isolation that are proposed. Well Proximity Risks: · Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-24 will be the closest well to CD1-35 (110.0' at 250' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 108.6' at 275' MD. Note that CD1-24 has not been drilled at the time of this permit application. These figures are based upon direction planning files. Drillin.q Area Risks: There are no high-risk events (e.g. overpressured zones) anticipated. Lost circulation: A small fault (10 ft of throw) is predicted around 1850' into the 6-1/8" horizontal section. This creates a potential for lost circulation. An addition of loss circulation material to the drilling fluid has successfully cured losses in previous wells. Good drilling practices will be followed to ensure that mechanically induced losses are kept to a minimum. 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. There is potential for differential sticking in the reservoir. The BHA design and 9.2 ppg mud weight have been developed to minimize this potential. However; vigilance through careful adherence to the directional plan will be required to ensure that wellbore geometry does not aggravate the potential for differential sticking. Annular Pumpin.q Operations: Incidental fluidS r developed from drilling operations on well CD1-35 will be injected into the annulus of a permitted well. The CD1-35 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing. 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 CDI-35 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2407') + 1,500 psi = 3,002 psi Pore Pressure - 1,089 psi Therefore Differential-- 3002 - 1089 - 1913 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2~992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4~599 psi 7,240 psi 6,154 psi CD1-35 DRILLING FLUID PROGRAM SPUD to Intermediate hole to Production Hole 9-5/8"surface casing 7" casing point - 8 Y2" Section - 6 1/8" point- 12 ¼" Density 9.5 - 9.8 ppg 9.5 - 10.0 ppg 9.2 ppg PV 10 - 25 12 -18 YP 20 - 60 15 - 25 35 - 45 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 18 - 22 10 minute gels <18 23 - 27 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min HPHT Fluid Loss at 160 8.5 - 9.0 9.0 - 10.0 <10 cc/30 min pH 9.0 - 9.5 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 permafrost and gravel, then reducing to 100-120 sec/qt by casing depth. Pump hi-vis sweeps if needed for supplemental hole cleaning. Maintain mud weight < 9.8 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 maintaining Iow end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 10 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. Colville River Field CD1-35 Temporary Suspension Schematic Wellhead installed with tubing hanger and BPV set and pressure tested to 3500 psi Diesel Freeze Protection in casing and annulus to 1200' TVD. 16" Conductor to 121' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2414' MD / 2407' TVD cemented to surface 10.0 ppg drilling mud in annulus £ 9.2 ppg brine with diesel freeze protection to 1200' TVD. I Updated 4/19/99 7" 26 ppf L-80 R3 BTC-Mod Production Casing at 7751' MD / 6991' TVD @ 90 deg Colville River Field CD1-35 Production Well Completion Plan 16" Conductor to 121' 9-5/8' TAM Port Collar @ +/- 1000' 4-1/2" Camco TRM-4PE-CF (5.937" OD, 3.812" ID) SSSV and DB-6 Lock (3.812" ID) with single 1/4" x 0.049" s/s control line @ 1,000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2414' MD / 2407' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-5 Top Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Packer Fluid mix: 9.2 ppg KCI Brine with 1200' TVD diesel cap Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-5 Top Latch 4-1/2" Tailpipe Assembly: (~- Baker GBH-22 seal assembly (3.958" ID) with 12' stroke, combo nitrile/viton seals TOC 500' MD above Alpine @ +/- 6746' MD/ 6604' TVD HES "X" (3.813" ID) Set at 60-65 deg Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2900 psi ;et 2 joints above the X landing nipple Baker Packer set +/-50' above 7" shoe O0 7" 26 ppf L-80 BTC Mod Production Casing @ 7751' MD / 6991' TVD, 90 deg Packer Assembly (~- Baker SLZXP Dbl Grip ZX Liner Packer (4.75" ID) with 12' Type 2 Extension on top (~)- 4-1/2" joint (1) blank pipe (3.958" ID) (~- HES "XN" (3.725" ID) landing nipple (~)- 4-1/2" x 10' pup joint w/centralizer O- Baker Model 'C' KOIV flapper check (3.81" ID) (~- 4-1/2" joint (1) blank pipe (3.958"1D) (~- 1/2 muleshoe joint Well TD at 10054' MD / 6976' TVD Updated 4/19/99 Colville River Field CD1-35 Production Well Completion Plan (w/ Isolation Options) 16" Conductor to 121' 9-5/8" TAM Port Collar @ +/- 1000' 4-1/2" Camco TRM-4PE-CF (5.937" OD, 3.812" ID) SSSV and DB-6 Lock (3.812" ID) with single 1/4" x 0.049" s/s control line @ 1,000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2414' MD / 2407' TVD cemented to surface Packer Fluid mix' 9.2 ppg KCI Brine with 1200' diesel cap Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-5 Top Latch 4-1/2" Tubing Tailpipe Assembly; - Baker GBH-22 seal assembly (3.958" ID) with 12' stroke, combo nitrile/viton seals, 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-5 Top Latch Hydraulics Set Liner Hanger Packer Assembly (~) - Baker SLZXP Packer (4.75" ID) with 12' Type 2 Extension on top (~) - 4-1/2" joint (1) blank tubing (~ -HES "XN" (3.725" ID) LN (~) - blank 4-1/2" liner (TBD) (~) - Baker Payzone ECP (~) - 4-1/2" joints (2) blank tbg (~) - Baker Model 'C' KOIV (~) - 4-1/2" joint (1) blank tbg Q - wireline entry guide with ECP cement inflated TOC +/- 500' MD above Alpine HES "X" (3.813" ID) Set at 60-65 deg Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2900 psi set 2 joints above the X landing nipple Baker packer +/-150' above 7" shoe Open Hole Scab Liner (~)- Baker Payzone ECP 4-1/2" joints (TBD) blank tbg with centralizers as required (~) - Baker Model XL-10 ECP with ECP's cement inflated Open Hole Bridge Plug (~)- Baker Payzone ECP (~)- 4-1/2" joints (TBD) blank tbg and centralizers as required (~)- 4-1/2" guide shoe with ECP's cement inflated 7" 26 ppf L-80 BTC Mod Production Casing 7751' MD / 6991' TVD@ 90 deg 4-1/2" 12.6 ppf L-80 blank IBT Mod. liner Well TD at 10054' MD / 6976' TVD Updated 4/19/99 CD1-35 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 the Alpine CD1-35 well · Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 121 / 121 10.9 52 56 9 5/8 2414 / 2407 14.2 1089 1537 7" 7751 / 6991 16.0 3163 2463 N/A 10054 / 6976 16.0 3155 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP- (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) -0.1} D = [(10.9 x 0.052) - 0.1] x 121 = 56 psi OR ASP = FPP - (0.1 x D) = 1089 - (0.1 x 2407') = 848 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)-0.1} D = [(14.2 x 0.052) - 0.1] x 2407 = 1537 psi OR ASP = FPP - (0.1 x D) = 3163 - (0.1 x 6991') = 2463 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3163 - (0.1 x 6991') = 2463 psi .I. HIDI~IM an~ J.N~rlVAInO=J ZL 91. gL I~L ~1. ~L LL 01. 6 8 OOg&- 00S9- OOSS- OOg~- Jd OOSS- ~ OOS~- OOSL- OOS- OOS .LN31QVEII3 3EIn.L:)VEI..-I aNY al'liN '3EIrISS3EId 3ElOd OgJ.VdlOIJ. NV SS- I. OO eu!dlV Alpine, CD1-35 Well Cementinq Requirei..=nts 9 5/8" Surface Casing run to 2414' MD ! 2407' TVD, TAM port Collar @ +!- 1000' MD Cement from 2414' MD to 1914' MD (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1914' MD to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (1914'- 860') Xo0.3132 ft3/ft X 1.5 (50% excess) = 495.2 ft3 below permafrost 860' X 0.3132 ft°/ft X 4 (300% excess) = 1077.4 ft3 above permafrost Total volume = 495.2 + 1077.4 = 1572.6 ft3 => 354 Sx @ 4.44 ft3/sk System' Tail slurry: 354 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 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 7751' MD / 6991' TVD Cement from 7751' MD to +/- 6746' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (7751' - 6746')° X 0.1268 ft3/ft X 1.4 (40% excess) = 178.4 ft3 annular volume 80' X 0.2148 ft°/ft = 17.2 ft3 shoe joint volume Total volume = 178.4 + 17.2 = 195.6 ft3 => 170 Sx @ 1.15 ft3/sk System: 170 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 c~ ~ ,~e,,~n FOR: ROBERTSON ~t~ plotted: tT-Mor-199g Plot Reference ~s CD1-~ Ve~lon ~ ~fna~s are In feet reference slot ~ T~e Ve~col Depths om reference ~flmot~ RKB. ARCO Alaska, Inc. Struotura: CD#I Well : 55 Iq$1d: Alpine FieldLeaafion : Nor'ih Slope, Alaska 4OO 400 800 1200 1600 2000 2400 2800 5200 3600 i-- 4000 I 4400 4800 5200 5600 6000 6400 6800 400 RKB ELEVATION: 57' 0.75 Begin Nudge 2.25 5.75 DLS: 1.50 deg per 100 ft 5.25 6.75 '2~5~ Permafrost · ~UEnd Build/Begin Drop 7.50 West Sak 6.00 4.50 5.00 DLS: 1.50 deg per 100 ft 1.50 EOD 317.1 1 AZIMUTH 1469' (TO TARGET) -40 9C--5528 Casing Pt C-20 K-$ K-2 TANGENT ANGLE 0.00 DEG KOP 5.00 6.00 9.00 DLS: 3.00 deg per 100 ft 12.00 15.00 ~81.,~~ Albion g7 ~'4.oo 27.00 30.00 Nb[an 96 33.00 EOC RZ I I i I i i 400 800 1200 I I I I I I I I I I I I I I I I [ I [ ! [ 1600 2000 2400 2800 3200 3600 4000 4400 4800 ,5200 5600 Vertical Section (feet) -> Azimuth 517.11 with reference 0.00 S, 0.00 E from slot #55 Creoted by finch FOR: ROBERTSON Dote plotted: 22-Mor-1999 Plot Reference is CD1-3,5 Version #4A, Coordinates are in feet reference slot jl,~§. True Vertical Depths are reference Estimated RKB, ARCO Alaska, Inc. Sfru~ure: CD//I Well: 55 Field : Alpine field Location: North Slope, Alaeka 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 KOP 5.00 6.00 9.00 DLS: 3.00 de9 per 100 ft 12.00 15.00 18.00 Albion 97 21.00 24.00 27.00 50.00 Albion 96 55.00 EOC ~*'¢' ~ ~ARGET ANGLE 90.37 DEG 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 ii i i i I i i i i i i i i i i i 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 5000 5200 5400 5600 3800 4000 4200 Verficol Section (feel) -> Azimuth 517.11 with reference 0.00 $, 0.00 £ from slot #55 Craoted by f~nch FOR: ROBERT~SON Date plotted: 22-1dot-IS99 [ Plot Re~erence Ps CD1-~ Version #4A. I Tru:OOV~inoa~f~e~ or~ tn feet r~fere~c;~(:lm~att:l~KB.I ARCO Alaska, Inc. Sfruofur~: CD~I Well : 5§ Fleld: Alpine Field Looaflon: North Slope, Alaska $200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 200 <- West (feet) 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 I I II II II II II II II II II II II II II I TD - Casing Pt TD LOCATION: 2607' FNL, 291' FWL SEC. 52, T12N, R5E TARGET LOCATION: 645' F'SL, 1577' FWL SEC. 52, T12N, R5E TARGET-7 Casing Pt-EOC Begin Drop EOC Deepest Point Bose Alpine ESTIMATED SURFACE LOCATION: 4.66' FNL, 2355' F'WL SEC. 5, T11N, RSE Alpine Alpine D Miluveoch A LCU K-1 Begin Build/Turn to Target HRZ '@~'~ EOC - '~bio n 96 '~ Alblon 97 i i i i I i i I i I I I I I I I I I I i I i i i i I i i i 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 <- West (feet) 5200 5000 2800 2600 2400 2200 2000 1800 A I Z 1600 0 1400 1200 1000 800 60O 400 200 200 Created by finch FOR: ROBERTSON Date plotted: 22-Mar-1999 Plot Reference is CD1-35 Version Coordinates ars in feet reference slot rrce Vertical Depths ore reference Est;mated RKB. ARCO Alaska, l)e.I Sfruefure: CD~I Well: Fleld: Alpine Field Location: NoHh Slope, Alaska[ I Point Begin Nudge Permafrost End Build/Begin Drop West Sa k EOD C-40 C-30 9 5/8 Casing Pt C-20 K-3 K-2 KOP Albion 97 Albion 96 EOC HRZ Begin Build/Turn to Target K-1 LCU Miluveoch A Alpine D Alpine Bose Alpine Deepest Point EOC Begin Drop TARGET-7" Casing Pt-EOC TD - Casing Pt 1 MD 250.00 859.58 916.67 1052.05 1585.55 2188.76 2405.76 2413.76 2778.76 5815.76 4048.76 5200.00 5851.51 6210.21 6326.45 6701.27 6882.21 6921 .O6 7O50.95 7165.99 7211.12 7245.78 7455.27 7527.62 7572.73 7650.96 7750.60 0053.80 PROFILE Jnc 0.00 9.14 10.00 7.97 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 19.54 30.31 33.79 33.79 33.79 37.19 48.62 58.81 62.82 65.90 84.37 91.00 95.06 95.06 90.37 90.37 COMMENT Dir 0.00 27O.0O 270.00 270.00 270.0O 517.56 517.56 517.56 517.56 517.56 517.56 317 56 517 56 51756 317 56 31756 317 56 319.02 522.63 324.89 325.64 326.18 329.03 529.97 329.97 329.97 331.67 331.68 TVD 250.00 857.00 913.29 1047.00 1576.57 2182.00 2597.00 24O7.00 2772.OO 3807.00 4042.00 5193.24 5832.00 6157.00 6255.51 6567.00 6717.57 6749.00 6844.00 6912.00 6934.00 6949.00 7O02.00 7005.00 7002.62 6995.72 6991.00 6976.00 DATA North 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 81.16 192.60 238.11 591.96 466.22 485.06 551.66 626.42 658.79 684.67 853.37 917.54 956.33 1025.80 1110.67 5158.09 East 0.00 -48.54 -58.03 -79.17 - 116.06 - 116.06 - 116.06 - 116.06 - 116.06 - 116.06 - 116.06 - 116.06 -190.29 -292.20 -333.82 -474.52 -542.43 -557.43 -612.94 -667.59 -690.03 -707.54 -8.14.33 -852.01 -874.55 -913.55 -962.05 -2054.79 V. Sect 0.00 55.05 59.49 55.88 78.98 78.98 78.98 78.98 78.98 78.98 78.98 78.98 188.96 539.98 401.65 610.12 710.75 755.50 821.34 913.50 952.29 985.18 1179.45 1251.97 1295.88 1571.86 1468.51 5697.68 Deg/lO0I O.OOJ 1.5"' 1.50 1.50 1.50 0.00 0.00 0.00 0.00i 0.00 0.00 0.00 3.00 3.00 3.00 O.C O.OU 9.00 9.00 9.00 9.00 9.00 9.00 9.00 9.00 0.00 5.00 0.00 Creoted by jone~ For: H Robert:son[ Oote plotted: 20-Apr-1999 Plot Reference Ts COl Coo~rnot~ am in feet reference slot ~5. I AL, O Alaska, Inc. Structure: CD#1 Field : Alpine Field Well : 55 Location : North Slope, Alaska East (feet) -> 400 360 320 280 240 200 160 120 A 80 I 0 Z 40 80 120 160 2OO 240 280 520 560 280 240 200 160 120 80 40 0 40 80 120 160 200 240 280 520 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 1400 1500 1200 /4000 O0 1100 \,ooo \ 900 6oo x~ 800 \ 700 ~35oo ~,X600 ~oo ~oo ~ ~ ~ ~00 ~200 ~ ~ ~ 300 6000 \ \ % 5900 \ \ ~, 5800 \ ,~ 5700 \ ~, 5600 ,. 5500 iii)400 50O ~ 600 / ? 700 ~ 800 / 900 / ~ 1000 / / ~ 1100 / / ~/1200 / / / ~' 1500 / / / / ~ 14.00 I I I I I I I I I I I I I I I I I I I I I I r i i i I i I 280 240 200 160 120 80 40 0 40 80 120 160 200 240 280 520 Eosf (foot) -> 4O0 560 520 280 24O 200 160 t20 80 A I z 40 o o 40 120 160 200 240 280 520 560 ARCO Alaska, Inc. CD~I 35 slot #35 A1 pi ne Fi el d North Slope, A1 aska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD1-35 Version~4A Our ref : prop3132 License : Date printed : 20-Apr-99 Date created : 11-Sep-98 Last revised : 22-Mar-99 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 32.522,w150 55 37.784 Slot Grid coordinates are N 5975664.584, E 385759.584 Slot local coordinates are 465.10 S 2336.52 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-9714'>,,22,CD~1 PMSS <O-10255'>,,WD2,CD~l PMSS <0-10548'>,,19,C[N~1 CD1-24 Version~4A,,24,CD~1 TCD1-40 Version #4,,40,CD~1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 1-Apr-99 129.5 262.5 262.5 13-Apr-99 1273.5 250.0 2800.0 19-Apr-99 159.4 275.0 8400.0 13-Apr-99 110.0 250.0 250.0 19-Apr-99 49.6 342.9 342.9 ARCO Alaska, Inc. Post Office iBo.~ 100350 A~chorage, A~aska 995't0-0360 Telephone 907 276 !215 March 21, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-35 Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is May 01, 1999. It is intended that Doyon Rig 19 be used to drill the well. The well will be drilled to horizontally penetrate the Alpine reservoir. It is intended that operations on this well be split into two distinct phases. The first visit by the drilling rig will drill the well down to the 7" intermediate casing point. The well will then be suspended and the rig moved onto other operations. At a later date, estimated at March / April 2000, the rig will return and the horizontal reservoir leg will be drilled prior to completion. Upon completion, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following · . 2. 3. 4. . 6. 7. 8. 9. 10. 11. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). Plat, identifying the property and location of the proposed CD1-35 well. A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed suspension diagram. Proposed completion diagram. Proposed completion diagram with open hole isolation options. Pressure information as required by 20 ACC 25.035 (d)(2). Proposed cementing program and calculations. 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: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely~,~ ,~t~,,~/ Brian Rob~rtson '~ Senior Drilling Engineer Attachments CC: CD1-30 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Lanston Chin ATO 1054 ANO 382 ANO 384 Kuukpik Corporation ARco Alaska, Inc. ALPINE DISBURSEMENT ACCOUNT P.O. Box 103240 Anchorage, AK 99510-3240 CHECK NUMBER PAY TO THE ORDER OF: ALASKA DEPT OF.REVENUE ALASKA OIL &..GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE ~ · . , . 249OO2989 MARCH 26, 1999 *** VOID AFTER 90 DAYS *** 73-426 839 0990337 EXACTLY *********** 100 DOLLARS AND O0 CENTS $*********** 100.00 The First National Bank of chicago-0710 Chicago, Illinois Payable ThrOugh Republic Bank Shelbyville, Kentucky TRACE NUMBER: 249002989 Ill 2 I'l ciO0 2 cill~ I~Ill I:DP, ~, CIO h 2 r= 21~: O ct cio 3 WELL PERMIT CHECKLIST FIELD & POOL /2(~ /~:3 COMPANY ~,,-~ ADMINISTRATION D/~TE ~ WELL NAME ~F_~ ~/-,~,._'~' PROGRAM: exp __ dev _'~' redrll __ serv __ wellbore seg ann. disposal para req ~ INIT CLASS ,Z~ /--<3,,,// GEOL N N N N N N N N N N N N N AREA ~;:~C~ UNIT# .~'~__2..~ _/~C) ON/OFF SHORE 1. 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 ddlling 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 ........... ENGINEERING 14. Conductor string provided ................... APPR D T GEOLOGY 15. Surface casing protects all known USDWs ........... /~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... ~ N 17. CMT vol adequate to tie-in long string to surf csg ........ Y N 18. CMT will cover all known productive hodzons .......... ~ N 19. Casing designs adequate for C, T, B & permafrost ....... (~ N 20. Adequate tankage or reserve pit ................. (~) N 21. If a re-drill, has a 10-403 for abandonment been approved... ~ 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... /~ N 24. Drilling fluid program schematic & equip list adequate ..... /~ N 25. BOPEs, do they meet regulation ................ ./~,, N 26. BOPE press rating appropriate; test to _~ ~OC:) psig. 6~' N 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~) N 28. Work will occur without operation shutdown ........... Y (~ 29. Is presence of H2S gas probable ................. Y 30. 31. 32. 33. 34. proper cementing records, this plan /J~fo.r ,~,~~(~,tf~~..-~J'7~(~- 35. With (A) will contain waste in a suitable receiving zone; ....... ~ m' ANNULAR DISPOSAL Permit can be issued w/o hydrogen sulfide measures ..... Y N/Y N -- Data presented on potential overpressure zones ....... Y,,,4q ~ ~ ~ Seismic analysis of shallow gas zones ............. /y~] ~ i /i.,/',, ~"'/' ,. Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratory (B) will not contaminate freshwater; or cause ddlling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. QN Comments/Instructions: - APPR DATE GEOI.,~C_~a.Y: ENGINEERING: UIC/Annular COMMISSION: RP~ BEW<~/~/-t'/''~T' WMtu/~l ~i~ DWO ~ JDH ~ ' RNC co ~/z~ c:\msoffice\wordian\diana\checklist