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Home My WebLink About200-006 STATE OF ALASKA ALI.OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment Li 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory❑ 200 6`GO t2 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage,AK 99510 50-103-20234-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25559 CRU CD1-27 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 11492 feet Plugs measured None feet true vertical 7050 feet Junk measured None feet Effective Depth measured 11492 feet Packer measured 8065 feet true vertical 7050 feet true vertical 6916 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2585' 9.625" 2622' ANNENOV 0 2 201 Intermediate Production 8465' 7" 8500' 7063' Liner Perforation depth Measured Depth: Open Hole Completion 8500'- 11492' RECEIVED True Vertical Depth: 7063'-7050' AUG 2 1 2017 Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 8153' MD, 6965'TVD , OGC Packers and SSSV(type,measured and true vertical depth) Packer: Baker S-3, 8065' MD, 6916'TVD SSSV: WRDP-2, 1822' MD, 1703'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8500'- 11492' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 344 400 2370 1347 205 Subsequent to operation: 329 405 2326 1343 179 14.Attachments(required per 20 PAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q . Exploratory❑ DevelopmentEl Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil CI Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 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 Ilnur Mustafin Email Ilnur.Mustafin(a�cop.com Printed Name Ilnur Mustafin Title Production Engineer Signature —7--- 4,-7 , Phone 263-4039 Date ,Ziff — l A► (a RBDMS L L- r. t 5 2017 Form 10-404 Revised 5/2015 Submit Original Only • • • CD1-27 Scale Inhibition Treatment 7/21/17—7/22/17 Aqueous Scale Inhibitor Squeeze Job pumped from 16:00 hrs on 7/21/17 to 00:30 hrs on 7/22/17. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA—641/1508/1000 - ACF pumped 30 bbls seawater for a tubing flush,TBG/IA/OA-424/1477/1000 - LRS pumped 21.8 bbls WAW5206 preflush at.73 bpm while ACF pumped 87 bbls seawater, TBG/IA/OA-0/1452/1000 - LRS pumped 16.4 bbls SCW720 scale inhibitor main treatment at .52 bpm while ACF pumped 93 bbls seawater,TBG/IA/OA—0/1451/1000 - ACF pumped 1242 bbls seawater overflush,TBG/IA/OA- 186/1882/1000 Interval treated: 8,500'—11,492' MD STATE OF ALASKA , • ALASK. AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERAT NS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Stimulate r Other Scale Inhibition Rill Tubing P New Pbol Wai Treatment Alter Casing r 9 (-` r 1� Time Exten r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p" Exploratory r _ 200 - 006 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 .• 50 00 7. Property DesigpationjLease Number): 8. Well Name and Number: ADL 25559, 372095 i CD1 - 9. Field /Pool(s): ry Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 11492 feet Plugs (measured) None true vertical 7050 feet Junk (measured) None Effective Depth measured 11492 feet Packer (measured) 8065 true vertical 7050 feet (true vertucal) 6916 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2585 9.625 2622 2367 PRODUCTION 8465 7 8500 7064 RECEIVED ' r an Perforation depth: Measured depth: open hole 8500' 11492' �,1` ' True Vertical Depth: 7064' - 7050' b:e : " r`e9P. Ceolrunts 1 . Tubing (size, grade, MD, and TVD) 4.5, L - 80, 8153 MD, 6965 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 8065 MD and 6916 TVD SSSV - CAMCO BAL-0 SSSV @ 1822 MD and 1703 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8500' - 11492' 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 228 1825 2187 -- 196 Subsequent to operation 200 1861 2328 -- 196 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development Service r Stratigraphic r 15. Well Status after work: - Oil I Gas r WDSPL r Daily Report of Well Operations XXX GSTOR f WINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Nelson (a, 265 -6859 Printed Name Tim Ne n Title Staff Production Engineer Signature . Phone: 265 -6859 Date did, / Fiscus JAN i Form 10 -404 RE 76--- Submit Original Only (• -- ..3/1.2_ . t „ i14'► WNS CD1 -27 • ConocoPhillips • ell Attributes ax Angle & MD TD • Alaska Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (fIKB) ,,.x,<c+,v0,p. 501032032400 ALPINE PROD 9230 9,555.77 11,492.0 Comment H2S (ppm) Annotation End Date KB-Ord (R as ) Rig Relee Date ••• Well Confle '- C01- 27,9/17/201110:49'.55AM SSSV:WRDP _I J - Last _ 43.40 3/3/2000 Schematic - Actual Annotation Depth ORB) ) End Date Annotation Last Mod By End Date Last Tag: 1 Date Rev Reason: RESET WRDP I ninam 9/17/2011 Casing Strings Casing Description String 0... String ID ... Top (MB) Bel Depth (f... Set Depth (TVD) _. String Wt... String .. String Top Thrd • CONDUCTOR 16 15.052 37.0 114.0 114.0 62.58 H-40 WELDED HANGER 33 ' ,. Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String •.. String Top Thrd Y SURFACE 95/8 8.697 36.6 2,621.9 2,366.5 36.00 J-55 BTC -MOD . ;. Casing Description String 0... String ID ... Top (IRKS) Set Depth (f... Set Depth (TVD) ... String Wt... String •.. String Top Thrd PRODUCTION 7 6276 34.5 8,500.0 7,063.9 26.00 L -80 BTCM Casing Description String 0... String ID ... Top (1903) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd OPEN HOLE 6 1/8 6.125 8,500.0 11,492.0 Tubing Strings Tubing Description String 0... String ID ... Top )kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd TUBING 1 4 1/2 1 3.958 1 32.8 ` 8,153.4 1 6,964.9 1. 12.60 I L -80 1 IBTM Completion Details Top Depth CONDUCTOR, (TVD) Top Intl Mond_ 37 - 114 Top(fKB) (RKB) (9 Item Description Comment ID(In) 32.8 32.8 -0.35 HANGER FMC TUBING HANGER 4.500 1,822.2 1,703.3 33.54 SAFETY VLV CAMCO BAL-0 SSSV 3.812 8,021.9 6, >:9.2 50.59 NIPPLE HES') NIPPLE 3.813 8,064.8 6,915.6 51.98 PACKER BAKER S-3 PACKER 3.8751 WRDP, 1,822 O 8,141.2 6,959.0 59.39 NIPPLE HES'XN' NIPPLE 3.725 SAFETY VLV, 1,822 8,152.1 6,964.3 I 60.89 WLEG WIRELINE ENTRY GUIDE 4.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc, Top (RKB) (RKB) / (1 Description Comment Run Date , ID (in) 1,822 1,703.1 33.54 WRDP 3.813" WRDP (SN: HRS- 280) 9/16/2011 2.125 Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (MB) (RKB) (RKB) (RKB) Type Date Comment SURFACE, 8,500.0 11,492.0 7,063.9 OPEN HOLE 3/8/2008 FRAC C SAND, PUMPED 429,000# 16/30 BADGER, 37 -2,822 FRAC 9 ppg ON FORMATION Notes: General & Safety S End Date Annotation 5/17/2009 NOTE: View Schematic w/ Alaska Schematic9.0 1/21/2010 NOTE: WAIVER WELL - OA CHARGING FROM FORMATION iir GAS LIFT 38. 1 III GAS LIFT 5.988 GAS LIFT. 7,942 a NIPPLE. 6,022 PACKER. 8,085 b. 1 NIPPLE, 8,141 Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run WLEG. 8,152 = Stn Top (RKB) (RKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,872.9 3,412.3 33.71 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/12/2006 2 5,988.2 5,198.9 32.45 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/1/2006 3 7,941.9 6,835.2 43,52 CAMCO 'KBG -2 1 GAS LIFT OV BK 0.250 0.0 2/7/2009 PRODUCTION, 35-8,500 OPEN HOLE OPEN 0 PEN ROLE, PEN OLE, 8.500.11,492 TD. 11,492 • • CD1 -27 Scale Inhibition Treatment 12/21/2011: Initial pressure TBG /IA /OA — 500/1075/1180; Facility pumped 50 bbls SW preflush; LRS pumped 2.8 bbls WAW5206 (118 gal) at 0.4 bpm and facility pumped 26 bbls SW, 300/1075/1120; LRS pumped 28.8 bbls SCW3001WC (1210 gal) at 0.65 bpm and facility pumped 163 bbls of SW, 100/950/1060; LRS pumped 2.8 bbls WAW5206 (118 gal) at 0.4 bpm and facility pumped 26 bbls SW, 100/950/1060; facility pumped 1710 bbls of SW over - displacement. STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS•N REPORT OF SUNDRY WELL OPERATIONS , RECEIVED APR 2 1 2010 1. Operations Performed: Abandon ~`~` Repair w ell ~"'~ Plug F~rforations ~`"` Stimulate ssw Commission ~~ . After Casing Pull Tubing ~`°°°' F~rforate New Pbol Waiver ~"` ime Extensio Change Approved Program Operat. Shutdow n Perforate ~"'" Re-enter Suspended Wel 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory "' 200-006 3. Address: '° ~. API Number: ' Service Stratigraphic ~ P. O. Box 100360, Anchora e, Alaska 99510 50-103-20324-00 7. Property Desi2~ation: 8. Well Name and Number: ADL 25559 / 372095 \ CD1-27 9. Field/Pool(s): Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 11492 feet Plugs (measured) None true vertical 7050 feet Junk (measured) None Effective Depth measured 11492 feet Packer (measured) 8065 true vertical 7050 feet (true vertucal) 6916 Casing Length Size MD TVD Burst Collapse CONDUCTOR 114 16 114 114 SURFACE 2566 .9.625 2622 2367 PRODUCTION 8444 7 8500 7064 d~ tir 4~~ K E t `t ~+ G ~ ~ 1 ~ ' ' > ~ 1 ! Perforation depth: Measured depth: open hole completion 8500 -11492 True Vertical Depth: 7064'-7050' Tubing (size, grade, MD, and TVD) 4.5, L-80, 8152 MD, 6964 TVD Packers &SSSV (type, MD, and TVD) PACKER -BAKER S-3 PACKER @ 8065 MD and 6916 TVD SAFETY VLV - CAMCO BAL-O SSSV @ 1822 MD and 1703 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8500'-11492' Treatment descriptions including volumes used and final pressure: See attachment 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 784 2926 1164 -- 217 Subsequent to operation 738 2930 1275 -- 205 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development ~` Service . Well Status after work: Oil ~' Gas WDSPL Daily Report of Well Operations XXX GSTOR '" WAG ~ GASINJ ~ WINJ ~ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: none contact Brian Barreda i~ 265-6036 Printed Name Brian Barreda Title WNS Production Engineer Signature ~ / Phone: 265-6036 Date ~~~'~~~ ~t~+~-- L~ ti Form 10-404 Revised 7/2009 RB-' ~~ APR 2~ 1 10 Y~Zi•io Submit Original Only • • CD1-27: Job pumped 105 am to 745 am 3-28-10. Aqueous squeeze; 31 bbls pre flush sea water with WAW 5206 (127 gal) @ 4 bpm/vacuum; 205 bbls SW/SCW-3001WC (1265 gal) @ 4.2 bpm/vacuum; post flush sea water with WAW 5206 (127 gal) @ 4 bpm/vacuum; Displace with 1178 bbls SW @ 5 bpm. 443 SITP at start of displacement; on vacuum at the end of the displacement Well SI for 14 hrs after squeeze before returning to production. ConottiPhilGps 1, ...u, 'Ir'Y,' ____ _, _`17eP CU.f9 ~~f=u, v7s W COf wl SA NIF ~Ac NIF W Plxc c F 0 a WNS CD1-27 Well Attributes Max Angle 8 MD TD WellAore API/U WI Field Name MD (ftK81 ~ ~ Well Status Inc! (°) Act Btm (ftKB) 501032032400 ALPINE I PROD 92.30 9,555.77 11,492.0 Comment 'H25 (ppm) End Date KB-Grd (ft) Annotation Date Rig Release Data ( ,SSSV: WRDP '~ ( ( Last WO: 43.40 3/3/2000 ',Annotation Depth (kKB) (End Date Last MOtl ...Entl Date Annotation ( ( 'Last Tag: ( Rev Reason: WAIVERED WELL Imoshor 1/25/2010 iCasmg Stria s (Casing Description (String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) . stria wt... g sain g .. . I, String Top Thrd CONDUCTOR i6 75.052 37.0 174.0 1140 62.58 H-40 WELDED _ Casing Description String O._ String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String .. . String Top Thrd SURFACE 95/8 8.697 366 2,621.9 2,366.5 36.00 J-55 BTC-MOD Casing Description String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) ... String Wt... String .. . String Top Thrd PRODUCTION 7 6.151 34.5 8,500.0 7,063.9 26.00 L-80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (i... Sat Depth (ND) ... String Wt... String .. . String Top Thrd OPEN HOLE 61/8 6-125 8,500.0 114920 __ ITubm~Stnn s __ ~ T b ng Description String 0... String ID ... _ Top (ftKB) Set Depth (t... Set Depth (ND) ... String Wt... Str ng ... String Top Thrd i IUBING 4 1/2 3.958 6.564.9 '~~ 12.60 L-80 32.8 8 153.4 IBTM Completion Details . ___ (Top Depth -- - ' (ND) Top Inc! Nomi... ITOp (ftKB) (ftKB) (°) Item Description Comment ID (in) 32.8 32.8 -0.35 HANGER FMC TUBING HANGER 4.500 1,822.2 1,703.3 33.54 SAFETY VLV CAMCO 8AL-O SSSV 3.812 8,021.9 6,889.2 50.59 NIPPLE HES'X'NIPPLE 3.813 8,064.8 6,915.6 51.98 PACKER BAKER S-3 PACKER 3.875 8,141.2 6,959.0 59.39 NIPPLE ~HES'XN'NIPPLE 3.725 8,152.1' 6,964.3 ', 60.89' WLEG IWIRELINE ENTRY GUIDE 4.500 Other I n Hole relin e retrievab le plugs, valves, pumps, fish, etc.) ' To De [h ~~~ (TVD) ~~~ Top Intl /Top (ftKB) (ftKB) (°) Description Comment Run D t ID (in) 1.822 1.703.1 33.54}WRDP Stim l tions 8 Treatments CAMCO WRDP #HSS-131 5/52009 2.125 u a ' t3onom i Min Top Maz Bim Top Depth Depth - - - - Depth Depth (ND) (ND) ~ ~ (ftKB) (ftKB) (HKBj ~ (ftKB) Type Date Comment _ _ $500.0', 11 492.0' 7 063.5 OPEN HOLE 318/2005 FRAC C SAND, PUMPED 429,000# 16130 BADGER, F RAC 9 ppg ON FORMATION Notes: General 8 Safety _ -.. _ End Date Annotation 5 /1 712 00 9 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 1/21/2010 NOTE: WAIVER WELL- OA CHARGING FROM FORMATION Mandrel Details _. _ - _ Top Depih Top Port (TVD) Inc! OD Valve Latch Sae TRO Run Stn Top (ftK6) (kK6) (°) Maka I Model (inl Serv Type Type (in) (psi) Run D t C_om_ ... KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5!1212006 1 3,872.5 3,412.3 33.71 CAMCO 2 5 988.2!, 5,198.9 32.45 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/1/2006 3 7,941 9 6,835.2 43-52 CAMCOIKBG-2 1 GAS LIFT OV BK 0.2501 0.0 2/7/2009 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION RE~~O~E® ,.~ lJ i~+ ~, e~ 2:~ Q 9 REPORT OF SUNDRY WELL OPERATIOI~I,~s~~ ~~~ ~ ~~~ ~;~,~~, Co;'~'i~il~~9CI? 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other A,t?C®p a squeeze Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ~ • Exploratory ^ 200-006 ! 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20324-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 56' CD1-27 8. Property Designation: 10. Field/Pool(s): ADL 25559•/ 372095 ~ Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 11492' ' feet true vertical 7050' feet Plugs (measured) Effective Depth measured 11492' feet Junk (measured) true vertical 7050' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 115' 115' SURFACE 2566' 9-5/8" 2622' 2367 PRODUCTION 8444' 7" 8500' 7064' Perforation depth: Measured depth: open hole completion 8500'-11492' `~ }y, ~ ~~~~~ true vertical depth: 7064'-7050' Tubing (size, grade, and measured depth) 4.5", L-80, 8153' MD. Packers &SSSV (type & measured depth) Baker S-3 pkr @ 8os5' Camco WRDP SSSV @ 1822' 12. Stimulation or cement squeeze summary: Intervals treated (measured) see attachment Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 754 1432 369 -- 190 Subsequent to operation 722 1588 442 -- 189 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ - Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none contact Tim Schneider @ 265-6859 Printed Name Tim Sch ider Title Alpine Staff Engineer c? ~r S D Signature •~-•~ Phone: 265-6859 Date Pre ared b Sharon All Drake 263-4612 Form 10-404 Revised 04/2006 ~ t, ' ;-_~~ Submit Original Only ~ 6~loy WSR -Well Service Report • Well Service Report U Page 1 of 1 Well Job Scope CP. AI Rep CD1-27 Scale Inhibition Shirtliffe, Ryan Date Daily tiVork Unit Number 5/15/2009 32 Initial & Final T/I/A Initial - 500/1100/1100 Field: ALPINE Pressures: Final VAC/800/1000 Pumped an aqueous scale squeeze into well. Pumped 14.Sbbls SW+5206, 2~# hr. 110.4bbls SW+3001, 14.5 bbls SW+5206 and chased in with 388bbis SW. Freeze Summary protected the well with 37 bbls Diesel. Pumped the job at 5.4bpm with pressure averagiung 600psi throughout job. Well on vacuum at end of stages. STf1RTTI.ME OPE.RATI:(JN 04:00 PM Rig in and pressure test lines. Wait on equipment. Pump pre-flush 14.Sbbls SW+5206 at 4.5 bpm and 600psi. Pump 110.4 bbls 06:00 PM SW+3001 at 5.4 bpm, 600psi followed by 14.Sbbls post flush SW+5206 at 5 bpm, SSOpsi. Displace the well with 388 bbls SW at 5.4 bpm, 600psi. 07:45 PM Freeze protect the well with 37 bbls diesel. 08:00 PM Rig out eq uipment and move to CD2 pad. Fluid Type To Well .From Well .1~on- recoti~erable Note DIESEL 37 SEAWATER 388 SEAWATER, SCW- 110 3001 WC SEAWATER, WAW- 29 5206 http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=8D 1285C3... 6/5/2009 CanotoPhillips ~ ~ :~,;, '~ ... HANG= contDUc i WRDP, SSSV,' SURF 3]--: GAS GAS GAS NIPPLE, PACKER, NIPPLE, WLEG. PRODUC 35 OPEN FRAC. OPEN( 8,500-• WNS ! CD1-27 501032032400 (ALPINE PRODUCING 'I 92.30_ 9,555.77 11.492.0 ment H45 (ppm) Date Annotation 'End Date KB-Grd (k) Rig Releasa0 SV: WRDP I I :Las/ WO: ' _ li 43.40 3/3/2000 ~.otation Depth (kKB) End Data Annotation Last Mod By !End Date a Tao: ~ (Rev Reasorc UPDATE T09.0 ~ ImosDOr 5/171200£ Casing Des criplion ( Strin 0... g m9 Ser' ID ... To (HKB) P Set De ih (... P istring wi.. string ... ll et e t .. P string rop rnrd ' CONDUCTOR I 16 15.052 0.0 114.0 62.58 H-00 1140 WELDED Casin Descn g ption Strin 0... 9 Strin ID ... 9 To (kKB) P Set De M t... P ( Sat Da th ND String Wt... String... P ( ) ~~ String Top Thrd SURFACE 9 5!8 8.697 36.6 2,621 9 2,366.5 36.00 J-55 BTC-MOD (Casing Description String 0... String ID ... Top (kKB) Set Depth (i... Set Depth (ND) .....String WI... String ... String Top Thrd PRODUCTION 7 6.151 34.5 8,500.0 70639 26.D0 L-80 BTCM Casing Description String 0... String ID ... Top (kK8) Set Depth (i... Set Depth (ND) ... ,String Wt... ~iString ... String Top Thrd OPEN FIOLE 61/8 6.125 8,500.0 114920 _-_ - . Tubin Stnn s 9 4 - _ Tnhin Descri tion P (Strin 0... String ID ... Top (kKB) Set Dep[h (f... Set Depth (ND) ... String Wt... String ... String Top Thrd (TUBING 41/2 I 3.958 32.7 8.153.4 6,964.9 12.60 L-80 IBTM ___- tion De Comple ~TOp Depth 1 tails _ _ - j (ND) Top Intl Top (kKB) (kK6) (°) Item Description Comment ID (in) 32.7 32.7 -0.35 HANGER FMC TUBING HANGER 4.500 1,822.2 1,703.3 33.54 SSSV CAMCO BAL-O SSSV 3.812 8,021.9 6,889.2 50.59 NIPPLE HES'X' NIPPLE 3.813 8,064.8 6,915.6 51.98 PACKER BAKER S-3 PACKER 3.875 8,141.2 6,959.0 59.39 NIPPLE HES'XN'NIPPLE 3.725 8,152.11 6,964.31 60.89j~WLEG WIRELINE ENTRY GUIDE ~ 4.500 Other In Hole ( Wireline retrievable plugs, valves, pumps, fish, etc.) _ Top Dep[h 'i (TVD) Top Intl Top (/tK8) (flK6) (°I Desc iption Comment Run Dat ID (in) __ - - ___ _ 1 ffi2 1./03.1 Stimulations 8 33.'i4 WRDP CAMCO WRDP dHSS-131 5/5/2009 2.125 Treatments ~~ _ _ _ ' eonom i - - Min Top Max Bhn '' Top Depth Depth Depth Depth (NDI (TVD) (kKB) (kKB) i (kK8) Iftl<e) ~ Type ~ Date Commeid _ I ~ 8,500.0 11 492.0 OPEN HOLE 3/8/2008 FRAC C SAND, PUMPED 429,000# 16/30 BADGER, I 7,063.9 I FRAC 9 ppg ON FORMATION Notes: General EnaDate 8 Safety _ _ __ _ _ .. - -A~ooranon ___ 5/17/2009 NO f E' VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Detail s Top Dopth Top Port ' I (TVD) Intl '' OD Valve Latch Size 'TRO Run Stn Top (kKB) (kK B) (°) Make Model liN Serv Type Type ! tin) (psi) Run Date ~ Com... 1 3,872.9. 3412.3 33.71 CAMCO',KBG-2 11GAS LIFT IDMY BK '0.000 0.05!122006 I ~ 2 5,988.2 5,198.9 32.45~CAMCO KBG-2 1 GAS LIFT '~DMY :BK '0.0001 00 5/1/2006 -- 3~ 7,941.91 6.835.2 43.52jCAMCOIKBG-2 1IGAS LIFT ~.OV IBK j0.250 0.0 2!72009 CD 1-27 (PTD 200-006) Report~OA SCP • Page 1 of 1 Regg, James B (DOA) From: NSK Probiem Well Supv [n1617@conocophillips.com] Sent: Monday, April 20, 2009 4:11 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B(DOA); NSK Well Integrity Proj; NSK Problem Well Supv Subject: CD1-27 (PTD 200-006) Report of OA SCP Attachments: CD1-27 schematic.pdf; CD1-27 90 day TIO plot.jpg Tom, Alpine gas lifted producer CD1-27 (PTD 200-006) has SCP on the OA from formation due to an open shoe. The well will be added to the quarterly SCP report. The current TIO~is 200/1000/900. The well was constructed with 9-5/8" 36# J-55 grade casing with an internal yield pressure of 3520 psi. Gas sam les have been taken and the as a ears similar to the as ca of the Qannik reservoir. A passing diagnostic was performed on 02/12/09 indicating tubing and production casing integrity down to the packer @ 8065'. There is no indication of IA x OA communication as the OA pressure will continue to build independently of the IA pressure. In order to establish the pressure in which the OA will stabilize, ConocoPhillips requests a test period of 90 days, allowing the OA pressure to climb until stabilized. The OA pressure will not be allowed to exceed 1500 psi (45% of 3520 psi = 1584 psi) during the test. A monthly update on the well can be provided if you would prefer during the test. The purpose of the test is to gather data and determine the path forward on this well and possible future wells. The stabilization pressure will determine whether the well can be internally waivered or if alternate methods of repair need to be taken, such as attempting to pump a cement shoe. Attached is a schematic and a 90 day TIO plot. ~ «CD1-27 schematic.pdf» «CD1-27 90 day TIO plot.jpg» Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 , ~ ~~~~i a~,~3.~~3~,~ ?-~:~~~.°! -- . ~ r:;,, r~ N 7/29/2009 CRU CD1-27 PTD 200-006 4/20/2009 TIO Pressures • • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~~~ REPORT OF SUNDRY WELL OPERA~e~Q~I~,S, 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate Q • ei " ~~f1'!!SSlOQ, ~fttl . Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ ^ Time x e F rr~Y, ^ Waiver Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^~ Exploratory ^ 200-006 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20324-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 56' CD1-27 8. Property Designatign: 10. Field/Pool(s): ADL 25559 / 372095 Colville River Field /Alpine Oil Pool 11. Present Welf Condition Summary: Total Depth measured 11492' feet true vertical 7050' • feet Plugs (measured) Effective Depth measured 11492' feet Junk (measured) true vertical 7050' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 115' 115' SURFACE 2566' 9-5/8" 2622' 2367' PRODUCTION 8444' 7" 8500' 7064' Perforation depth: Measured depth: open hole completion 8500'-11492' true vertical depth: 7064'-7050' Py~? " ' ~'~~~* ~•^~~~': j~~4 ~~' ~Ul+ Tubing (size, grade, and measured depth) 4.5", L-80, 8153' MD. Packers &SSSV (type & measured depth) Baker S-3 pkr @ 8os5' Camco WRDP SSSV @ 182 2' 12. Stimulation or cement squeeze summary: Intervals treated (measured) pumped 109 bbls SW+WAW5206, refer to attachment Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 754 1432 369 -- 190 Subsequent to operation 722 1588 442 -- 189 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work : Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none Contact Tim Schneider @ 265-6859 Printed Name Ti Schneider Title Alpine Staff Engineer Signature A, ! F~iope: 265-6859 `/ C Date 7 "~ V l Pre aced b Sharon Allsu Dr k 263-4612 Form 10-404 Revised 04/2006 ~- ~ Nf~!` 11 ~ 1~Q~ V'~j~~-~ ~ r~ Submit Original Only ~ WNS - CD1-27 ..~]1,~ 1 5 ` 1~l1 CCNlt7~0 ~ Well Attributes _ ~ Max Angle & MD _ ITl) p ~ 1 t',u ,. Wellbore APUU WI Fieltl Name ( (Well Status (Prod/Inj Type Inc! (°) MD (ftK8) _ ~ACt Bim (ftK6) ~ .. 501032032400 ALPINE PROD 92.30 9,556 11,492 _ Comment H2S (ppm) Date A notation End Date KB-Grd (ft) Rig R I e Data ., , wet n 2f 8r ~ non z QP SSSV. WRDP (Last WO: I 43.40 I 3/3!2000 _ ) i- z. „ ~ _ _ _ Srt~enialK, AC I Annotation Depth (fl KBj End Date Annotation Entl D t Last Tag Rev Reason: GLV CIO, RESET WRDP 2/18/2009_ Casin Strin s String OD I. String ID ~ Set Depth Set Depth (ND) String Wt String ~. Casing Description (in) (in) Top (ftK6) (ftK6) (ftK8) (Ibs/k) Gratle Siring TOp Thrd_ • CONDUCTOR I 16~ 15052 0 114 114.0 62.58 H-00 WELDED _ .• E 95/8 J-55 OO iBTC-MOD ~; _ -_ ~IPRODUC ION I 6.151 0 8,500 7,063.91 26. ~L-80 BTCM - conlDUCroR. _~ OPEN HOLE 6 118 6.125 8,500 it 492 .. Tubin St_nn_ s ___~ g ~. String OD i Shing ID _. _ ___ Set Depth Set Depth (ND) String WI String Tubing Des ription (in) ~ (in) Top (ftK6) (ftK6) (ftK8) (Ibslft) G d e String TopThrtl ALL 4 1/2I 3.958 l 0 8,153 6,965 12.60 L 80 IIBTM Other In Hole A ll Jewel : Tubin Run $ Retrievable Fish etc. NIPPLE,,,822- WRDP, 1,822 ~-- ^u Top Depth , 'I (TVD) Top Inc! "Top (ftK6) (ftK6) (°) Description Comment Run Dat ID (in) ' 1,822 1,703.1 33.54 NIPPLE I CAMCO BAL-O LANDING NIPPLE 3/2/2000 T 3.81: ' 1,822 1,703.1 33.54 WRDP ~ICAMCO WRDP #HSS-243 2/7/2009 2.12` 3 873 3,412.4 1 33.71 GAS LIFT ICAMCO/KBG2/1/DMY/BK/l/ Comment: STA 1 I 5/1212006- ~ 3.93E SURFACE. _ 5,988 5,198.8 32 45 GAS LIFT CAMCO/KBG2/1/DMY/BKI// Comment: STA 2 ~ _- L 5/1/2006 ! 3 93E 2,622 ~ _ _._ - _ 7,942 6,835.3 43.54 GAS UFT ~CAMCO/KBG2/1/OVIBK/.25//Comment STA3 _.. _: 2/712009 13.93E . 8,022 6,889.2 SO 601 NIPPLE IHESXNIPPLE 3/2/2000 -~ 3.81 ~j, 8,065 6,915.7 52.OO~PACKER (BAKER S3 PACKER 3/2/2000 i 3.87`_ ",~° 8,141 6,958.9 I 59.361 NIPPLE HES XN NIPPLE 322000 3 72` GAS UFT,__ 8,153 6,964.7 61.01IWLEG BAKER WIRELINE RE-ENTRY GUIDE 312/2000 3.87`_ 3.673 , Stimulations $ Treatments - __._.. _ eono~n Min Top Max Btm Top Depth Depth Depth Depth (ND) (TVD) I (ftK6) (ft KB) (ftK8) (ftK8) Type Date I Comment _ 8,500 11,492 7 063.9 OPEN HOLE 3/82008 iFRAC C SAND, PUMPED 429,000# 16/30 BADGER, I FRAC i9 ppp ON FORMATION GAS LIFT, 5,988 GAS LIFT, 7,962 NIPPLE. 6.022 8,065- NIPPLE, 8,141 WLEG. E.'S3 8.500 ~ ~ ii OPEN HOLE • ~• FRAC, 8,500 i OPEN HOLE, i • 11,492 \ " • TD.'11.d92 -- CD1-27 Well Work Summary DATE SUMMARY 03/22/09 Initiate chemical squeeze on we~umped stage 1, 109 bbls of SW+WAWS~t 4.5bbls/min. Start to pump Stage 2 of the job, pumped 18 bbls and ran into higher pressure. Call PE to discuss. PE an location. Kick in the pump and 0.5bb1/min, pressure continuing to increase. Shut down job at 1100 psi. Pump diesel freeze protect and SDFN. 03/23/09 GAUGE TBG TO 3.84" TO 1822' RKB. PULLED 3.81" SCSSSV (WRDP-2/SER# HSS-243/ BAL-O/ O-RING PACKING) @1822' RKB. REPLACED WITH 3.81" SCSSSV (WRDP-2/SER# HRS-282/ BAL-O/ O-RING PACKING). PERFORMED CLOSURE TEST WITH 600# DIFFERENTIAL ACROSS FLAPPER. ***PASS*'`'`. JOB COMPLETE. CD1-27 (PTD 2000060) Report of~led TIFL Page 1 of 1 • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, January 28, 2009 12:24 PM , ~~`~ I f Z`~~I Z~'vy To: 'NSK Problem Well Supv' Cc: Maunder, Thomas E (DOA) Subject: RE: CD1-27 (PTD 2000060) Report of failed TIFL Check your well schematic -the completion report shows surface casing as 9-5/8" 36ppf J55 (not L80), makes a pretty big / difference in the burst rating far pipe Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, January 20, 2009 12:41 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: CD1-27 (PTD 2000060) Report of failed TIFL Tom, Jim Alpine gas lifted producer CD1-27 (PTD 2000060) failed a diagnostic TIFL on 01/18/09 and has been added to the weekly SCP report. The TIO prior to shut in for the test was 50/950 A leaking GLV is suspected. SL will troubleshoot the GLV's and repair if possible. The TIFL (and IC packoff testing) was done for barrier confirmation to ensure the well does not have OA SCP. This well has an open OA shoe and we are monitoring the pressure daily. If SCP becomes apparent the Commission will be notified as required. Attached is a schematic and a 90 day TIO plot. «CD1-27schematic.pdf» «CD1-27 TIO.jpg» Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~ 6A- _ ~~~~~'; _ Lc ~~ /'. ___._ Ca q~ ~" 1/28/2009 CRU CD1-27 PTD 200-006 1 /20/2009 CHOKE FTP - -- -- FTT IAP TII10 Piot - CD1-27 OAP zoo 1000 .. ...:........A,... ..................................... ................................... ........ -- ~ ~ A D 800 .................. _ _ _ _ .............. ......... 150 : ~ 600 vi . ................ ... ..............~,~........... .............................................................. ~ _. _ ......... ~ 100 ~ o. - _._.__ _ ___ --~ - -, , - --v ----r---- -- ' --, sc ~ ; r ~ ~~ c ~ 400 ........... .. ...........................~ ................................... ..................... ....... v CCG~e ~~ 50 200 ......1~ y^~ ~ ~~ 0 01-Nov-08 01-Dec-08 01-Jan-09 Date 0 • ~ - _ • ALPINE -,, C©nacc~Phillips Alaskai, In+N. CD1-27 C D 1-27 ---- --- TUBING (0-8153, - --- API: 501032032400 ----- - Well T e: - - - PROD --- - - An le TS: -- - ... de 00:4.500, SSSV Type: WRDP Orig Completion: 3/3/2000 Angle @ TD: 92 deg @ 11492 10:3.958) PROD Annular Fluid: Last W/O: Rev Reason: FRAC, GLV C/O, caswG SET WRDP (o-asoo, 00:7.000, - -- - Reference Lo T . Ref Lo Date: Last U date: 3/25/2008 wczs.oo) Last a TD. 11492 ftK8 ~~ - ~ Last Tai Date: Max Hole Angle: 92 deg @ 9556 _ - - - - --- - 70- Casing String -ALL _ - ~4c%'] Descri lion _ Size To Bottom TVD Wt Grade hread Gas Lift -- CONDUCTOR 16.000 0 114 114 62.58 'WELDED andrel/Dummy = SURF CASING 9.625 0 2622 2366 36.00 TC-MOD valve 1 (3s73-3e7a, ~= PROD CASING 7.000 0 8500 7062 26.00 - BTCM ooasea) I OPEN HOLE 6.125 8500 11492 11492 0.00 Tubing String -ALL -- _- - _ - - - j __ Size __ Top _ Bottom ~ TVD_ _~ Wt _Grade~ __ Thread -t iJU 0 8153 t i~5 12.60 f L 80 IBTM -- ~ - _ L - - Stimulatian_s & Treatments __ _ Gas Lin Interval Date T e Comment andrevDUam~m2 = ~ 8500 - 11492 3/8/2008 OPEN HOLE FRAC FRAC C SAND, PUMPED 429,000# 16/30 BADGER, 9 ppg (ssss~5sas, - ON FORMATION 00:5.984) ~- ~ ~- ----- - _. Gas Lift M_andrel5Natves _ St MD ~ TVD I M na M rf Man Type V Mfr j V Type I V OD Latch Port I TRO ~ Date Run I Vlv Gas Lift MandrelNalve 3 (7942-7943, NIP (8022-8023, 00:5.000) PKR (6065-8066, 00:7.000) NIP (8141-8142, 00:5.000} WLEG (8153-6154, 00:5.000) 2 5988 5199 CAMCO KBG2 CAMCO DMY 1.0 -. 3 7942 6835 CAMCO Other lu s, equip., etc De th TVD T e KBG2 CAMCO OV 1.0 .) - JEWE_ L_RY - Descri ti 1822 1703 SSSV CAMCO WRDP #HSS-200- set 3/22/200 1822 1703 NIP CAMCO BAL-O LANDING NIPPLE i 8022 6889 NIP HES X NIPPLE 8065 6916 PKR BAKER S3 PACKER 8141 6959 NIP HES XN NIPPLE -~ 8153 6965 WLEG BAKER WIRELINE RE-ENTRY GUIDE _J i I ~ _ ___ ~ OPEN HOLE ~~ FRAC ' , (6500-11492) , ' ii ~ ~ ~~~~ ~~ OPEN HOLE f • ' (8500-11492, ~ ~, 00:6.125) ' , I I 3/9/2008 3.813 3.875 L 111 /111V V V{.I.1V IJ~KVVI~VJ 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 1 KbV 1 Vl V 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 Scate Squeezes Tom, Per our conversation, here is our preliminary list of wells we'd like to perform scale squeezes on. CD2-34 (201-191) CD1-27 {200-006) *~-- CD1-35 (199-038) CD1-43 (200-106) CD2-50 (202-049) We'll incorpora#e 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 9:26 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 bbi inhibitor pill (85% MEG, 15% scale inhibitor} Flush will be with dead Alpine crude (350-450 bbls) • 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 A11,/111V VVKlt, V111.1V\+LVJ ~~ 1, ~'.;. ':~ ~N i} ~p .~'"~' ~'+., iT. ~a ~.rati.,~. 1i~~ t'°iis ~v, , ~; 3 C7 nor i~^~iL+~4.oLvi ~ `i~%fth ~~Ja~irGlit > ~~% `N+°.`~i repiaCe ti~"ie ~,~1~~ 'td;:t"i S~abl~~ter aS well aJ t'i?e fiusl s. 1 i4~. V L. V 1 L Vile plan to perform ~~ wells prior to the ice road season to evaluate results and improve upon our procedures for up to 20 treatments during ice road (dependent on RU time-simops, eic.) The scale inhibitor designs are based on core work done in 2002-2004 to determine a scale inhibitor that mould not damage the Alpine reservoir and we were able to identify a product (acroiyte 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. dope this helps explain our plans. Let me know if further information is needed. Thanks, Tim From: Maunder, Thomas E (DOA) [mailto:tom.maunder@ataska.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 wells, 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 goal will be to inject below parting pressure. Is a 10-403 required to perform these? Thanks, Tim . S. Schneider Subsurfoce Development Staff Production Engineer WNS- Alpine 'a' Phone: 907-265-6859 ~ Fax: 907-2656472 pi Mobile: 907-632-8136 Email: t{m_sschnei_der@conocophillips.com 9/15/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEI~E® APR 1 S 2008 1.Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q e 8S f1S. ommlSSl Alter Casin g ^ Pull Tubin g ^ Perforate New Pool ^ Waiver Anch~ge ^ 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 0 ~ Exploratory ^ 200-006 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20324-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 37' CD1-27 8. Property Designation: 10. Field/Pool(s): ADL 25559 &ADL 372095 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 11492' feet true vertical 7050' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' SURF CASING 2566' 9-5/8" 2622' PROD CASING 8444' 7" 8500' OPEN HOLE 2992' 6-1/8" 11492' ~~ r '~~ANN~~ MAY $ 200 Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 8153' MD. Packers &SSSV (type & measured depth) pkr= BAKER S3 PACKER pkr= 8065' SSSV= SSSV ; NIP SSSV= 1822' ; 1822' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~~ ~ •r °~ ~r~j! ) ¢~ 2~~~ ~.. 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 2716 2205 1995 800 200 Subsequent to operation 4811 • 5420 518 1147 253 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 • 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: 308-022 Contact Printed Name Tim hneider Title Signature ~ ~//1 Phone 265-6859 Date -~7~'D~ Form 10-404 Revised 04/2004 ~ R I ~ Submit Original Only • • CD1-27 Stimulation Results Summary of stimulation job: 3-08-08: Pump frac in two stages: The first frac ramped from 2-12 ppa; 1600 bbls slurry for the first stage with a 360 bbl flush and ramped 2-9 ppa for the 2"d stage, 1250 bbls slurry, 50 bbls diesel for freeze protect and 87 bbls SW flush. First Frac: AIR-30 BPM, AIP-1979 psi, ISIP-2101 psi, 271,000 lbs. 16/30 Badger sand in perfs. Second Frac: AIR- 30 BPM, AIP-1979 psi, ISIP-2101 psi, 158,000 Ibs, 16/30 Badger sand in open hole. Well test: 4/15/08: 4811 bopd, 518 bwpd, 5.4 mmcfpd, 253 WHP • o- e~ ~~~ i~` ~" ~ ~ ~ ~~ ~ ~~ ~-~ ~ SARAH PAUN, GOVERNOR CO~S+~t~p~j~*O O ~ I ~ 333 W. 7th AVENUE, SUITE 100 ~4i~ .Li •••~~.~~~uuu---~~iiil ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Barreda Production Engineer Conoco Phillips Alaska, Inc. ~~~~ .)A~ ~ ~QC PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-27 Sundry Number: 308-022 ~~ ~ ~j Dear Mr. Barreda: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of January, 2008 Encl. J ~~• ~~~ STATE OF ALASKA (.`~ 'y ALASKA OIL AND GAS CONSERVATION COMMISSION R~~E1~i,ED JAN ]. 7 ~~aos APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.2so Alaska Oil & Gas Conf R Commission 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ W i rC Other ,,^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class. 5. Permit to DriN Number: ConocoPhiAips Alaska, InC. Development ^ Exploratory ^ 200-006 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20324-00 " 7. If pertorating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS NO ^ CD1-27 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25559 &ADL 372095 ~ RKB 37' Colville River Field i Alpine Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11492' ' 7050' - Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURF CASING 2566' 9-5/8" 2622' PROD CASING 8444' 7" 8500' OPEN HOLE 2992' 6 1/8" 11492' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1 /2" L-80 8153' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER S3 PACKER pkr= 8065' SSSV= SSSV ; NIP SSSV= 1822' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development [] ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 15, 2008 Oil ^ ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brian Barreda Title: Production Engineer Printed Name ,Bri n Barreda `~ Signature rr.- ~rrkK ~i, yj~~4 Phone 670-4798 Date 1!16/08 Commission Use Only SundryNumber: `~ ~ ' Conditions of approval: Notify Commission so that a representative may witness ~~x-/CJ ~ ^' Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. ~~ ~ ~ ~~~$ / ~ ; Subsequent Form Required: ~~y ' APPROVED BY •' D D ,'" (~ Q ate: (J Approved by: C MISSIONER THE COMMISSION Form 10-403 Revised 06/2006 n' ~ t ubmit in Duplicate • • Overview: ~ . CD1-27: 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 osi, add breaker as per lab results. Maintain 2000-3000 psi on the IA during the treatment. • 100 bbls YF125ST Pad • 100 bbls YF125ST w/ 2 ppa 16/30 White Sand • 170 bbls YF125ST w! 4 ppa 16/30 White Sand • 250 bbls YF125ST w/ 7 ppa 16/30 White Sand • 40 bbls YF125ST w/12 ppa 16/30 White Sand Repeat treatment above 4 times. • Flush the last stage with linear YF125ST and freeze protect Total Sand: 450,000 lbs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ¡' J 7 Y:', ,;'" SCl~NED APR 1 0 2007 ;).ftJ - ()O (¡; Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells :trom 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 2/1612007 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 2/1612007 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 CDI-27 & CDI-28 report ofSCP e e Tom & Jim, ~ Producers CD1-27 (PTD 200-006) & CD1-28 (PTD 200-199) both failed TIFLs yesterday and have been added to the SCP report. The TxlA communication is suspected to be due to a leaky GLV check valve. New GL Vs will be installed in an attempt to fix the TxlA comm. Attached are schematics and 90 day T/IIO plots. Please let me know if there are any questions. clCf' ';;;'i.·. ~}"Nj· ì!\",,",: :,::;;'~:'_'I I, :[ Marie McConnell Problem Well Supervisor 659-7224 «CD1-28.pdf» «CD1-27.pdf» «cd1-27 90 day TIO Plot 4-20-06.gif» «cd1-28 90 day TIO Plot 4-20-06.gif» Content-Description: CDl-28.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: CDl-27.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: cdl-27 90 day no Plot 4-20-06.gif cdl-27 90 day TIO Plot 4-20-06.gif Content-Type: image/gif Content-Encoding: base64 Content-Description: cdl-28 90 day no Plot 4-20-06.gif cdl-28 90 day TIO Plot 4-20-06.gif Content-Type: image/gif Content-Encoding: base64 1 of 1 4/26/200612:51 PM ;d of 4/26/2006 12:49 PM 5 F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~.".. ~1~: '. .,J r :...... .., . ConocOPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7"' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment Alpine Cement Top Fill Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual 404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: · Tom: Last week we had a cement crew go down the line at Alpine, top filling · the conductors with cement. I believe 34 wells were treated. Chuck Scheve · and John Crisp were notified but declined to witness when we told them what · we were doing. Some time past we had agreed to submit a 10-404 for this · kind of work. Due to the number of these, is a 10-404 needed on each well? · I don't want to commit the time to doing this if it is not necessary; · 10-404's are time consuming to prepare. Would a list of the jobs suffice, · or something similar? We have the well numbers, depth to cement top, and · sacks used to fill the void. My proposal would not affect future · submissions of 10-404's for this work. What do you think? Thanks! · · Jerry Dethlefs (See attached file: tom_maunder.vcf) 1 of 2 4~24~2003 7:55 AM Alpine Cement Top Fill ~r~AOGCC ALPINE cement top outs 04-16-03.xls Name: AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 r"~Cement Top Fill AOGCC Letter 04-23-03.doc Name: Cement Top Fill AOGCC Letter 04-23-03.doCl Type: WINWORD File (application/msword) I Encoding: base64 I Tom Maunder <tom maunder~,admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 4~24/2003 7:55 AM ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS -- BBLS Cement CD1-1 2,25' 0,3 WI 1,8 CD1-2 4' 0,6 WI 3,6 CD1-3 10' 1,4 MI ; 8,5 CD1-4 7,33' I P 6.0 cD1---5 4-r 0,6 MI 3,6 CD1-6 10.42' 1-14 Gl 8.5 CD1-16 14.33' 2 WI 12.1 .... CD1-17 8.~5' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 CD1-22 t,83' 0,3 P-' 1,--~ CD1-23 15,42' 2,1 U-[ 12,7 CD1-24 2' 0,3 P .... ;i',8 CD1-25 5,66' 0,8 P 4,8 CD1-27 18,83' 2,6 P 15,7 CD1-28 6,75' 1 P 6,0 CD1-32 8,33' 1,2 P 7,2 CD1-34 41,83' 5.7 P 34,4 cD1-36 16,75' 2.3 WI 13,9 CD1-38 3.5' 0,5P 3,0 CD1-42 5,83' 0,8 MI 4,8 c'D2-16 11,66' 1.6 INJ --9,7 CD2-17 18' 2,5 INJ 15,1 CD2-19 11,66' 1,6 P 9.7 CD2-22 13,5' 1,8 INJ 10,9 C D2---2-~--- ~,-25' '------~-7' P-- 22.3 CD2-26 10.42' 1.4 INJ 8,5 CD2-32 8,5' 1,2 INJ 7,2 CD2-33 -- 7' 1 P 6.0 CD2-34 4' 0,6 P 3,6 CD2-41 11,83' 1,6 P 9.7 cD2~6 7,42' 1 INJ 6,0 CD2-48 10,33' 1.4 INJ 8.5 CD2-49 9.33' .1,3 INJ 7,8 CD2-50 1,66' 0.25 P 1.5 DATA SUBMITTAL COMPLIANCE REPORT 312112002 Permit to Drill No. 2000060 Well Name/No. COLVILLE RIV UNIT CD1-27 Operator PHILLIPS ALASKA INC. API No. 50-103-20324-00-00 MD 11492 TVD 7050 Completion Date 312/2000 J Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N_~o Samples N._~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name ~/~'~ 'SRVY RPT ~//GR/RES-MD JGR/RES-TVD L~ SRVY CALC (data taken from Logs Portion of Master Well Data Maint) Log Log Scale Media Run No Interval Start Stop OH / Dataset CH Received Number Comments 25 25 FINAL FINAL 115 11492 2651 11492 2400 7060 0 11492 OH 3~9~2000 SCHLUM OH 4/10/2000 ~ ~ OH 4110/2000 /~b- OH 4/18/2000 BHI O 4110/2000 09495 2651-11492 ~V-~il Co~s)Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Rcceivcd? Analysis Received? Daily History Rcc~ived? Formation Tops R¢ccuivcd? Comments: Compliance Reviewed By: Date: APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ '13me extension _ Stimulate _X Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 407' FNL, 2888' FEL, Sec. 5, T11N, R5E, UM At top of productive interval 1053' FSL, 1329' FEL, SEC. 5, T11 N, R5E, UM At effective depth At total depth 1786' FNL, 5134' FEL, Sec. 9, T11N, R5E, UM 5. Type of Well: Development ._X Exploratory _ Stratigraphic _ Sewi~__ (asp's 385816, 5975721) (asp's 387327, 5971883) (asp's 388770, 5969018) 6. Datum elevation (DF or KB feet) RKB 56 feet 7. Unit or Property name Colville River Unit 8. Well number CD1-27 9. Permit number / approval number 200-006 10. APl number 50-103-20324 11. Field / Pool Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 114' SURF CASING 2566' PROD CASING 8444' OPEN HOLE 2992' OPEN HOLE Size 16" 9-5/8" 7" 6.125" 11492 7050 11492 7050 feet Plugs (measured) feet feet Junk (measured) feet Cemented 10 cu yds Portland Type 3 409 Sx AS III Lite, 233 Sx Class G 143 Sx Class G Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 Tbg O 8153' MD. Measured Depth Trueverfical Depth 114' 114' 2622' 2366' 8500' 7062' 11492' RECEIVED Packers & SSSV (type & measured depth) BAKER S3 PACKER O 8065' MD. CAMCO BAL-O LANDING ~ 1822' MD. 13. Attachments Description summary of proposal ~ Detailed operations program _ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: April 19, 2001 16. If proposal was verbally approved Oil _X Name of approver Date approved Service 17. I hereby, certify that the foregoing is true and correct to the best of my knowledge. Signe 0 Title: Alpine Production Engineer Gas __ Suspended _ Questions? Call Michael Erwin. ¢~ 265-1478. Prepared b~ Sharon Al~sup-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity __ BOP Test _ Location clearance _ Mechanical Integrity Test_ Subsequent form required lo- ORIGINAL SIGNED ..... Approved bYOrder of the Commission D Taylor Seamount Commissioner Approval no. ORIGINAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLI CATE Stimulation Procedure Colville River Field CD1-27 Conversion operations will commence following ice road construction on or about April 1, 2001. Completion is expected on or about April 15, 2001. This procedure is designed to clean out and stimulate a newly drilled producer. The goal is to remove filtercake, drilled solids, and polymer from the openhole completion. 1. RU coil tubing unit. GIH with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with diesel. 2. Spot +/-110 bbl. of DS MudSolv mixed in a 9.2 ppg KCL base fluid in the openhole interval. 3. POOH and RD coil tubing. 4. Allow the breaker to soak for 24 hours. 5. Return the well to production. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 56 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 servia__ Colville River Unit 4. Location of well at surface 8. Well number 407' FNL, 2888' FEL, Sec. 5, T11 N, R5E, UM (asp's 385816, 5975721) CD1-27 At top of productive interval 9. Permit number / approval number 1053' FSL, 1329' FEL, SEC. 5, T11 N, R5E, UM (asp's 387327, 5971883) 200-006 / At effective depth 10. APl number 50-103-20324 At total depth 11. Field / Pool 1786' FNL, 5134' FEL, Sec. 9, T11 N, R5E, UM (asp's 388770, 5969018) Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured 11492 feet Plugs (measured) true vertical 7050 feet Effective depth: measured 11492 feet Junk (measured) true vertical 7050 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" lO cu yds Portland Type 3 114' 114' 409 Sx AS III Lite, 233 Sx Class 2622' 2366' SURF CASING 2566' 9-5/8' PROD CASING 8444' 7" 143 Sx C~ass G 8500' 7062' OPEN HOLE 2992' 6.125' 11492' Perforation depth: measured None RECEIVED true vertical NoneAPR 2 7 ZOOt Tubing (size, grade, and measured depth) 4.1/2", 12.65, L-80 Tbg O 8153' MD. , CO/~,~/0/] Packers & SSSV (type & measured depth) BAKER S3 PACKER e 8065' MD. CAMCO BAL-O LANDING ~ 1822' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached description Treatment description including volumes used and final pressure 14. Representative Daily Avera._qe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4179 4571 0 233 Subsequent to operation 4571 4160 0 226 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations _~ Oil _X Gas __ Suspended ~ Service 17. I ~y certify that the foregoing is true and correct to the best of my knowledge. Signed/Mehael Erwin~'~~ ~ ~ Title Alpine Production Engineer Datpre;aredbySharonA/isup~Orake£8$.4el~, ORIGINAL Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE CD1-27 Description of Work Completed CT Enzyme Treatment 4/19/01' ENZYME TREATMENT COMPLETED. TREATED OPENHOLE SECTION FROM 11300' TO 8500' W/ 127 BBLS OF DOWELL MUDSOLVE PRODUCT. RETURNS .8 TO 1 DURING TREATMENT. UTILIZED BOTH CT STRAIGHTENER & FDR TO MAKE DEPTH BUT SHORT OF TD @ 11492'. FREEZE PROTECTED WELLBORE TO 2000' W/30 BBLS OF DIESEL. WELL TO REMAIN SHUT IN UNTIL FLOWBACK COMPLETED. 4/20/01' POST ENZYME TREATMENT FLOWBACK COMPLETED. FLOWED BACK 419 BBLS ( 90 BBLS OF DIESEL, 100 BBSL OF MUDSOLV, 229 BBLS OF CRUDE, & 218 MSCF OF GAS). SAMPLES SHOWED A NASTY EMULSION THEN CLEANED UP TO 100% CRUDE AT THE END OF THE FLOWBACK. RETURNED THE WELL TO PRODUCTION PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 April 24, 2001 RECEIVED APR 5 2.001 Ms. Wendy Mahan Natural ResourCe Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: KuPamk Area Annular. Disposal, First Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the first'quarter of. 200'1,' as well as total volumes disposed into annuli for which disposal authorization expired during the. first quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike .Mooney. · 'Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / SnOdgrass B. Morrison and M. Cunningharn SharOn Allsup-Drake Well Files Annular Dis ~osal durin ; the first quarter of 2001: zoo - o $'5' 2.oo-loo 7,oo-101, ' h(1) h~(2) h(3~ Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date CD1-44 8929 100 0 9029 22899 31928 Dec. '00 Jan.'01 cpi-a3, COl-NQ1, ¢m-10, ¢ol-25 2N-318 12276' 100 0 12376 1619 13995 Dec.'00 Jan.'01 2N-314 CD1-43 30552 100 0 30652 385 31037 Jan.'01 Feb.'01 CD1-NQI~ CD1-21 CD1-31 6698' 100- 0 6798 392 7190 Feb.'01 Mar.'01 CDI-14 1D-42 17187 '100 0 17287 15118 ' 32405 Dec.'00 Jan.'01 1D-37~ 1D-39 1D-32 23162 100 0 23262 337 .23599 Jan.'01 Feb.'01 1D-39 1J-03 13020 100 0 13120 0 13120 Mar.'01 Mar.'01 1J-09~ 1J-14 Total Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2001: Z.L>O - o1,:, _ Total- ume Start End Source Wells Total h(1) Total h(2) Total h(3). Injected. Date Date Well Name Volume Volume Volume Status of Annulus 1L-28 9837 100 0 9937 Open, Freeze Protected March 2000 April 2000 1L-20A, 1L-26A CD1-27 .32714 -100 0 32814 Open, Freeze Protected May 2000 June 2000 CD1-44, CDI-19A, CD 1-09, CD 1-06 CD1-38 20220 100 0 20320 Open, Freeze Protected March 2000 May 2000 CD1-44, CD1-41, CD1- 19A CD1-05 286' 100_ 0 ' 386 Open, Freeze Protected Jan. 2000 Jan. 2000 CD1-05 CD1-03 33890 100 0 33990 Open, Freeze Protected Aug. 2000 Sept. 2000 CD1-43, CD1-31, CD1--~ 30 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 25, 2000 Ms. Wendy Mahan Natural Resource Manager. Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli . during the second quarter of 2000, as well as total.volumes injected into annuli for which injection authorization expired during the second quarter of 2000. Annular In}ection durin$ the' second quarter of 2000: ' h(l) h(2) h(3) Total for previous New Well Name Volume Volume Volume Quarter Total Total 2N-341 20406 100 0 20506 0 20506 2L-313 4640 100 0 4740 12533 17273 CD1-40 108 100 0 208 32669 32877 CD1-23 16751 100 0 16851 17135 33986 CDI-16 25 0 0 25 29025 29050 CD1-32 82 100 0 182 33331 33513 CD1-38 11056 100 0 11156 9164 20320 CD1-27 32333 100 0 32433 381 32814 1L-28 5853 100 0 5953 3984 9937 ~ 1D-11 135 100 0 235 0 235 1D-14 1337.6 100 0 1437.6 0 1437.6 / CD1-25 8141 100 0 8241 386 8627 CD1-34 278 100 0 378 0 378 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Robert Christenson, .,~:~..,,, Chairman Blair Wondzell, P. I. Supervisor FROM: Jeff Jones/'(/-~~ SUBJECT: Petroleum I~l'sp6dtor DATE: May 29, 2000 Diverter Function test Doyon 141 MPF-81 MPU Development Non. Confidential Sunday, May 28, 2000; I traveled to BPX's MPU to witness the Diverter Function test on well # MPF-81, where Doyon Rig #141 was rigging up to spud. The rig was fairly close to being completely rigged up. 'The layout of the 16" vent line was such that it provided for down wind venting of the gas and allowed for escape from the pad if necessary. The gas detectors were tested during the function test and operated properly. The Doyon crew performed the Diverter Function Test in a safe and proficient manner. The vent line was not tied down when I arrived, but this was accomplished during the function test. I found the rig and the surrounding area orderly and quite clean. SUMMARY: I witnessed the Diverter Function test on Doyon 141 drilling well # MPF-81 Attachments: Diverter Doyon 141 5-29-00 JJ.XLS cc: Tim Burns(PBU DRLG ENG.) NON-CONFIDENTIAL Diverter Doyon 141 MPF-81 5-29-00 JJ STATE OF ALASKA {' ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Date: Operation: Development X Exploratory: Drlg Contractor: Doyon Rig No. 141 PTD # 200-066 Rig Ph. # Operator: BPX Oper. Rep.: Jim Pyron Well Name: MPF-81 Rig Rep.: Jim Willin~lham Location: Sec. 12 T. 13N R. 09E Merdian UM 5~29~00 659-0318 MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: P Well Sign: P Systems Pressure: 3000 psig Housekeeping: P (Gen.) Drlg. Rig: P Pressure After Closure: 2200 psig Reserve Pit: NIA Flare Pit: NIA 200 psi Attained After Closure: 0 min. . 4.__.~0 sec. Systems Pressure Attained: 2 min. 42 sec. DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: Diverter Size: 21.25 in. psig Divert Valve(s) Full Opening: P Valve(s) Auto & Simultaneous: P MUD SYSTEM INSPECTION: Light Alarm Vent Line(s) Size: 16 in. Trip Tank: P P Vent Line(s) Length: 70 ft. Mud Pits: P P Line(s) Bifurcated: N/A Flow Monitor: P P Line(s) Down Wind: P Line(s) Anchored: P GAS DETECTORS: Light Alarm Turns Targeted / Long Radius: NIA Methane P P Hydrogen Sulfide: P P ~ Diverter Vent Line r,D Shop Camp Drlg Rig 'Motors I N IPipe Shed I I W ~'~---~ E ~r Wind S Non Compliance Items 0 Repair Items Withir NIA Day (s) And contact the Inspector @ 659-3607 Remarks: Rig in good shape Distribution orig. - Well File c - Oper/Rep c- Database c - Trip Rpt File c- Inspector AOGCC REP.' Jeff Jones OPERATOR REP.: Diverter Doyon 141 5-29-00 J J1 Jim Pyron DVTRINSP.XLT (REV. 1194) ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 17, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: CD 1-27 (Permit No. 200-06) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on CD 1-27. If there are any questions, please call 263-4792. Sincerely, D.~e~ter ~~r"~"' Alpine Drilling Team Leader AAI Drilling DC/skad ORIGINAL RECEIVED APR 1 8 ~000 A_.rr,~k~ Oil & O~ Con~. Gommi~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r'~ Gas [~ Suspended r-] Abandoned r-] Service D 2. Name of Operator V['J~,~_~ 7. Permit Number ARCO Alaska, Inc. i~,..~. ~"~ 200-06 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 .._.,,,.,,.,.,..,, 50-103-20324-00 4. Location of well at surface ................... =9. Unit or Lease Name . · Colville River Unit 408' FNL, 2391' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385816.1, 5975721.2) ~. ,, .... ,. At Top Producing Interval i . ~.-~.'-"~v"~.. '...~__~....~ 10. Wall Number 1053' FSL, 1329' FEL, Sec. 5, T11N, R5E, UM (ASP: 387327.4, 5971882.9) '; ,. :::.,..;...: [. CD1-27 At Total Depth i--~II'I~ ..... ii 11. Field and Pool 1790' FNL, 148' FWL, Sec.9, Tll N, R5E, UM (ASP: 388769.6, 5969018.2) "- ........................ Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool DF 56 feetI ADL 25559/372095 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions February 16, 2000 February 27, 2000 March 2, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11492' MD/7050' TVD 11492' MD/7050' TVD YES r'~ No r"lI 1822, feet MD 1663' 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 RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 115' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2621' 12.25" 409 sx AS III Lite, 233 sx Class G 7" 26# L-80 Surface 8500' 8.5" 143 sx Class 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" 8153' 8065' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) ,. AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on Facility Start-Up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. CD1-27 Top Alpine 8276' 7012' TD 11492' 7049' Annulus left open - freeze protected with diese ORIGINAL $1. 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 Brian Robertson 265-6034 Signed Title Drillina Team Leader Date '3~/,,~4/~L.i ~ Chester Prepared by Sharon AIIsup-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 PL~13~~~3~,e~l~Injection, Gas Injection, Shut-in, Other-explain.~,l[~r,..i v i;.;,,i,~' Item 28: If no cores taken, indicate "none". Form 10-407 18 Na t a 0il & Gas Cons. Commission chot Oo Date: 03/23/00 ( REGEIVED sc. APR 1 8 000 WELL SUMMARY REPORT Alasl(a & Gas Cons. Commi Page: 1 WELL:CD1-27 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: ALPINE SPUD:02/16/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20324-00 02/15/00 (D1) MW: 8.7 VISC: 300 PV/YP: 34/108 APIWL: 12.4 TD/TVD: 114/114 (114) DRLG @ 350' SUPV:LUTRICK / GOLDBERG Standby. Damaged ARCO sow while connecting to GIS. Move GIS. Move rig to CD1-27. NU riser and flowline. Accept rig @ 1830 hrs 2/15/00 02/16/00 (D2) MW: 9.6 VISC: 180 PV/YP: 8/40 APIWL: 17.6 TD/TVD: 2415/2192 (2301) TD @ 2631' MD. POOH TO RUN 9-5/8" CASING SUPV:REYNOLDS / GOLDBERG PJSM. Perform diverter test. Spill drill. Drill ice in conductor to 115'. Drill from 115' to 2415'. 02/17/00 (D3) MW: 9.7 VISC: 57 PV/YP: 12/20 APIWL: 15.0 TD/TVD: 2631/2373 (216) TESTING BOPE. SUPV:REYNOLDS / GOLDBERG Drill from 2415' to 2631'. Circulate sweep-large amount of cuttings-circulate until hole clean. Observe well, static. POOH wet t/1587'. RIH with no problems. Circulate sweep, more cuttings to surface, circulate hole clean. Observe well, static. PJSM. RIH w/9-5/8" casing. Wash through tight spots from 1320' to 1440'. PJSM. Pump cement. Bumped plug. Floats held. ND diverter. 02/18/00 (D4) MW: 9.7 VISC: 43 PV/YP: 9/19 APIWL: 8.2 TD/TVD: 3135/2797 ( 504) NO DIESEL SHOWS OR FUMES PRESENT AFTER DRILLING OUT SU SUPV:REYNOLDS / GOLDBERG Install SSV. NU BOPE. Test to 250/3500 psi. Pull test plug. RIH with HWDP. Drill FC, cement, FS & 20' new hole to 2651'. Perform LOT, FIT @ 16 ppg EMW. Displace to LSND mud. POOH for failed GR response in MWD. Preprogram MWD. RIH. PJSM. Wash & ream from 2594' to 2651'. Drill from 2651' to 3135' ',., 02/19/00 (D5) MW: 9.7 VISC: 40 PV/YP: 8/24 APIWL: 5.9 TD/TVD: 5712/4958 (2577) DRILLING AHEAD @ 6469' MD. SUPV:REYNOLDS / GOLDBERG Drili from 3135' to 3641'. Circulate hivis sweep. Sweep brought small load of cuttings to surface. POOH to Shoe @ 2621'. RIH. No hole problems. Drill from 3641' to 4497' Oil shows & smell @ 4400'. Drill from 4497' to 5638'. Circulate hivis sweep and continue to circulate until hole clean. Monitor well, static. POOH to 3546'. Drill from 5638' to 5712' {' Date: 03/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 02/20/00 (D6) MW: 9.6 VISC: 40 PV/YP: 7/16 APIWL: 5.6 TD/TVD: 7542/6501 (1830) DRILLING AHEAD @ 7573' WITH BUILD ASSEMBLY BHA 94. SUPV:REYNOLDS / GOLDBERG Drill from 5712' to 7542'. Circulate around hivis sweep & circulate until hole cleaned up. Observe well, static. POOH 10 stands, RIH to bottom, no hole problems. CBU until hole clean. Monitor well, static. POOH. 02/21/00 (D7) MW: 9.7 VISC: 41 PV/YP: 9/15 APIWL: 5.0 TD/TVD: 8276/7012 ( 734) TD'D WELL @ 8510' MD. PROJECTED: 7063 TVD. INC 88 DEG SUPV:REYNOLDS / REILLY RIH w/HWTDP and DP. CBU. Break circulation until hole clean. Drill from 7542' to 8276' 02/22/00 (D8) MW: 9.7 VISC: 50 PV/YP: 9/21 APIWL: 4.9 TD/TVD: 8510/7063 (234) CIRCULATING & CONDITIONING MUD FOR CEMENT JOB. SUPV:REYNOLDS / REILLY Drill from 8276' to 8510'. Circulate sweep until hole cleaned up. Observe well, static. POOH. PJSM. Run 7" casing. 02/23/00 (D9) MW: 9.6 VISC: 43 PV/YP: 9/21 APIWL: 5.1 TD/TVD: 8510/7063 ( 0) DRILLING OUT SHOE. SUPV:REYNOLDS / REILLY Run 7" casing to 8500'. Circulate and condition mud for cement job. PJSM. Pump cement. Install packoff and test to 5000 psi. Test choke manifold to 250/3500 psi. PU DC's. Shallow test MWD. MWD turns on but does not receive good date. Test PBL and retrieve balls. Plastic ball split in half leaving piece in DS. Deep test MWD. MWD will not turn on. Suspect missing part of plastic ball jamming stator in MWD. POOH. Change out MWD. RIH. Test MWD, ok. 02/24/00 (D10) MW: 9.2 VISC: 44 PV/YP: 9/23 APIWL: 5.4 TD/TVD: 9160/7082 (650) POOH TO PU NEW MWD. SUPV:REYNOLDS / REILLY RIH. Circulate and condition mud. Test 7" casing to 3500 psi, OK. Drill cement and 20' new hole from 8385' to 8530' Perform FIT to 11.5 ppg EMW. Displace well to 9.2 ppg flo-pro mud system. Drill from 8530' to 8550'. CBU. 02/25/00 (Dll) MW: 9.2 VISC: 45 PV/YP: 9/23 TD/TVD: 9517/7074 ( 357) DRILLING AHEAD @ 9905' SUPV:REYNOLDS / REILLY RECEIVED APIWL: 4.6 Drill from 9160' to 9382'. Observe well, static. Pump out to 8297'. Trip in to 9328'. Pump lo-hi vis sweep around. Pump out to 7917'. Monitor well @ 8494' and 7917', static. POOH wet. Pulling slow. Dropped dog collar nut in well while preparing to change out MWD. Drained stack - found nut. Fish out nut. RIH. Drill from 9328' to 9517' APR Oil & Gas Cons. Commi$~m Anchorage ,, ( RECEIVED Date: 03/23/00 ARCO ALASKA INC. Page: 3 APR 1 8 000 ~aska ~i & Gas Cons. Commi~ion 02/26/00 (D12) MW: 9.2 VISC: 46 PV/YP:~~ APIWL: 4.4 TD/TVD:10901/7051 (1384) DRILLING AHEAD @ 11255. ECD=10.8 PPG. DECIDED TO FOR SUPV:REYNOLDS / REILLY Drill from 9517' to 10901'. 02/27/00 (D13) MW: 9.2 VISC: 27 PV/YP: 1/ 2 APIWL: 0.0 TD/TVD:l1492/7050 ( 591) LD MOTOR & MWD. SUPV:REYNOLDS / REILLY Drill from 10901' to 11492'. take final survey. Pump lo-vis sweep. Pump out to shoe to 8463'. CBU. Monitor well, static. RIH to 11492'. No hole problems encountered. Pump around lo-vis sweep. Hole extremely clean. PJSM. Change out flow-pro with brine. 02/28/00 (D14) TD/TVD:l1492/7050 ( SUPV:REYNOLDS MW: 9.2 VISC: 27 PV/YP: 1/ 2 APIWL: 0.0 0) PU BHA TO FISH PACKER AND TAILPIPE ASSEMBLY. POOH to shoe ~ 8500'. Monitor well - losing 18 bph. Continue to POOH to 3900'. Retrieve wearring. Found junk on top of wear ring and running tool. PJSM. RIH w/4.5" tubing with completion. Set packer @ 2847'. RIH with retrieving tool. Attempts made to latch onto rod and ball. Entire retrieving tool came to surface without rod &ball. PJSM. RIH w/chemical cutter. 02/29/00 (D15) MW: 9.2 VISC: 70 PV/YP: 8/ 1 APIWL: 10.5 TD/TVD:l1492/7050 ( 0) FISH RETRIEVED TO SURFACE. CUT TAILPIPE BELOW PACKER SUPV:REYNOLDS/ROBERTSON RIH w/chemical cutter. Cut tubing @ 2847'. CBU. POOH with 4.5" tubing. Set bowl protector. RIH w/fishing assembly. Screw in @ 2780'. PJSM. Wash to 2847'. Mill on packer. Slips on packer spinning. Spot nutplug pill. Continue to mill on packer. Start losing fluid when milled past rubber. CBU. Pull up to see if pkr is free. Had movement. Set back down to continue milling. POOH w/ fish. No fish. RIH w/fishing assembly. 03/01/00 (D16) MW: 9.2 VISC: 27 PV/YP: 1/ 2 APIWL: 0.0 TD/TVD:l1492/7050 ( 0) MU AND TEST SSSV CONTROL LINES SUPV:LUTRICK/ROBERTSON RIH. Spear fish @ 8500'. POH w/fish. Complete recovery. RIH to 8100'. Pump viscous pill. PJSM. RIH w/4.5" completion equipment. 03/02/00 (D17) MW: 9.6 VISC: 27 PV/YP: 1/ 2 APIWL: 0.0 TD/TVD:l1492/7050 ( 0) SPOT RIG ON CD1-25 SUPV:LUTRICK/ROBERTSON RIH w/4.5" completion. MU SSSV. Attach control lines and test to 5000 psi. RIH. MU hanger. Test control line seals to 5000 psi. Test hanger seal to 400 psi. Test hanger to 5000 psi. ND BOP. NU tree and test to 5000 psi. PJSM. Pump brine and diesel. Release rig @ 0000 hrs. 3/3/2000. · .. . 'iii · - ..ii'- :J' i-.:.i - , .,- -i. - i ,:; .~ .. -., ,..· · .- , · i " · '" · " J ' i ' ' ' I " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00013 Sidetrack No. Page 1 of 6 / II '- [I [e-] '-- 1:3[--1 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/27 Survey Section Name CD1-27 MWD BHI Rep. GEHRES / MILCHAK ltN""r~~ WELL DATA Target TVD (F-r) Target Ooord. N/S Slot Ooord. N/S -408.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Ooord. F_/W Slot Ooord. FJW 2391.0t3 Magn. Declination 25.8g0 Calculation Method MINIMUM CURVATURE Target Direction (DD) Builc~Walk\DL per: 103ft~ 30rnFi 1omi-I- Vert. Sec. Azim.' 157.1g Magn. to Map Corr. 25.8g0 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 ~ (DD) (DD) (FT) (F-l") miT) (F'r) (Per 100 FT) Drop (-) Left (-) 0.03 0.03 0.03 0.00 0.00 0.03 0.00 TIE IN POINT 16-FEB-00 MWD 115.00' 0.00 0.00 115.00 115.00 0.00 0.00 0.00 0.00 0.00 9 1/2" MlC 1.4 DEG AKO 16-FEB-00 MWD ' 174.00 0.25 ..355.00 59.00 174.00 -0.12 0.13 -0.01 0.42 0.42 GSS 16-FEB-00 MWD 297.69 1.51 -. 197.11 123.69 297.68 0.87 -1.16 -0.51 1.41 1.02 16-FEB-00 MWD 388.32 3.47 175.07 90.63 368.22 4.40 -5.04 -0.63 2.37 2.16 16-FEB-O0 MWD 475.22 5.81 174.24 86.90 474.63 11.11 -12.03 0.04 2.69 2.69 -0.96 16-FEB-O0 MWD 565.71 8.54 170.93 90.49 564.60 22.01 -23.23 1.56 3.05 3.02 -3.66 16-FEB-00 MWD 656.89 10.50 175.27 91.18 654.52 36.49 -38.19 3.31 2.29 2.15 4.76 I bL;I--IVI-I 16-FEB-(X)- MWD 837.93 14.08 171.65 90.19 831.46 73.16 -76.08 7.81 2.28 2.24 -1.77 16-FEB-00 MWD 926.16 16.55 165.21 68.23 916.56 96.00 -98.86 -- 12.58 3.40 2.80 -7.30 AP~ '1 8 16-FEB-O0 MWD 1016.79 19.42 163.01 - 90.63 1002.75 123.78 -125.75 20.28 3.25 3.17 -2.43 ,,_-__-,_., r~l ~ ~=_, c~.~. Cammissi0n 16-FEB-00 MWD 1112.03 22.82 159.87 95.24 1091.59 157.99 -158.24 31.26 3.76 3.57 -3.30 16.FEB-00 MWD 1206.80 25.96 159.07 94.77 11 77.89 197.09 -194.88 45.00 3.33 3.31 -0.84 16.FEB-00 MWD 1301.92 28.1-1 159.19 95.12 1262.61 240.30 -235.28 60.40 2.26 2.26 0.13 16-FEB-00 MWD 1397.36 30.93 158.24 95.44 1345.65 287.30 -279.09 77.48 3.00 2.95 -1.00 16-FEB-00 MWD 1492.32 33.80 156.00 94.96 1425.86 338.12 -325.89 97.28 3.28 3.02 -2.36 16-FEB-00 MWD 1587.25 32.86 155.97 . 94.93 1505.17 390.27 -373.54 118.51 0.99 -0.99 -0.03 16-FEB-00 MWD 1 681.93 31.59 155.03 94168 1585.26 440.73 -419.48 139.44 1.44 -1.34 -0.99 16-FEB-O0 MWD 1777.07 33.03 155.88 95.14 1665.67 491.56 -465.74 160.55 1.59 1.51 0.89 16-FEB-00 MWD 1870.55 34.09 157.17 93.48 1743.57 543.23 -513.14 181.13 1.37 1.13 1.38 16-FEB-00 MWD 1967.41 35.21 156.76 96.86 1823.25 598.30 .563.82 202.68 1.18 1.16 -0.42 16'FEB-00 MWD 2063.95 34.63 156.29 96.54 1902.41 653.55 -614.50 224.69 0.66 -0.60 -0.49 16-FEB-00 MWD 2158.98 34.57 156.53 95.03 1980.63 707.51 ' -663.96 . 246,29 0.16 -0.06 0.25 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00013 Sidetrack No. Page 2 of 6 rd -' I =[-,1 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD I I/ Well Name & No. PAD CD#1/27 Survey Section Name CD1-27 MWD BHI Rep. GEHRES / MILCHAK JrJ~Jl"~l~ WELL DATA Target TVD (FO Target Coord. N/S Slot Coord; N/S -408.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS~ Target Description Target Coord. F_.JW. Slot Coord. E/W 2391.00 Magn. Declination 25.890 Calculation Method MINIMUM CURVATURE Target Direction (DD) BuilcflWalk\DL per: 100ft~ 30m[-] 10m0 Vert. Sec. Azim. 157.19 Magn. to Map Corr. 25.890 Map North to: OTHER SURVEY DATA Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Build (+) Right (+) Comment Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (FT) (OD) OJO) (FO (FO {FO (FO . {Per 100 FO Drop (-) Left (-) 16-FEB-O0 MWD 2253.56 34.26 156.36 '94.58 2058.66 760.96 -712.96 267.65 0.34 -0.33 -0.18 16-FEB-O0 MWD 2348.39 33.65 157.00 94.83 2137.31 813.93 -761.60 288.62 0.75 -0.64 0.67 17-FEB.00 MWD '2443.02 33.42 ~. 157.67 94.63 2216.19 866.20 -809.84 308.76 0.46 -0.24 0.71 17-FEB-(X) MWD 2537.85 32.89 157.10 94.83 2295.58 918.07 -857.71 328.71 0.65 -0.56 -0.60 17-FEB.00 MWD 2589.59 32.99 156.94 31.74 2322.22 935.32 -873.60 335.44 0.42 0.32 -0.50 18-FEB-00 MWD 2724.00 32.59 157.71 154.41 2452.03 '1018.94 -950.76 367.68 0.37 -0.26 0.50 6 3/4" MIXL 1.2 DEG AKO 18-FEB-00 MWD 2819.80 32.15 157.29 95.80 2532.94 1070.23 -998.14 387.31 0.52 -0.46 -0.44 18-FEB-00 MWD 2914.00 33.33 158.13 94.20 2612.18 1121.17 -1045.28 406.63 1.34 1.25 0.89 18-FEB-O0 MWD 3008.00 33.39 158.02 94.00 2690.69 1172.86 -1093.23 425.93 0.09 0.06 -0.12 18-FEB.00 MWD 3104.00 33.57 157.72 96.00 2770.76 1 225.81 -1142.29 445.88 0.25 0.19 -0.31 .j ~----, ,~-~ e--""~~1 ~"Dj'- .- o..,? .o.,,o ,, ,.... . 19-FEB.00 MWD 3295.00 33.61 ' ,157.27 96.00 ' 2929.74 1331.68 -1240.04 486.53 0.13 .0.12 -0.07 2000 19-FEB.00 MWD 3389.00 33.65 156.28 94.00 3008.00 1383.73 -1287.88 507.06 0.58 0.04 -1.05 ~ J 19-FEB-00 MWD 3484.00 33.54 155.15 95.00 3087.14 1436.28 -1335.79 528.68 0.67 -0.12 -1.19 ,~/!~. ~I {~JJ & Gas Cons. (~;01111111~i~ _ 19-FEB-(X) MWD 3579.55 33.57 154.71 95.55 3166.76 1 489.05 -1383.63 551.06 0.26 0.03 -0.46 jl~nl~lol'a(~ 19-FEB.00 MWD 3673.55 33.10 154.13 94.00 3245.30 1540.65 -1430.22 573.36 0.60 -0.50 -0.62 19-FEB-C0 MWD 3769.59 32.67 1 54.22 96.04 3325.95 1592.72 -1477.16 596.07 0.45 -0.45 0.09 19-FEB-00 MWD 3863.99 33.77 158.21 94.40 3404.93 1644.40 -1524.47 616.90 2.59 1.17 4.23 1 g-FEB-00 MWD 3959.15 33.18 157.93 95.16 3484.31 1696.89 -1573.16 636.50 0.64 -0.62 -0.29 . 19-FEB-O0 MWD 4053.91 33.31 157.51 94.76 3583.56 1748.83 -1621.23 656.20 0.28 0.14 -0.44 19-FEB-00 ' MWD 4149.15 33.06 157.17 95.24 3643.26 1800.96 -1669.33 676.28 0.33 -0.26 -0.36 19-FEB-00 MWD 4243.89 32.79 156.88 94.74 3722.79 1852.46 -1716.74 696.38 0.33 -0.28 -0.31 __ 19-FEB.00 , MWD 4341.28 32.75 156.75 -97.39 3804.68 1905.17 -1765.20 717.13 0.08 -0.04 -0.13 19-FEB-00 MWD 4433.87 32.39 156.46 92.59 3882.71 1955.01 ;1810.95 . 736.92 0.42 -0.39 -0.31 :" ' " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00013 Sidetrack No. Page 3 of 6 Company ARCO ALASKA, INC. Rig'Contractor & No. Doyen Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/27 Survey Section Name CD1-27 MWD BHI Rep. GEHRES / MILCHAK Jr'Nl"J"~~ WELL OATA Target TVD (F~ Target Coord. N/S Slot Coord. N/S -408.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W · Slot Coord. E/W 2391.00 Magn. Deolination 25.890 Caloulation Method MINIMUM CURVATURE Target Direction (Do) Buil~Walk\DL per: 100ft~ 30m[-I 10ml-I Vert. See. Azim. 157.10 Magn. to Map Corr. 25.890 Map North to: OTHER SURVEY DATA Survey Survey Inol. Hole Course Vertioal Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / ,~(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (Fr) (DO) (DO) (F~ (FT) (FT) (F'I3 (Per ~00 F'r)Drop (-) Left (-) 19-FEB-00 MWD 4528.39 32.08 156.19 94.52 3962.66 2005.42 -1857.12 757.17 0.36 -0.33 -0.29 19-FEB-00 MWD 4622.84' 31.81 155.69 94.45 4042.80 2055.38 -1902.75 777.54 0.40 -0.29 -0.53 -- 19-FEB-O0 MWD 4718.64 31.66 : 155.65 95.80 4124.28 2105.75 -1948.67 798.30 0.16 -0.16 -0.04 19-FEB-00 MWD 4813.81 32.43 -. 159.97 95,17 4204.96 2156.22 -1995,40 817.34 2.54 0.81 4.54 19-FEB-00 MWD 4910.31 .31.93 159.63 96.50 4286.63 2207.56 -2043.64 835.09 0.55 -0,52 -0,35 19-FEB-00 MWD 5004.33 31.91 159,20 94.02 4366.44 2257.23 -2090.17 852.56 0.24 -0.02 -0.46 19-FEB-00 MWD 5099.77 31.71 158.68 95.44 :-4447.54 2307.51 -2137.12 870.64 0.36 -0,21 -0.54 . ;. 19-FEB-00 MWD 5195.22 31.82 158.52 95.45 4528.70 2357.75 -2183.90 888.98 0.15 0,12 -0.17 19-FEB-00 MWD 5291.00 31.97 157.95 95.78 4610.02 2408.34 -2230.90 907.74 0,35 0,16 -O.60 19-FEB-O0 MWD 53B6.00 31.59 157.59 95.00 4690.77 2453.37 -2277.22 926.67 0.45 -0.40 -0.38 ,9-FEB-00 MWD 5482.00 33.02 157.77 96.00 4771.91 2509.68 -2324.68 -' 946.15 1.49 1.49 0.19 19-FEB-O0 MWD 5574.72 32.70 158.08 92.72 4649.80 2559.98 -2371,30 965.06 0.39 -0.35 0.33 2UUU 19-FEB-(X) MWD 5371.26 32.19 157.95 96.54 4931.27 2611.77 -2419,32 964.45 0.53 -0.53 -0.13 _ 20-FEB-00 MWD 5768.00 31.63 157.80 96.74 5013.39 2662.90 -2466.69 1003.71 0.56 -0.56 -0.16 ,A.[._%~l,'~ i"lil ,% ~sl.e C. nn.~ CommisSic _ :1~1l iB,,~ ~ ~ 20-FEB-00 MWD 5863.01 33.11 157.75 95.01 5093.63 2713.76 -2513.78 1022.95 1.56 1,56 -0.05 jgl~{~01'~ 20-FEB-00 MWD 5958.00 32.51 158.25 94.99 5173.47 2765.23 -2561.50 1042.23 0.69 -0,63 0.53 20-FEB-00 MWD 6053.00 32.32 157.33 95.00 5253.66 2816.15 -2608,65 1061.48 0.53 -0.20 -0,97 20-FEB-00 MWD 61 48.00 32.19 157.31 95.00 5334.00 2866.85 -2655.43 1081.03 0.14 -0,14 -0.02 20-FEB-00 MWD 6242.05 33,31 157.38 94:05 5413.10 2917.73 -2702.38 1100.62 1.1 9 1.1 9 0.07 20-FEB-00 MWD 6338.00 33,42 1 56.68 95.95 5493.24 2970.49 -2750.96 1121.22 0.42 0.11 -0.73 20-FEB-00 MWD 6432.25 33,76 156.33 94,25 5571.75 3022.63 -2798.78 1142.01 0.42 0.36 -0.37 20-FEB-00 MWD 6527.72 33.69 155.83 95.47 5651.15 3075.63 -2847.24 1163.50 0.30 -0.07 -0.52 20-FEB-00 MWD 6623.14 33.67 155.59 95.42 5730.56 3128.53 -2895.47 1185.26 0.14 -0.02 -0.25 20-FEB-00 MWD 6718.65 33,25 155.14 95.51 5610.24 3181.16 . -'2943.33 1207.21 0.51 -0,44 -0.47 . . "" SURVEY CALCULATION AND FIELD WORKSHEET NO. 0450-00013 Sidetrack No. Page 4 of 6 I~1 Company ARCO ALASKA, INC. Rig' Contractor & No. Doyon Drilling Co.-Rig: #19 Field ALPINE FIELD Well Name & No, PAD CD#1/27 Sun/ey Section Name CD1-27 MWD BHI Rep. GEHRES / MILCHAK j~J~i~ WELL DATA i Target TVD (F~ Target Coord. N/S Slot Coord. N/S -408.00 Grid Correction 0.000 'Depths Measured From: RKB ~ MSL 0 SS~ Target Description Target Coord. E/W - Slot Coord. F_./W 2391.00 Magn. Declination 25.890 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build~Walk\DL per: 100ff~ 30m0 10mO Vert. Sec. Azim. 157.19 Magn. to Map Corr. 25.890 Map North to: OTHER i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT} (OD) (DD) (FT) (FT) (FT) (F'r) . (Per 100 Fr) Drop (-) Left (-) 20-FEB-00 MWD 6815.16 32.89 154.92 96.51 5891.12 3233.78 -2991.07 1229.44 0.39 -0.37 -0.23 20-FEB-00 MWD 6908.74 33,30 157.73 93.58 5969.52 3284.86 -3037.86 1249.95 1.70 0.44 3.00 . 20-FEB-D0 MWD 7003.38 33.09 : 158.73 94.64 6048.71 3336.67 -3085.98 1269.17 0.62 -0.22 1.06 2D-FEB-00 MWD 7098.44 33.32 -- 158.44 95.06 6128.25 3388.71 -3134.44 1288.18 0.29 0.24 -0.31 20-FEB-00 MWD 7193.57 33.27 158.15 95.13 6207.77 3440.92 -3182.96 1307.49 0.18 -0.05 -0.30 20-FEB-00 MWD 7288.74 32.86 158.12 95.17 6287.52 3492.84 -3231.15 1326.83 0.43 -0.43 -0.03 20-FEB-O0 MWD 7384.41 32.65 157.33 · 95.67 6367.98 3544.60 -3279.05 1346.44 0.50 -0.22 -0.83 20-FEB-D0 MWD 7479.96 31.89 157.60 95.55 6448.77 3595.61 -3326.17 1366.00 0.81 -0.80 0.28 21-FEB-00 MWD 7568.97 32.00 156.51 89.01 6524.30 3642.70 -3369.53 1384.36 0.66 0.12 -1.22 21 -FEB(X) MWD 7854.38 34.00 163.14 29.39 6766.96 3792.66 -3510.53 1435.91 8.94 8.91 -1.19 ,,~ji~l~ia 0ii & Gas Cons. C0mmiai0n Anr4tnr~ · Ill I ~1 I]¥1 ~II%~'WI r --~,~ 21-FEB-O0 MWD ?888.55 37.47 164.37 34.17 6794.70 3812.48 -3529.69 1441.48 10.37 10.18 3.60 -- 21-FEB-00 MWD 7920.54 40.94 1 64.33 31.99 6819.48 3832.54 -3549.16 1446.94 10.85 10.85 -0.13 21-FEB-00 MWD 794g.68 44,44 164.37 29.34 6841.04 3852.27 -3568.31 1452.30 11.93 11.93 O. 14 21-FEB-00 MWD 7883.76 48.33 163.00 33.88 8864.41 3876.64 -3591.84 1459.20 11.85 11.48 -4.04 21 -FEB-O0 MWD 8015.93 50.25 1 63.85 32.17 6885.39 3900.94 -3815.00 1486.81 8.14 5.97 -7.30 21-FEB-O0 MWD 8046.40 51.99 157.25 30147 8904.52 3924.54 -3837.13 1475.34 10.39 5.71 -11.16 21-FEB-O0 MWD 8079.25 53.25 154.54 32.85 -8924.47 3950.74 -3660.95 1486.00 7.59 3.84 -8.25 21-FEB-O0 MWD 8111.06 58.04 153.31 31.81 6942.87 3976.63 -3684.25 1497.41 9.32 8.77 -3.87 21-FEB-O0 MWD 8141.46 59.42 152.77 30,40 6959.10 4002.27 -3707.18 1509.06 11.22 11.12 -1.78 21-FEB(X) MWD 6173.80 63.87 151.95 32.34 6974.48 - 4030.62 -3732.38 1522.27 13.94 13.78 -2.54 21 -FEB-O0 MWD 8206.50 67.79 150.68 32,70 6987.64 4060.2g -;3758.55 1,536.54 12.35 11.99 -3.27 I I SURVEY CALCULATIONAND FIELD WORKSHEET Job No. 0450-00013 Sidetrack No._ ..... Page 5 of 6 ~ I! £r] -' I =('-1 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD _- I · Well Name & No. PAD CD#1/27 Survey Section Name CD1-27 -MWD BHI Rep. GEHRES / MILCHAK Target TVD 0'r) Target Coord. N/S Slot Coord. N/S -408.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSQ Target Description Target Coord. F_,/W - Slot Coord. E/W 2391.00 Magn. Declination 25.890 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build~Walk\DL per: 100ft~ 30m['] 10m0 Vert. Sec. Azim. 157.19 Magn. to Map Corr. 25,890 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) (F~ - Per 100 FT) Drop (-) Left (-) 21-FEB-00 MWD 8237.04 69.91 149.40 30.54 6998.86 4088.56 -3783.25 1550.72 8.28 6.94 -4.85 21-FEB-00 MWD 8269.39 70.45 148.80 32.35 7009.83 4118.69 -3809.36 1566.35 2.41 1.67 -1.85 22-FEB, O0 MWD 8301.47 70.63 ~ 148.79 32.08 7020.52 4148.61 -3835.23 1582.02 0.55 0.56 -0.03 22-FEB-00 MWD 8331.77 71.92_ '- 149.88 30,30 7030.25 - 4177.04 -3859.91 1596.66 5.45 4.26 3.60 22-FEB-O0 MWD 8364.19 74.88 149,50 32,42 7039.51 4207.84 -3886.73 1612.34 9.20 9.13 -1.17 22-FEB-O0 MWD 8396.16 77.70 149.22 31,97 7047.08 4238.60 -3913.45 1628.16 8.86 8.82 -0.88 22-FEB-00 MWD 8442.62 80.64 150.14 46.46 7055.81 4283.84 -3952.84 1651.20 6.62 6.33 1.98 24-FEB-00 MWD 8534.52 86.78 149.92 91.90 7065.88 4374.43 -4031.93 1696.81 6.69 6.68 -0.24 4 3/4' MIX 1.2 DEG AKO 24-FEB-00 MWD 8628.24 87.05 150.35 93.72 7070.92 4467.31 -4113.09 1743.41 0.54 0.29 0.46 24-FEB-00 ' MWD 8724.18 87.57 152.16 95,94 7075.42 4562.62 -4197.11 1789.49 1.96 0.54 1.89 ; 24-FEB-00 MWD 8815.11 88.05 151.16 90.93 7078.90 4653.06 -4277.08 1832.63 1.22 0.53 -1.10 24-FEB-O0 MWD 8907.25 88.87 :151.27 92.14 7081.38 4744.67 -4357.81 1876.98 0.90 0.89 0.12 24-FEB-00 MWD 8999.72 89.52 1 50.20 92,47 7082.67 4836.54 -4438.47 1922.18 1.35 0.70 -1.16 -- . 25-FEB-00 MWD 9183,75 90,99 151.25 91.32 7081,94 5019.50 -4599.46 2011,31 0,86 0,85 -0,10 25-FEB-00 MWD 9276.48 91.44 150.55 92.73 7079.97 5111.65 -4680.47 2056.39 0.90 0.49 -0.75 25-FEB-00 MWD - 9369.05 91.13 153.50 92.57 7077.89. i 5203~81 -4762.19 2099.80 3.20 -0.33 3.19 25-FEB-O0 MWD 9463.93 91.47 155,08 94.88 7075.74 5298.54 -4847.65 2140.95 1.70 0.36 1.67 26-FEB'00 MWD 9555.78 92.30 155.21 91.85 7072~72 5390.28 -4930.95 2179.53 0.91 0.90 0.14 26-FEB-O0 MWD 9646.78 91.44 154,61 91,00 7069.75 5481.16 -5013.32 2218.10 1.1 5 -0.95 -0.66 26-FEB-OO MWD 9738.11 92.23 154.90 91.33 7066.83 5572.36 -5095.88 2257.03 0.92 0.86 0.32 26-FEB-O0 MWD 9830.66 90.69 1 54,62 92,55 7064.47 5664.79 -5179.57 2296.48 1.69 -1.66 -0.30 .. 26-FEB-O0 MWD 9923.46 91.17 153.63 92.80 7062.96 5757.45 -5263.05 2336.98 1.19 0.52 -1.07 26-FEB-00 MWD 10016.04 90.72 152.91 92.58 7061.44 5649.80 ~5345.72 2378.61 0.92 -0.49 -0.78 · hill ~1 ii] ~ r · i Company ARCO ALASKA, INC. Rig' Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#1/27 Survey Section Name CD1-27 MWD BHI Rep. GEHRES / MILCHAK ~',~rE~ WELL DATA Target TVD (FO Target Coord. N/S Slot Coord: N/S -408.00 Grid Correction 0.000 Depths Measured From: RKB I~ MSL l'-I SSI~ Target Description Target Coord. E/W. Slot Coord. E/W 2391.00 Magn. Declination 25.890 Calculation Method MINIMUM CURVATURE Target Direction (OD) Buil~Walk\DL per: 100ft[~ 30mi-[ 10m[-] Vert. Sec. Azim. 157.19 Magn. to Map Corr. 25.890 Map North to: OTHER SURVEY DATA Suwey 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) (OD) (F'I') {Fl') (Fl) (FO (Per ~00 F'r)Drop (-) Left (-) 26-FEB-00 ' MWD 10108.02 91.44 152.97 91.98 7059.70 5941.51 -5427.62 2420.45 0.79 0.78 0.07 26-FEB-00 MWD 10200.88 90.99 153.47 92.86 7057.73 6034.12 -5510.50 2462.28 0.72 -0.48 0.54 -- 26-FEB-00 MWD 10293.31 90.10 ~ 152.44 92.43 7056.85 6126.29 -5592.82 2504.30 1.47 -0.96 -1.11 26-FEB-O0 MWD 10353.99 90.48 --153.68 90.88 7056.39 6216.74 -5673.66 2545.38 1.43 0.42 1.37 26-FEB-00 MWD 10475.08 ,. 91.51 154.03 91.08 7054.81 6307.66 -5755.41 2585.51 1.19 1.13 0.38 26-FEB-00 awo 10569.25 90.17 152.17 94.17 7053.43 6401.57 -5839.38 2628.11 2.43 -1.42 -1.98 26-FEB-00 MWD 10660.84 90.82 153.57 91.59 7052.64 6492.89 -5920.88 2669.88 1.69 0.71 1.53 26-FEB-00 MWD 10753.74 89.69 152.93 92;90 7052.23 6585.57 -6003.84 2711.69 1.40 -1.22 -0.69 26-FEB-00 MWD 10848.94 90.58 153.80 95.20 7052.00 6680.58 -6088.94 2754.37 1.31 0.93 0.91 27-FEB-00' MWD 10~38.77 89.35 152.21 89.83 7052.08 6770.14 -6168.97 2795.14 2.24 -1.37 -1.77 r,3~r~% #l,,W_l,_,_~ 27-FEB-00 MWD 11030.92 90.21 153.03 92.15 7052.41 6862.00 -6250.80 --2837.52 1.29 0.93 0.89 27-FEB-00 MWD 11124.24 89.04 .150.87 93.32 7053.02 6954.92 -6333.15 2881.40 2.63 -1.25 -2.31 nl I 27-FEB-00 MWD 11216.69 89.97 151.06 92.45 7053.82 7046.82 -6413.98 2926.26 1.03 1.01 0.21 27-FEB-O0 MWD 11310.37 90.69 151.90 93.88 7053.28 7140.03 -6496.29 2970.99 1.18 0.77 0.90 Alaska 0il & Gas C0~s. C0mmi~'--'" 27-FEB-00 MWD 11402.76 91.20 152.63 92.39 7051.76 7232.07 -6578.05 3013.98 0.96 0.55 0.79 /.u]cflOl'a~ 27~FEB-OD MWD 11436.83 91.51 152.38 34.07 7050.95 7266.01 -6608.26 3029.71 1.17 0.91 -0.73 27-FEB-00 MWD 11492.00 91.51 152.38 55.17 7049.50 7320.97 -6657.13 3055.27 0.00 0.00 0.00 Projected Data - NO SURVEY -, A~ADRILL SCHLUMBERGER Survey report Client ................... : ARCO Alaska, Inc. Field .................... : Colville River Well CD1-27 API number ............... : 50-103-20324-00 Engineer ............ ~ .... : Dammeyer Rig: ..................... : Doyon 19 State: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea level Depth reference .......... : Drill Floor -GL above permanent ....... : . 19.50 ft KB above permanent ...... -.: Top Drive DF above permanent ....... : 56.20 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: 157.19 degrees 27-Feb-2000 10:05:05 Page Spud date ................ : 16 Feb-00 Last survey date ......... : 27-Feb-00 Total accepted surveys...: 136 MD of first survey ....... : 115.00 ft MD of last survey ........ : 11492.00 ft 1 of 6 ORIGINAL Geomagnetic data Magnetic model ........... : Magnetic date ............ : Magnetic field-strength..: Magnetic dec (+E/W-) ..... : Magnetic dip .............. : BGGM version 1999 15-Feb-2000 1144.65 HCNT 25.89 degrees 80.48 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.89 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W--) .... : 25.89 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6_0C_07] RECEIVED MAR 000 Alaska Oil & Gas Cons. Commission Anchorage ,ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 115.00 0.00 0.00 2 174.00 0.25 355.00 3 297.69 1.51 197.11 4 388.32 3.47 175.07 5 475.22 5.81 174.24 6 565.71 8.54 170.93 7 656.89 10.50 175.27 8 747.74 12.06 173.25 9 837.93 14.08 171.65 10 926.16 16.55 165.21 11 1016.79 19.42 163.01 12 1112.03 22.82 159.87 13 1206.80 25.96 159.07 14 1301.92 28.11 159.19 15 1397.36 30.93 158.24 16 1492.32 33.80 156.00 17 1587.25 32.86 155.97 18 1681.93 31.59 155.03 19 1777.07 33.03 155.88 20 1870.55 34.09 157.17 21 1967.41 35.21 156.76 22 2063.95 34.63 156,29 23 2158.98 .34.57 156.53 24 2253.50 34.26 156.36 25 2348.39 33.65 157.00 0.00 59.00 123.'69 90.63 86.90 90.49 91.18 90.85 90.19 88.23 90.63 95.24 94.77 95.12 95.44 94.96 94.93 94.68 95.14 93.48 96.86 96.54 95.03 94.52 94.89 26 2443.02 33.42 157.6J 94.63 27 2537.85 32.89 157.10 94.83 28 2569.59 32.99 156.94 31.74 29' 2724.00 32.59 157.71 154.41 30 2819.00 32.15 157.29 95.00 TVD depth (ft) 115.00 174.00 297.68 388.22 474.83 564.60 654.52 743.62 831.46 916.56 1002.75 1091.59 1177.89 1262.61 1345.65 1425.86 1505.17 1585.26 1665.67 1743.57 1823.25 1902.41 1980.63 2058.61 2137.31 2216.19 2295.58 2322.22 2452.03 2532.27 27-Feb-2000 10:05:05 Page 2 of 6 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 -0.12 0 0.87 -1 4.40 -5 11.11 -12 22.01 -23 36.49 -38 53.48 -55 73.16 -76 96.00 -'98 .00. 0.00 0.00 .13 -0.01 0.13 .16 -0.51 1.27 .03 -0.63 5.07 .03 0.04 12.03 .23 1.56 23.28 ,19 3.31 38.34 . .87 5.11 56.10 .08 7.81 76.48 .86 12.58 99.65 0.00 0.00 TIP 355.00 0.42 GYR 203.90 1.41 MWD 187.13 2.37 MWD 179.82 2.69 MWD 176..17 3.05 MWD 175.05 2.29 MWD 174.78 1.77 MWD 174.14 2.28 MWD 172.75 3.40 MWD 123.78 -125 157.99 -158 197.09 -194 240.30 -235 287.30 -279 .75 20.28 127.38 170.84 .24 31.26 161.30 168.83 .88 45.00 200.01 167.00 .28 60.40 242.91 165.60 .09 77.48 289.64 164.48 .89 97.28 340.10 163.38 .54 118,51 391.88 162.40 .48 139.44 442.05 161.61 .74 160.55 492.63 160.98 .14 181.13 544.1.7 160.56 202.68 224.69 246.29 267.64 288.62 338.12 -325 390.27 -373 440.73 -419 491.5.6 -465 543.23 -513 599.14 654.29 708,16 761.51 814.45 866.70 918.54 935.79 1019.38 1070.22 308.76 328.70 335.44 367.69' 387.15 598.'30 -563.82 653.55 -614.50 707.51- -663.96 760.93 -712.93 813.93. -761.60 3.25 MWD 3.76 MWD 3.33 MWD 2,26 MWD 3.00 MWD 3.28 MWD 0.99 MWD 1,44 MWD 1.59 MWD 1.37 MWD 866.20 -809.83 918.06 '857.71 935.32 -873.60 1018.94 -950.75 1069.80 -997.74 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 160.23 1.18 MWD 159.92 0.66 MWD 159.65 0.16 MWD 159.42 0.34 MWD 159.25 0.75 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 159.13 0.46 MWD 159.03 0.65 MWD 158.99 0.43 MWD 158.86 0.38 MWD 158.79 0,52 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 RECEIVED UAR 09 2000 Alaska Oil & Gas Cons. Commission ~ ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 31 2914,00 33,33 158,13 32 3008,00 33,39 158,02 33 3104,00 33,57- 157,72 34 3199,00 33,73 157,34 35 3295,00 33,61 157,27 95.00 94.00 96,00. 95.00 96,00' 36 3389,00 33.65 156,28 94,00 37 3484,00 33,54 155,15 95,00 38 3579.55 33,57 154,71 95.55 39 3673.55 33,10 154.13 94.00 40 3769,59 32,67 154.22 96,04 27-Feb-2000 10:05:05 TVD Vertical Displ Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) 2612,17 1121,18 -1045.28 2690,69 1172,86 -1093,23 2770,76--1225,82 -1142,29 2849,84 1278,46 -1190.93 2929,73 1331,68 -1240,04 3008,00 3'087,13 3166,76 3245,30 3325,95 41 3863,99 33,77 158,21 94,40 3404,93 42 3959,15 33,18 157,93 95,16 3484,30 43 4053.91 33.31 157.51 94.76 3563,55 44' 4149,15 -33,06 157,17 95,24 3643.26 45 4243'89 32,79 156,88 94.74 37.22,78 46 4341,28 32,75 156,75 97.39 3804,67 47 4433,87 32,39 156,46 92,59 3882,70 48 4528,39 32,08 156,19 94,52 3962.65 49 4622,84 31,81 155,69 94,45 4042,80 50 4718,64 31,66 155,65 95,80 4124,28 51 4813,81 32,43 159,97 95.17 4204,96 52 4910,31 31,93 159,63 96,50 4286,63 53 5004,33 31.91 159,20 94,02 4366,44 54 5099.77 31,71 158,68 95,44 4447.54 55 5195.22 31,82 158,52 95,45 4528,69 406,63 425.93 445,88 466,00 486,54 56 5291.00 31,97 157,95 95,78 4610,01 57 5386,00 31,59 157,59 95,00 4690,77 58 5482,00 33,02 157.77 96,00 4771,91 59 -5574,72 32,70 158.08 92.72 4849,79 60 5671,26 32,19 157,95 96,54 4931,26 1383,74' -1287.88 1436.28 -1335.79 1489.,06 -1383,63 1540,65 -1430,22 1592,72 -1477,16 507,07 528.69 551,06 573,37 596,08 1644,41 -1524.47 1696,89 -1573,16 1748.84 -1621.23 1800,96 -1669,33- 1852,46 -1716.74 616,91 636,51 656,20 676,29 696.39 1905,17 -1765,20 1955,01 -1810,95 2005,42 -1857.12 2055.39 -1902.75 2105,76 -1948.67 717,14 736,93 757,17 777,55 798,31 2156,22 -1995.40 2207.56 -2043,64 2257,24 -2090,17 2307.52 -2137,12 2357,75 -2183,90 817,35 835,09 852,57 870.65 .888.98 2408,35 -2230,90 2458.38 -2277.22 2509.68 -2324,68 2559,98 -2371,30 2611,77 -2419,32 907,75 926,68 946.16 965,07 984,~5 Page 3 of 6 1121.59 1173,28 1226,23 1278,86 1332,07 At DLS Srvy Tool Azim (deg/ tool qual (deg) 100f) type type 1384,10 1436,61 1489,33 1540.87 1592,89 158,74 158,71 158.68 158,63 158,58 1644,56 1697,05 1749,00 1801,12 1852,61 1905,31 1955,15 2005,54 2055,49 2105,85 158,51 158,41 158,28 158,15 158,02 157,97 157,97 157,96 .157,95 157,92 2156,32 2207,68 2257,37 2307,66 2357.91 157,89 157,86 157,82 157.77 157,72 2408,51 2458,55 2509,85 2560,16 2611,95' 157,73 157,77 157,81 157.83 157,85 157,86 157,86 157,85 t57,85 157,86 1,33 MWD 6-axis 0,09 MWD 6-axis 0,25 MWD 6-axis 0,28 MWD 6-axis 0,13 MWD 6-axis 0,58 MWD 6-axis 0,67 MWD 6-axis 0,26 MWD 6-axis 0,60 MWD 6-axis 0,45 MWD 6-axis 2,59 MWD 6-axis 0,64 MWD 6-axis 0,28 MWD 6-axis 0,33 MWD 6-axis 0,33 MWD 6-axis 0,08 MWD 6-axis 0,42 MWD 6-axis 0,36 MWD 6-axis 0,40 MWD 6-axis 0.16 MWD 6-axis 2.54 MWD 6-axis 0,55 MWD 6-axis 0,24 MWD 6-axis 0,36 MWD 6-axis 0,15 MWD 6-axis 0.35 MWD 6-axis 0.45 MWD 6-axis 1.49 MWD 6-axis 0,39 MWD 6-axis 0,53 MWD 6-axis RECEIVED MAR 09 2000 Alaska Oil & Gas Cons. Commission Anchorage ~ ANADRILL SCHLUMBERGER Survey Report' 27-Feb-2000 10:05:05 Page 4 of 6 Seq Measured Incl Azimuth % depth angle' angle - (ft) (deg) (deg) 61 5768,00 31,63 157,80 62 5863.01 33.11 157,75 63 5958,00 32,51 158.25 64 6053.00 32,32 157.,33 65 6148,00 32.19 157,31 66 6242,05 33.31 157,38 67 6338,00 33,42 156,68 68 6432,25 33.76 156,33 69 6527,72 33.69 155,83 70 6623,14 33,67 155.59 Course' length (ft) 96.74 95,01 94,99. 95,00 95.00' 94.05 95,95 94,25 95,47 95.42 TVD depth (ft) 5013,38 5093,63 5173,46 5253,66 5334,00 5413,10 5493,24 5571,75 5651,15 5730,56 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 2662.90 -2466.69 2713,77 -2513,78 2765,23 -2561.50 2816,15 -2608,65 2866,85 -2655,43 1003,71 2663,08 157.86 1022,95 2713,95 157,86 1042,24 2765.42 .157.86 1061,48 2816,34 157,86 1081,03 2867.04 157,85 1100,63 2917,92 157,84 1121,22 2970,68 157,83 1142.01 3022,81 157,80 1163,50 3075,79 157,77 1185,27 3128,67 157,74 2917,73 -2702.38 2970.50 -2750,96 3022,64 -2798,78 3075,63 -2847.24 3128,53 -2895,47 0.58 MWD 6-axis 1.56 MWD 6-axis 0,69 MWD 6-axis 0,56 MWD 6-axis 0,14 MWD 6-axis · 1,19 MWD 6-axis 0,42 MWD 6-axis 0,42 MWD 6-axis 0,30 MWD 6-axis 0,14 MWD 6-axis 71 6718,65 33,25 155~14 95,51 5810,24 72 6815.16 32,89 154,92 96,51 5891,11 73 6908.74 33,30 157,73 93,58 5969.52 74' 7003.38 33,09 158,73 94,64 6048,71 75 7098.44 33,32 158,44 95,06 61-28.25 3181,16 -2943,33 3233,79 -2991.07 3284,87 -3037.86 3336,67 -3085,98 3388.71 -3134.44 1207,22 3181,29 157,70 1229,45 3233.89 157,66 1249,96 3284.97 157,63 1269,17 3336,78 157,64 1288.18 3388.83 157,66 0,51 MWD 6-axis 0,39 MWD 6-axis 1,70 MWD 6-axis 0.62 MWD 6-axis 0,29 MWD 6-axis 76 7193,57 33,27 158,15 95,13 6207.76 77 7288,74 32.86 158.12 95,17 6287,52 78 7384,41 32,65 157,33 95,67 6367,98 79 7479,96 31,89 157,60 95,55 6448,77 80 7568.97 32,00 156,51 89,01 6524,30 81 7663,93 31,99 158,58 94,96 6604,84 82 7759.07 31.18 160,82 95,14 6685,89 83 7824,99 31,38 163,49 65,92 6742,23 84 7854,38 34,00 163,14 29,39 6766,96' 85 7888,55 37,47 164.37 34,17 6794,69 3440,93 -3182.96 3492,84 -3231,15 3544.60 -3279,05 3595,61 -3326.17 3642,71 -3369,54 3693,02 -3416,03 3742,79 -3462,75 3776,88 -3495,33 3792,66 -3510.53 3812,48 -3529.69 1307,50 3441,04 157,67 1326,83 3492,97 157,68 1346,45 3544,73 157,68 1366,00 3595,74 157,67 1384,36 3642.83 157,66 1403,58 3693,14 157,66 1420,88 3742,93 157,69 1431,36 3777,05 157,73 1435,92 3792,85 157,75 1~41.49 3812.69 157,79 0,18 MWD 6-axis 0.43 MWD 6-axis 0,50 MWD 6-axis 0,81 MWD 6-axis 0.66 MWD 6-axis 1,15 MWD 6-axis 1.50 MWD 6-axis 2,12 MWD 6-axis 8.94 MWD 6-axis 10,37 MWD 6-axis 86 7920,54 40..94 164,33 31.99 6819,48 87 7949,88 44,44 164,37 29~'34 6841,04 88 7983,76 48,33 163,00 33,88. 6864.41 89 8015.93 50,25 160,65 32,13 6885,39 90 8046,40 51,99 157,25 30,47 6904,52 3832,54 -3549,16 3852,28 -3568,31 3876,65 -3591,84 3900,95 -3615,01 3924,65 -3637,13 1446,95 3832,78 157,82 1452,31 3852.54 157,85 1459,21 3876,93 157,89 1466,82 3901,26 157,91 1475,35 3924.97 157.92 10,85 MWD 6-axis 11.93 MWD 6-axis 11,85 MWD 6-axis 8,14 MWD 6-axis 10 39 MWDD6-axis Naslm Oil & Gas Cons. Commission Anctmrage a- ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 91 8079.25 53.25 154.54 92 8111.06 56.04 153.31 93 8141.46 ~9.42 152.77 94 8173.80 63.87 151.95 95 8206.50 67.79 150.88 Course length (ft) 32.85 31.81 30.40. 32.34 32.70 96 8237.04 69.91 149.40 97 8269.39 70.45 148.80 98 8301.47 70.63 148.79 99 8331.77 71.92 149.88 100 8364.19 74.88 149.50 30.54 32.35 32.08 30~30 32.42 101 8396.16 77.70 149.22 102 8442.62 80.64 150.14 103 8534.52 86.78 149.92 104' 8628.24 87,05 150.35 105 8724118 87.57 152.16 31.97 46.46 91.90 93.72 95.94 106 8815.11 88.05 151.16 107 8907.25 88.87 151.27 108 8999.72 89.52 150.20 109 9092.43 90.21 151.34 110 9183.75 90.99- 151.25 90.93 92.14 92.47 92.71 91.32 111 9276.48 91.44 150.55 112 9369.05 91.13 153.50 113 9463.93 91.47 155.08 114 9555.78 92.30 155.21 115 9646.78 91.44 154.61' 92.73 92.57 94.88 91.85 91.00 27-Feb-2000 10:05:05 TVD Vertical Displ depth section +N/S- (ft) (ft) (ft) 6924.47 6942.87 6959.10 6974.46 6987.84 6998.86 7009.83 7020.52 7030.24 7039.51 7-047.08 7055.81 7065.87 7070.92 7075.43 7078.91 7081.39 7082.69 7082.91 7081.95 7079.98 7077.91 7075.75 7072.73 7069.76 116 9738.11 92.23 154.90 91.33 7066.84 117 9830.'66 90.69 154.62 92.55 7064.48 118 9923.46 91.17 153.63 92.80 7062.98 119 10016.04 90.72 152.91 92.58 7061.45 120 10108.02' 91.44 152.97 91.98 7059.71 Page 5 of 6 3950.74 -3660.95 3976.64 -3684.25 4002.27 -3707.16 4030.62 -3732.36 4060.30 -3758.55 4088.56 -3783.25 4118.69 =3809.36 4148.62 -3835.23 4177.04 -3859.92 4207.84 -3886.73 Displ Total At +E/W- displ Azim (ft) (f~) (deg) 1486.01 3951.05 157.91 1497.42 3976.93 157.88 1509.07 4002.54 157.85 1522.27 4030.86 157,81 1536.55 4060.50 157.76 4238.61 -3913.45 4283.84 -3952.84 4374.43 -4031.94 4467.31 r4113.09 4562.63 -4197.11 1550.73 4088.73 157.71 1566.36 4118.82 157.65 1582.03 4148.71 157.58 1596.66 4177.11 157.53 1612.34 4207.89 157.47 4653.07 -4277.08 4744.67 -4357.81 4836.54 -4438.47 4928.67 -4519.37 5019.-50 -4599.46 1628.17 4238.64 157,41 1651.20 4283.86 157.33 1696.81 4374.43 157.18 1743.42 4467.33 157.03 1789.50 4562.68 156.91 5111.65 -4680.47 5203.81 -4762_.19 5298.54 -4847.65 5390,28 -4930.95 5481.16 -5013.32 1832.63 4653,17 156.81 1876.98 4744.85 '156.70 1922.18 4836.81 156.58 1967.45 4929.05 156.47 2011.31 5020.00 156'.38 5572.36 -5095.88 5664.80 -5179.57 5757.45 -5263.05 5849.80 -5345.73 5941.51 -5427.62 2056.40 5112.29 156.28 2099.81 5204.58 156.21 2140.95 5299.38 156.17 21~9.54 5391.17 156.15 2218.11 5482.09 156.13 2257.04 2296.49 2336.98 2378.62. 2420.45 DLS Srvy Tool (deg/ tool qual 100f) type type - 7.59 MWD 6-axis 9.32 MWD 6-axis 11.22 MWD 6-axis 13.94 MWD 6-axis 12.35 MWD 6-axis 8:28 MWD 2.41 MWD 0.56 MWD 5.45 MWD 9.20 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 8.86 MWD 6.62 MWD 6.69 MWD 0.54 MWD 1.96 MWD 6-axis 6-axis 5-axis 5-axis 5-axis 1.22 MWD 0.90 MWD 1.35 MWD 1.44 MWD 0.86 MWD 5-axis 5-axis 5-axis 5-axis 5-axis 0.90 MWD 3.20 MWD 1.70 MWD 0.91 MWD 1.15 MWD 5-axis 6-axis 6-axis 6-axis 6-axis 5573.35 5665.84 5758.58 5851.03 5942.87 156.11 0.92 MWD 6-axis 156.09 1.69 MWD 6-axis 156.06 1.19 MWD 6-axis 156.01 0.92 MWD 6-axis 155.970 79 RECEIV b 6-axis 09 2000 Naska 0il & Gas Cons. Commission Anchorage .- ~' ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 121 10200.88 90.99 153.47 122 10292.31 90.10 152.44 .. 123 10383.99 90.48 153.68 124 10475.08 91.51 154.03 125 10569.25 90.17 152.17 Course length (ft) 92.86 91.43 91.68. 91.09 94.17' 126 10660.84 90.82 153.57 127 10753.74 89.69 152.93 128 10848.94 90.58 153.80 129 10938.77 89.35 152.21 130 11030.92 90.21 153.03 91.59 92.90 95.20 89.83 92.15 131 11124.24 89.04 150.87 132 11216.69 89.97. 151.06 133 11310.37 - 90.69 151.90 134 11402.76 91.20 152.63 135 11436.83 9_1.51 152.38 93.32 92.45 93.68 92.39 34.07 . Last Survey Projected to TD 136 11492.00 91.51 152.38 . . 55.17 TVD depth (ft) 7'057.75 7056.88 7056.41 7054.83 7053.45 7052.66 7052.24 7052.02 7052.07 7052.43 7053.04 7053.84 7053.30 7051.77 7050.97 7049.52 27-Feb-2000 10:05:05 Page 6 of 6 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 6034.13 -5510.50 6125.30 -5591.93. 6216.74 -5673.66 6307.66 -5755.41 6401.57 -5839.38 ~462.28 6035.60 155.92 2503.85 6126.90 155.88 2545.39 6218.47 155.84 2585.52 6309.49 155.81 2628.12 6403.54 155.77 6492.90 -5920~89 6585.58 -6003.84 6680.56 -6088.94 6770.15 -6168.98 6862.00 -6250.80 2669.88 6495.01 155.73 2711.69 6587.82 155.69 2754.37. 6682.94 155.66 2795.14 6772.67 155.62 2837.52 6864.70 155.58 6954.92 -6333.15 7046.82 -6413.98 7140.03 -6496.29 7232.07 -6578.05 7266.02 -6608.27 2881.40 6957.82 155.54 2926.27 7049.98 155.48 2971.00 7143.43 155.42 3013.99 7235.67 155.38 3029.71 7269.68 155.37 7324.76 155.35 7320.97 -6657.13 3055.28 0.72 MWD 1.49 MWD 1.41 MWD 1.19 MWD 2.43 MWD 1.69 MWD 1.40 MWD 1.31 MWD 2.24 MWD 1.29 MWD 2.63 MWD 1.03 MWD 1.18 MWD 0.96 MWD 1.17 MWD 0.00 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 [(c)2000 Anadrill IDEAL ID6 0C 07] RECEIVED MAR 09 2000 Alaska Oil & Gas Cons. Commission Anchorage (' (' MWDILWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CD1-27 ~3" O(~ (~ Date Dispatche 6-Mar-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 ECEI ED 09 21100 Alaska0ii & Gas Cons. Commission Anchorag{ Received By: L~---~ ~,~(~~ ~ Please sign and return to: .~ Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 Email: nrosel@slb.com Fax: 907-561-8417 g y , Dec '97 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 AnChorage, AK 99503-5711 ATTN: Sherrie NO. 121339 Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 4~3/00 Field: Alpine Color Well Job it Log Description Date BL Sepia Prints CD r, CD1'27~c~'' 20112 M10,CDR IMPULSE 000228 1 CD1-27 20112 MD GR/RE$ 000228 I 1 CD1-27 20112 TVD GR/RES 000_~_~8 I 1 ., --~.~-~r_l~ s,~.~.: ~ .^~: APR 10 2000 Naska Oil & Gas Cons. ~ummissi0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~.Or'agO ARCO Alaska, Inc.~',.,~ Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 03, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well: CD1-27 Dear Sirs: ARCO Alaska, Inc. hereby requests that CD1-27 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Please find attached form 10-403 and other pertinent information as follows: . 2. 3. 4. 5. 6. 7. Form 10-403 Surface Casing Description Surface Casing Cementing Report Copy of the Daily Drilling Report covering surface casing cementing. Casing and Formation Test Integrity Report (LOT at surface casing shoe). Formation LOT on 9-5/8" x 7" casing annulus. CD1-27 Well Completion Schematic. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792, Brian Robertson Senior Drilling Engineer CC. CD1-27 Well File Alpine Files Doug Chester Gracie Stefanescu ANO-382 Anadarko RECEIVED ~.~,ar~ 07 2000 Alae~ Oil a Gas Cons. Commim~on /lnchorage RECEIVED 07' Alaeka'Oil & Gas Cons~ Commission Anchorage .. /\1{(;() AI;u;I,:a, Ill(:. i:; ;t b;lll):;idHH'y OI Al[;Hili¢;l{il:hil(~lli(.:Olllp;H']V STATE OF ALASKA i" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: 2. Name of Operator ARCO Alaska, Inc. Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ 3. Address P. O. Box 100360 _Anchorage, AK 99510-0360 4. Location of well at surface ,/' ~' ~"' 408' FNL, 2391' FWL, Sec.5, T11 N, R5E, UM At target (7" casing point in Alpine)) .876' FSL, 1223' FEL, Sec 5, T11 N, R5E, UM At effective depth At total depth 1772' FNL, 179' FWL, Sec.9, T11N, R5E, UM ...... 12. Present well condition summary Total depth: Effective depth: Casing Conductor 5. Type of Well: Development _X Explorato~j _ Stratigraphic _ Service _ Surface Production per APD per APD measured 11492 feet true vertical 7050 feet measured 11492 feet true vertical 7050 feet Length Size Cemented 77' 16" 10 cu.yds, Portland Type 3 2585' 9.625" 409 sx ASL3, 233 sx Class G 8466' 7" 143 sx Class G Other _ Annular Injection - X 6. Datum eleva~on (DF or KB feet) RKB 56' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-27 9. Permit number / approval number 200-06,/' APl number 15~.103.20324.00~/ 11. Field / Pool Colville River Field/Alpine Oil Pool OR GINAL Measured Depth 114 2622' 8500' True vertical Depth 114 2366' 7063' CD1-27 is as an open hole production well. It was suspended after being completed with 4-1/2" tubing. It is intended that the 9-5/8" x 7" annulus be used for injection of associated drilling waste as per the previously applied for annular waste disposal permit application. RECEIVED · 0 7 ; 000 113. Attachments Description summary of proposal _ Detailed operations program _ 14. Estimated date for commencing operation 115. Status of well classification as: April 1,2000 I ' .16. If proposal was verbally approved lOft _..).X_ Gas _ I Name of approver Date approved IServica _ 17. I hereby certify t~t the foregoing is true and correct to the best of my knowledge. 'Signed /.~/~.4 .~ ~~ .... Title: Drilling Team Leader /"/ FOR COMMISSION USE ONLY Conditions of apg~'val: Notify Commission so representative may witness Plug integrity _ BOP Test _ Mechanical Integrity Test _ BOP sketch Suspended_ Date Location clearance _ Subsequent form required 10-~ ~::~g ~::3,t'-~,~.~3.~" ,~'~p._~.-\~::~ ~ Approved by order of the Commission ORIGINAL SIGNED BY' ~,.k,~,.~ ~ C'.hri_~t~q~Or~ q '~,'~.,~e~,,~.-.. - ........ Commissioner Date c~-'&;~ 2'''' ~/~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Casing Detail 9 5/8" Surface Casin; Well: CD1-27 Date: 2/17/00 Subsidiary of Al~al Subsidiary of A~antic Richfield Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.60 FMC Gen V Hanger 2.19 36.60 Jts 3 to 68 66 Jts 9-5/8" 36# J-55 BTC Csg 2494.25 38.79 Davis Lynch Float Collar 1.52 2533.04 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 85,56 2534.56 Davis Lynch Float Shoe 1.77 2620.12 2621.89 TD 12 1/4" Surface Hole 2631.00 RUN TOTAL 40 BOWSPRING CENTRALIZERS - I per jt on Jt #1 - #13 (On stop rings of Jt #1 & #2) #15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39, 41 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63, 65, 67 8 Jts left out #68 - #75 Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 150k Dn Wt - 138k Block Wt - 70 Supervisor: S. Reynolds/ S. Goldberg ,4k, ARCO Alaska, Inc. Cementing Details Well Name: CD1-27 Report Date: 02/18/2000 Report Number: 1 Ri~l Name: Do}/on 19 AFC No.: 998C03 Field: ALPINE Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: I % washout: 9-5/8" 12-114" 2621I 2533I 12.9 'Centralizers State type used, intervals covered and spacing 'Comments: Used 40 9-5/8" bowspring centralizer. 1 per joint first 13 joint and 1 per 2 joints to surface. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 9.7 21 12I 47 20 Gels before: Gels after: Total Volume Cimulated: 34/63/67 12/38/43 519 bbls Wash 0 Type: Volume: Weight: Comments: Water 40 bbls 40 bbls viscosified water wlnutplug Spacer 0 Type: Volume: Weight: Comments: ARCO 545 $0 bbls 10.5 ppg Lead Cement 0 Type: Mix wtr tamp: No. of Sacks: I Weight: Yield: Comments: .' AS III Lite 70 409I 10.7 ppg 4.44 Additives: · ·Class G+30% D053, 0.6% D046, 1.5% D079,1.5% S001, 50% D124, 9% BWOW D044. . .. Tail. Cement. '°. ! = =. ' .. Type: Mixwtrtemp: I No. of Sacks:I Weight: Yield: C'.o~n)ents.: '. :': . G 70 233 15.8 ppg 1.17 . .. ". =.: .... ' ' · . ' Additives: '! i: :' ' Class G+ 0.2% D046, 0.3% D065, 1% S001. D'ispl~,c~i/ieiit. ':0~' '..'. ". ' :...' '~. :/i. Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: ~:o~hi~:~!' i,.i;., ...':...:;..i .'..::.r .:. :i 8 bpm 8 bpm 150k ... ..... ':: ' = Reciprocation length: Reciprocation speed: Str. Wt. Down: : " 'i. :" ': ' :: ' '. ; ~ :' ';: 30' 15' per minute 138k ; : ::: '~ ;' i' ': ::: ::' .' ::i i:..:. :::.::::i! :i',' ::'.::: :.; Theoretical Displacement: Actual Displacement: Str. Wt. in mud: i:.:. ::.' : ." .': :' i":':; i! ..... ":' .:. ' 176 bbls 175 bbls .0.4k Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:2-17-99 yes yes Time:21:25 hrs Remarks:Preflush @ surface 33 bbls over calculated volume pumped of 259 bbls--assuming gauge hole-. Average hole washout back calculated to 12.9%. Had contaminated spacerlcmt returns 30 bbls into rig displacement. Approximately 65 bbls contaminated mud and 80 bbls good cement returned to surface. Cement Company: Rig Contractor: IApproved By: DS DOYON I Scott D Reynolds Daily Drilling Report ARCO Alaska, Inc. AFC No. I Date Rpt No Rig Accept - hrs Days Since AcceptJEst: 2.25 / 2.25 998C03 102/1712000 3 102/15/2000 06:30:00 Rig Relase - hrs: IPM Well: CD1-27 Depth (MD/TVD) 2631/2373 Prev Depth MD: 2415 Progress: 216 Contractor: DOYON Daily Cost $ 201560 Cum Cost $ 410708 Est Cost To Date $ 410000 Ri~l Name: Doyon 19 Last Cs~l: 9 5/8" O 2621' Next Cs~: 7" O 8489' Shoe Test: n/a Operation At 0600: Testing BOPE. Upcoming Operations: MU BHA & orient. RIH, teat casing, drillout & perform LOT/RT. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL SPUD 2631 I N TST 02/06/2000 02/16/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.7ppg 145 12.25 01103/2000 02/05/2000 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 57sqc 154 HTC N SPACE 02/16/2000 06/21/2000 PV/YP SO vv'r' TYPE TYPE TYPE FUEL & WATER · 12 / 20 130 MXC1 ' · GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 4568 12 / 38 / 43 9 E28ZY APl WL MAX DRAG , DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 820 15 2631 02/1 5/2000 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN '" ""i :.' POTABLE WATER 97 : . : . mi/30 min 0800 115 .INJECTION ' "?., USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL ,..:'%::i::,: ;i"i. ::' .'..'"::.'.'.'='.;:iWE~THER::,&!;=.i'?'.'. '". ':"'. '::.. :: :':."..'"~',: 7% 8000 2516 CD1-36 HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F -22 360bbl 17801 2000 I ~ 16.33/7.62 / CD1-27 MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 21 20 1 121 I lS- as 3.s ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 45° 9.1 5.5161 I 8o- 1150 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F -71.30 1.5% 771771 I water Base Muds 902 PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 2 150 27213221 I 101151151151 I IIIII 50 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $9313 III $11910 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $15660 III 41SlWTIA III 952 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 16 Mi I I I EI 1 IRG I TD I I I 9372 PERSONNEL TOTAL 491 ~'H~'iI~I~'$CR ~ ~lq~?!TM '. ':. :.i I Bit, 1.4 dog AKO Navidrill MachlC, NMDC-short, NMSTAB, MWD, UBHO SUB, 2-NMDC, NMSTAB, DC, XO, 3-HWDP, JARS, :;;..";i! :.':?. :;.'::';,"!:".::'.'.'..:':::i...:.'.'=":..:.:.'.::i' , 'i.126.HWOP ' '",, :", · ",: ,:'" ',,, :,: ' ':', :, ', ',,':' :: ',:" ,',: ',,",'::,::,':':,':,:' , ,, ': 'DRIEU~Ii~E:'::Ei'A,:rA,ii:"':: :,,:'!'?i'"::':,,:::,,":""':':',,,: ',:: =',,,,,'",::', ',';',,': :,','"'":',i :',,':,: = ,:,"::~,%,':::'!',:,i:':,',':¥',:',':::! BHA NO I ' ,",' ,'OD .... :,, :' ,:i' :' ;:'ID:,:, ,, ", BHA LENGTH 1062.42' 5 4.281 19.6 G106 4-1/2" I.F. DATE LAST 5 3 49.3 HWDP 4-1/2 IF 871.49 INSPECTED: HOURS ON JARS: DAH0103UJ 16.33 hfs .. TIME" i' i: I'..,..EN'Di. :. '1",:." ;HOURS:' .: :. ' 'OPS.OODE::: :'.1'::":'"' HOLE.;.SEC~: :.' ':I;PHASE:'OPS'.,. · ".'1"' "..' ':: .' '. '.' ":..OI~ER~I'O~S:.FRi3M~".000~)!.~:'00(~0.'!:' i'.. '::: .'::.:.':::ii:::: :'..,!:,:.:.::' 12:00 AM 03:00 AM 3.00 DRIL SURF Making Hole Drill f/2415' t/2631'. ART=2.44 hrs; AST= 0.0 hrs. 03:00 AM 04:00 AM 1.00 CIRC SURF WiperTrip Circulatate sweep-large amount of cuffings-circulate until hole clean. Observe well-static. 04:00 AM 05:00 AM 1,00 WIPERTRP SURF WiperTrip POOH wet t/1587' (base permafroat). RIH with no problems. 05:00 AM 05:30 AM 0.50 CIRC SURF Trip Out Circulate sweep--more cuttings to surface-circulate hole clean. Observe well--static. 05:30 AM 08:30 AM 3.00 TRIP_OUT SURF Trip Out POOH to BHA. Observe well-static. 08:30 AM 09:30 AM 1.00 BHA SURF Trip Out Stand back DC's; LD UBHO- MWD- STAB- motor. 09:30 AM 10:30 AM 1.00 BHA SURF Trip In Clear rig floor of miscellaneous BHA equip. 10:30 AM 11:30 AM 1.00 RUN_CSG SURF Casing and RU slips-elevators-tongs & Franks fill up tool. Cementing Daily Drilling Report: CD1-27 02/17/2000 Page 1 i11:30 AM 12:00 PM 0.50 RUN_CSG 12:00 PM 04:30 PM 4.50 RUN_CSG 04:30 PM 07:30 PM 3.00 CIRC 07:30 PM 09:30 PM 2.00 CEMENT 09:30 PM 10:30 PM 1.00 CEMENT 10:30 PM 11:00 PM 0.50 BOPE 11:00 PM 12:00 AM 1.00 BOPE 24.00 SURF SURF SURF SURF SURF SURF SURF Casing and Cementing Casing end Cementing Casing and Cementing Casing and Cementing Casing end Cementing Other Other PJSM for running 9-5/8" casing. RIH w/9-5/8" casing, wash through tight spots f/1320' t/1440'. Continue to RIH t/2631' with no more problems. Land casing in hanger. Circulate & condition mud for cementing (518 bbls). Reciprocate casing while circulating. MU Dowell cement head & hold PJSM for cementing. Pump-40 bbls pre-wash w/nutplug-5 bbls wtr. Pressure test lines. Drop btm plug. Pump 50 bbl spacer--324 bbls 10.7# lead-49 bbls 15.8# tail-drop top plug-pump 20 bbls wtr. Displace 175 bbls with rig pumps. Bumped plug 1 bbls under calc. disp. CIP O 21:25 hrs. Approximately 00 bbls good cement returned, Check flosts-held, RD cement head & olean floor. Jet Stack and Divertar. ND Diverter. Supervisor. REYNOLDS / GOLDBERG Daily Drilling Report: CD1-27 02/17/2000 Page 2 CASING TEST and FORMATION INTEGRITY TEST · Well Name: CD1-37 Reason(s) for test: Date: 2/18/00 Supervisor: S. D. Reynolds [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,622' TMD 2,366' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: Hole Depth: 2,631' TM D 2,373' TVD EMW = Leak-off Press. + Mud Weight = 790 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,366' EMW for open hole section = 16.0 ppg Used cement unit NO Pump output = 0.0997 bps Fluid Pumped = 1.0 bbl$ Riq Dump used # 2 Fluid Bled Back = 0.5 bbls 2.800 psi 2.(100 I I I I I I I I I J 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 2.800 psi I I I I I I i I I I I I I I ! I~¢L~ I ! ! ! I I I I~11 I I I I I I I I I I I I I I 2.300 psi 2.200 psi 2.100 psi TIME LiNE J ?,000 psi ,.~.,, . , ~..N..~...~!.!.,.N..u_._T.~..~!_C_.~.K.~_.~..... ! I 1,700 psi J i,f~0 psi ~ LEAK-OFF TEST 1,50o psi 1,400 psi ~CASlNG TEST 1,3oo psi -+-- LOT SHUT IN TIME 1,200 psi 1.100 psi ~ CASING TEST SHUT IN TIME ],ooops~ i TIME LINE ~ psi 800 psi ~ 0psi I 0 10 20 30 40 50 60 STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ................ '1 ....... % ....... '1 i i · i , U , 0 DSI , ................ ; ............... -I- ........ ' ........ · | 2.0 i 130psi .,' J- ............... 1 ............................... t I 4.0 280 psi ................ 1 ..... '~ii~ ..... r"'~g[~"l;'~i-"l ................ ! ....... "'" ...... i ................. , 8.0 , 560 psi , ................ 1 ..... '~::~ ..... t'"~T~"~'a'"l ................ ~ ....... 2.' ...... ~ 10 0 ................ I ........ ' ...... ,+ ................ ! ................ 4 ............... i , , , ! ................ ~ ............... a- ................ J , i i ................ l ............... i i i ................ J ............... i ................. t i i i ................ 4 ............... -i- ................ i , , ! ! , , ! ................ · J ............... ~ ................ t i , a , SHUT IN TIME J SHUT IN PRESSURE min 0.0 , , 700 psi -'i.o m~ ~ ............... t"'~b"~'a .... "'~:~'m~ 1 ............... t"'~b-~'a .... ................~.0 m~ 1 ............... t'"~b"~'a .... ................4.0 rain 1 ............... t---/~b--~-a .... "'~:b"~h'"l ............... t'"/:/b"~'a .... ::::::::::::::::::::::::::::::::::::::::::::::: 7.0min ; ; 740 psi "-~:b",~i~,"-J ............... t'-'¢;i~"~'~i .... "-'~:0' ........ min J ............... l"-'~:{b"~,'a.... ..].o...9._m.'."..~ ............... ~...Z.42..P.s.' .... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ................ T ............... T ................. i i · i , Ostks , Oos, , ................ t ............... ~ ....... -" ........ -I ................ i...~..~.t~ ....... ................ i...to.~.t~ ...... ................ i...t~.?.t~ ..... .~:.a..a..o....~!.4 I 28 stks 2,500 psi .,'-'--". ................ ................ i ............... i ................ 4 ................ t ............... T ................ 'I,, ................ J ............... T ................ I ................ I ............... ! ................ I ................ t ............... ; ................ i ................ t ............... T ................ I ................ i ............... i ................ 4 ................ t ............... ; ................ i ................ i ............... 4 ................ 4 ................ J ............... ~ ................ i I ~ J ....0.:.0..~i.n...i ............... i...2.,._S.0..0...P.s. [. j 1.0min I I 2,425 psi l ................ !' ............... 1' ................ '1' 2.0 min 3.0 minj j 2,410 ps, "'~['b"~i'¢l'"," ............... ',"'~;iii~[}'~ii'1 ..... : .......... .._s. :9. mLn...i ............... i---~-'-a-~-°- 6.0 min[ J 2,390 psi J "'~;6"r~f~'"l ............... l"~,'§[iD"~i'! "'~6"r~[B-'l ............... l"~;~ii~"~i'~ "'~.'~)"r~[B'"l ............... !"~',':~ii~'~'~i"l,' 15.0 min I ! 2,375 psi I ................ 20 0 min ...... '- ......... f ............... f ................ -I ' i i · i 25.0 mln., ., 2,350 pst: ............ .'"'t ............... !' .............. ~'~ ...3..o...9...m.'..n_l ............... i...~.,.a_s. P...P.s.:. j NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Modified by Scoff Reynolds CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-27 Date: 2/23/00 Supervisor: S.D. Reynolds Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG X Casing Setting Depth: 2,622' TMD 2,366' TVD 7" 26# L-80 BTCM CSG TOC Hole Depth: 7,774' TMD 6,699' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 5,152' EMW = Leak-off Press. + Mud Weight 0.052 x TVD _- 692 psi + 9.6 ppg 0.052 x 2,366' EMW for open hole section = 15.2 ppg Used cement unit yes Pump output = bbls pumped Fluid Pumped = 9.5 bbl$ Rig pump used # 2 Fluid Bled Back = N/A gOO psi 800 psi 700 psi (K)0 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi : .% ' . ITIME LINE i "',,, ~ lONE MINUTE TICKS --e,=,. LEAK-OFF TEST Ia~CASING TEST --~- LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME I TIME LINE 0 10 20 BARRELS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT BeLS PRESSURE ................ I ....... '-- ....... 'l ..... '_ ........... T I I ' I , 0 , O DSI , ................ ~ ............... -I ......... ' ........ I I ' I , 0.5 , 30 PSI , ................ · 1 ............... ~ ....... -' ........ ~ I 36 psi ' ............... '1 ................................. ................ i ..... ~...s. .......... .4..s._.,.,..i .... i 2 61 psi i ................ 1 ............... ,'r ................ , 2.5 , 86 psi , ................ I ....... ~' ...... t"'i~'~"~'~i'"l ................ 1 ..... -~:~ ..... ,,+'"i~-'~'a"! ................ 1 ....... ;~ ...... ................ 1 ...... ~:~ ..... t'"~"~'~i'"l ................ ! ....... ~' ...... t'"~"fi'a'"! ................ 1 ...... ~:~ ..... I---'~-~'~i---I ................ ! ....... ~' ...... t'"~'~'~i'"l ................ · 1 ............... ' ................ i 6.5 520 psi ; ................ I ....... ~ .......... '~i"~'~i'"l ................ I ..... '~:~ ......... i i ' I , 8 , 692 OSl , ................ ~ ............... -I ........... ' ...... t ~ 8.5 i 661 psi ~ ................ ! ............... t ............ :'--! , 9 , 631 OSl , ................ ~ ............... a. ........ .. ....... t ~ 9.5 621 psi l i i ' I , 9.5 , 601 DSl , ................ ~ ............... -I- ........ -' ....... t ! ! ! ! ! I ~ 1 SHUT IN TIME I SHUT IN PRESSURE min 0.0 , , 601 psi ""I':D' ........ min I ............... t"~"~'~i'" · "~;~"~f~"1 ............... t'"i~"~'~i'" "'~:;"~i~"'l ............... t'-~"~'a'" "'~,:~' ........ min l ...............t'"~:~§'~'~i'" "'§:8"~ii~'"J ............... t'"~iii"~'~i'" "'~.'~)' ........ min ! ...............t"'~§"l~J'" '-'~:~"~i~-"l ............... t'"~i~"~'~i"' "'~:~'-~-"l ............... t---~r~-a--- "'~:8' ........ min l ............... t'"~i§"l~'~J"' ,.2.o.:.o_.~Ln..: ............... :...~?...p.s.! .... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ................ l'"ii'~'t'l~'E"l ..... b"~i ..... l ................ l ............... l ................ I I I i ................ i ............... i ................ -i ! ! ! I i ................ t ............... t ................ i i ................ f ............... f ................ ! ! · ................ i ............... i ................ 4 ! ! I I I i ................ ~ ............... ~ ................ ................ i ............... i ................ 4 i i ................ i ............... i ................ 4 i i i ................ i ............... i ................ 4 ! ! ................ i ............... i ................ 4 ! ! ! ! ................ ~ ............... ~ ................ I I I ................ t ............... t ................ -I i I ................ ~ ............... ~ ................. ! ! i I ................ t ............... t ................ I ................ ! ............... I ................ I I i i SHUT IN TIME I SHUT IN PRESSURE 0.0 min i i 0 psi ................ ! ............... l ................ -! 1.0 min , , , ........... ~ .... ~ ............... t ................ -I 2.0 m~n I ~ 3.0 min ~ ! ................ ~ ............... t ................ · I I I 4.0 mln , , , ................ ~ ............... ~ ................ -t 5.0 min i I "'~:b"r~'"! ............... I ................ ! "'~;b"r~r~"! ............... I ................ ! ................ t ............... t ................ ! 8.0 min , , , · "~:~"~r~'"! ............... I ................ I "'~'~:~"~r~"l ............... I ................ I "'i~:~"~r~-I ............... t ................ I ................ t ............... t ................ 20.0 min ! , , ................ t ............... t ................ 25.0 min , , ! ................ t ............... ~ ................ -I · I I i 30.0 mln , , , NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Modified by Scoff Reynolds ( Colville River Field CD1-27 Production Well Completion - As Built 16" Conductor to 114' Completion Run on 03/02/00 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1822' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" sis control lines 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2622' MD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3873' MD 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 .DOg KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing Tubing Supended with diesel to lowest GLM Completion MD Camco KBG-2 GLM (3.909" ID) at 5988' MD for E Dummy with 1" BK-2 Latch '~~~~ Camco KBG-2 GLM (3.909" ID) &l \ \ \ \ "Camco DOK-2 Shear Valve (sheared L~'~out) at 7942' MD' II ~, '",,,~l;'l~ Baker S3 Packer at +/- 8065' ~I .~ ~.. ,, l~!i!, ,, mn,=, ,, , , , Oalculated TOO at +/- 7336' MD 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) 4-1/2" tubing joint (1) Baker S3 Packer 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 4-1/2" 10' pup joint WEG (+/- 63 deg) 32' 1822' 3873' 5988' 7942' 8022' 8065' 8141' 8153' Note: 80 solid body aluminum centralizers installed between +/-2660' and +/-5150' Well TD at 11492' MD / 7050' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8500' MD / 7063' TVD @ 90 deg TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~LSllSSION Brian Robcrtson Senior Drilling Enginccr ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-036[) 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Colviile River Unit CD1-27 ARCO Alaska Inc. Permit No: 200-06 Sur Loc: 408'FNL. 2391'FWL. Sec. 5, TI IN. R5E. UM Btmhole Loc. 1772'FNL. 179'FWL, Sec. 9, TI IN, R5E, UM Dear Mr. Robcrtson: Enclosed is the approved application for permit to drill thc above referenced well. The permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Fomaation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must bc 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 arc pumped down the surface/production casing annulus of a well approved for mmular disposal on Drill Site CD I must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the almular 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 thc Commission to witness 'a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting the Commission petroleum field inspector on thc North Slope pager at 659-3607. ~Christcnson. P.E. Chair BY ORDER OF THE4I.OMMISSION DATED this ~ '1~'~ day of January, 2000 dl~':.nclosm'es l)cpartment of Fish & Game. Habitat Section w/o ~.n~cl. l.)cpartment of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation ~ ~d' Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559 .~'72-O~,~".~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 408' FNL, 2391' FWL, Sec.5, T11 N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 876' FSL, 1223' FEL, Sec. 5, T11N, R5E, UM CD1-27 #U-630610 At total depth 9. Approximate spud date Amount 1772' FNL, 179' FWL, Sec. 9, T11 N, R5E, UM 02/04/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I'VD) Property line Alpine CD1- 26 11,490' MD Crosses Sec. 8 to feet 9.3' @ 272' Feet 2560 7,036' TVD feet Sec 9 T11 N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 92° Maximum surface 2490 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Wei~lht Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pro-installed 12.25" 9.625" 36# J-55 BTC 2627' 37' 37' 2664' 2400' 522 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 8452' 37' 37' 8489' 7066' 135 sx Class G N/A 4.5" 12.6# L-80 I BT-M 8052' 37' 37' 8089' 6945' 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)ORIGINAL true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural , Conductor RFCEI'VED Surface Intermediate Production Liner ~ ~'..k l"~ Perforation depth: measured true vertical .~a,~;';~ 0ii & 20. Attachments Filing fee X Property plat BOP Sketch A[[;~0["3,[~ Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certi~ that the foregoing is true and correct to the best of my knowledge Signed ,/~l~/ ,~DV '~.~r~'~ Title ' Drilling Team Leader Commission Use Only Permit Number I APl number ___'~'(~) fy..~No I Approval date,,-~ I See cover letter for ,;~.-~'-'~..~ -- 0~:) 50- //O ~- ~ / "'21~ ~)l~ Other r,,e,cj, uirements Conditions of approval Samples required Mud Icg required Yes /~'No ~ Hydrogen sulfide measures Yes ~o~ Directional survey required ~s~ No Required working pressure for BOPE Other: ORIGINAL SIGNED. BY by order of Approved by Robert N. Christenson Commissioner the commission Date Form 10-401 Rev. 7-24-89 Approved CoPY p, etumed Submit in triplicate Alpine: CD1-27 Procedure , , 3. 4. 5. 6. 7. 8. , 11. 12. 13. 14. 15. 16. 17. 18. Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8-1/2" hole to the intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule 20 AC 25.030. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 1/'2, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus 19. Set BPV and secure well. Move rig off. Well Proximity Risks: i" Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-26 will be the closest well to CD1-27 (9..3' at 272' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 7.9' at 283' MD. Drillin.q Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: There are no faults mapped within the vicinity of CD1-27. The potential for lost circulation in the Alpine Sand is therefore considered to be Iow. However if losses are encountered, conventional LCM treatments have been successful in controlling losses when encountered in previous CD1 wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpin,cI Operations: Incidental fluids developed from drilling operations on well CD1-27 will be injected into the annulus of a permitted well. The CD1-27 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-27 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi CD1-27 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 ~" Section - 6 1/8" point- 12 lA" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 <10 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at __ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% 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 CD1-27 Production Well Completion Plan 16" Conductor to 114' Updated 01/21/00 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1700' TVD = 1834' MD - Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile - Dual 1/4" x 0.049" s/s control lines 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2664' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ +/- 2000 psi set 2 joints above the X landing nipple Baker S3 Packer at +/- 8089' 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 Tubing Supended with diesel to lowest GLM Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1834' 1700' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 3850' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 5985' 6200' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 7988' 6879' 4-1/2" tubing joints (2) HES "X" (3.813" ID) 8057' 6924' 4-1/2" tubing joint (1) Baker S3 Packer 8089' 6945' 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 8154' 6980' 4-1/2" 10' pup joint WEG (+/- 63 deg) 8165' 6986' Note: solid body aluminum centralizers installed between 2400' TVD (=2664') and 4500' TVD (=5155') TOC @ +/- 7715' MD (500' MD above top Alpine) Well TD at 11490' MD / 7036' TVD Top Alpine at 8215' MD / 7008' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8489' MD / 7066' TVD @ 90 deg (" Colville River Field ('' CD1-27 Production Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.25" ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0.049" sis control line 9'5/8 36 ppf J-55 BTC Surface Casing @ 2664' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Updated 01/21/00 (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2000 psi set 2 joints above the X landing nipple TOC @ +/- 7715' MD (500' MD above top Alpine) Baker S3 Packer set at +/- 8089' Well TD at 11490' MD / 7036' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8489' MD / 7066' TVD @ 90 deg CD1-27 (" PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2664 / 2400 14.2 1086 1532 7" 8489 / 7066 16.0 3197 2490 N/A 11490 / 7036 16.0 3183 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 Drilling below conductor casing (16") ASP = [(FG x 0.052) -0.1} D = [(10.9 x 0.052) -0.1] x 114 =53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = -- ASP = -- -- [(FG x 0.052) -0.1} D [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR FPP - (0.1 x D) 3197 - (0.1 x 7066') - 2490 psi 3. Drilling below intermediate casing (7") ASP = FPP- (0.1 x D) = 3197 - (0.1 x 7066') = 2490 psi Alpine CD1-27 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 -500 -1500 -2500 -3500 PR -4500 -5500 -6500 -7500 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT AIP(,..e, CD1-27 Well Cementing Requif~,nents 9 518" Surface Casing run to 2664 MD ! 2400' TVD. Cement from 2664' MD to 2164' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2164' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2164'-1663') X 0.3132 ft3/ft X 1.5 (50% excess) = 235.4 ft3 below permafrost 1663' X 0.3132 ft3/ft X 4 (300% excess) = 2083.4 ft3 above permafrost Total volume = 235.4 + 2083.4 = 2318.8 ft3 => 522 Sx @ 4.44 ft3/sk System: Tail slurry: 522 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% BWOW1 D044 freeze suppressant 500' X 0.3132 ft~/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 8489' MD 17066' TVD Cement from 8489' MD to +/- 7715' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (8489' - 7715')o X 0.1268 ft~/ft X 1.4 (40% excess) = 137.4 fta annular volume 80' X 0.2148 ft°/ft = 17.2 ft3 shoe joint volume Total volume = 137.4 + 17.2 = 154.6 ft3 => 135 Sx @ 1.15 ft~/sk System: 135 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 ft~/sk ~ By Weight Of mix Water, all other additives are BWOCement 550 350 7O0 1050 1400 1750 2100 245O 2800 5150 55O0 5850 4550 49OO 5250 5600 5950 6500 665O 7000 7550 7700 55O AI"..CO Alaska, ItLc. Structure : CD#1 Field : Alpine Field Well : 27 Location : North Slope, Alaska RKB Elevation: 56' KOP 5.00 Begin Turn to Tgi: 7..52 10.26 15.25 DLS: 5.00 deg per 100 ft 16.21 19.19 22.18 25.17 West Sak 28.16 31.16 EOC mrr~Q Permafrosl~ g 5/8 Cas;n9 C40 C50 C20 157.19 AZIMUTH (TO ***Plone of Proposol*** K-3 K-2 AVERAGE ANGLE 32.53 DEG TARGET ANGLE 90 DEG Nb;an -97 Albion-g6 HRZ K-1 Bgn Tm/Bid [o Tgt LCU -. Miluveach A ~ DLS: 9,00 deg per 100 ft Alpine ,D ~ Alpine .~ [~ Tg[- EOC - CsgPt i i i 350 700 i i i i i i i i i i i i i i i i i i i i 1050 1400 1750 21 O0 24502800 3150 5500 · 3850 4200 Vertical Section (feet) -> Azimufh 157.19 wifh reference 0.00 S, 0.00 ir from slof #27 i ! i i i i 4550 4900 5250 For: B Robertson] Idatt~d: 17~-~ ~ Is ~1-27 ~ ~7. In ~t ~m Mot ~27. 700 550 ~ ~ 55O 700 N" CO Alaska, If"c. Structure: CD#I Field : Alpine Field Well: 27 Location: North Slope, Alaska East (feet) -> 0 550 700 1050 1400 1750 21 O0 2450 2800 5150 I I I I I I I I I I I I I I I I I I I )Begin Turn to Tgt West Sok EOC Perma frost SURFACE LOCATION: 408' FNL, 2591' FWL SEC. 5, TllN, R§E C40 1050 1400 1750 2100 2450 ~ 28OO ~ 5150 -I-- 0 5500 . I V 585o- 4200 - 4550 - 4900 525O 5600 5950 6500 6650 7000 i 700 9 5/8 Casing Pt C20 K-5 K-2 TARGET / CASING PT LOCATION: 876' FSL, 1223' FEL SEC. 5, T11N, R5E 157.19 AZIMUTH 7 22' (TO TD) ***Plane of Proposal*** i i i i i 550 0 550 Albran-g7 Albian-96 HRZ Bgn Trn/BId to Tgt Alpine D~ ~lrluveach A Alprne Tgt- EOC - CsgPt INTERMEDIATE Pt LOCATION: 449' FNL, 523' FEL SEC. 8, T11N, R5E 3500 5850 I I I I TD LOCATION: I 1772' FNL, 17g' FWL SEC. g, TllN, R5E i i i i i i i i 700 1050 1 400 1750 East (feet) -> Angle Build End Angle Build Begin Angle Drop ntrrnd Pt - EOC TD - End Angle Drop i i i i i i 21 O0 2450 2800 in Final Build F~nol Build Begin Rnal Drop i i I i I 3150 5500 3850 350 350 700 1050 1400 1750 2100 2450 2800 (j) 0 5150 5500 .~. I 5a5o V 4200 4550 4900 525O 5600 5950 650O 6650 7000 crem,~ ~ Ionm For: B Robert. eon Oot~ #gfild: 17-Jun-2000 Plot ~f~ ~, CDI-~ V~ ~7. ~lnot~ ore Iff f~ ~emnce ~ ~27. INTEq ARCO Alaska, Inc. Structure: CD#1 Field: Alpine Field Well : 27 Looaflon : North Slope, Alaska 5400- 560O 5800 6000 6200 6400 6600 6800 7000 7200 AVERAGE ANGLE 32.53 DEG 157.19 AZIMUTH (re **Plone of Proposol*** TARGET ANGLE 90 DEG i I ! i i i I i 3000 5200 3400 3600 i i i i i i i i i i i I i i i i ii i ii i ii i i i i i i i i i i i i i i i i 5800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 Vertical Section (feet) -> Azimuth 157.19 with referenae 0.00 S, 0.00 E from slot #27 i 7800 JC.m=t.d t,/Ion.. For: B robertsonI Dote p~ottod: 17-Jofl-2000 Plot Rofemnc~ Is CD!-27 Version iT. Coordinotes ore tn feet reference ~lot t1[27. I True Vert~ul Ogptlm ore ref. (Og~gn t111g).1 I I ARCO Alaska, Inc. Structure: CD#1 Well : 27 Field : Alpine Field Location: North Slope, Alaska Point KOP Begin Turn to Tgt West Sc:k EOC Permc:frost C40 9 5/8 Cc:sing Pt C50 C20 K-5 K-2 Albic:n-g7 Albic:n-96 HRZ K-1 Bgn Trn/BId to Tgt LCU Miluveach A Alpine D Alpine Tgt- EOC - CsgPt Begin Angle Build End Angle Build Begin Angle Drop Intrmd Pt - EOC Begin Finol Build End Finc:l Build Begin Finol Drop TD - End Anqle Drop MD 250.00 585.55 1070.16 1545.71 1665.57 2404.66 2664.41 2671.55 3096.14 4526.09 4598.88 6765.45 7142.99 7558.12 7856.84 7848.54 7908.72 8126.74 8159.72 8214.64 8488.75 9488.75 9554.70 9925.20 9989.13 0989.15 1055.77 1425.57 1489.56 PROF In¢ 0.00 4.00 24.28 52.53 32.53 32.53 32.53 52.55 52.55 52.55 52.53 52.55 32.53 52.53 52.55 52.55 57.93 57.49 60.45 65.58 90.00 go.o0 91.98 91.98 90.00 90.00 91.98 91.98 go.o0 ILE COMMENT DATA Dir TVD North 180.00 250.00 0.00 180.00 585.25 -4.65 158.54 1046.00 -161.72 157.45 1288.17 -285.06 157.45 1556.00 -440.79 157.45 2181.00 -808.87 157.45 2400.00 -957.84 157.45 2406.00 -941.57 157.43 2764.00 - 1152.21 157.45 5801.00 - 1 762.92 157.45 4051.00 - 1898.57 157.45 5856.00 -2975.16 157.43 6176.00 -3161.61 157.45 6526.00 -5567.75 157.45 6761.00 -5506.15 157.45 6770.70 -5511.84 156.44 6820.00 -3545.87 154.19 6966.00 -5689.47 155.95 6985.00 -5714.88 155.57 7008.00 -5758.72 151.98 7066-.00 -5994.93 151.98 7066.00 -4877.75 151.98 7064.86 -4955.94 151.98 7052.14 -5261.05 151.98 7051.00 -5319.24 151.98 7051.00 -6202.04 151.71 7049.85 -6260.77 151.71 7057.14 -6584.45 151.71 7036.00 -6642.53 East 0.00 0.00 52.22 101.47 167.05 320.02 575.65 575.10 462.74 716.59 772.89 1219.65 1297.96 1585.64 1441.17 1445.54 1457.20 1524.67 1557.02 1558.64 1680.56 2150.15 2181.12 2554.15 2585.09- 2854.89 2886.52 5060.55 3091.82 V. Sect 0.00 4.29 169.52 500.26 471.07 869.67 1009.55 1013.17 1241.49 1902.85 2049.54 5213.46 3417.55 5640.76 5790.64 5796.82 3831.64 5992.01 4020.25 4069.02 4355.94 5529.85 5595.50 5762.26 5827.90 6825.80 6890.12 7256.02 7521.69 Deg/j,O0 ;0 5.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 9.00 9.00 9.00 9.00 9.00 0.00 3.00 0.00 3.00 0.00 3.00 0.00 3.00 ATTACHMENT 6 ARCO Alaska, Inc. CD#1 27 slot #27 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : CD1-27 Version Our ref : prop3527 License : Date printed : 17-Jan-2000 Date created : 10-Aug-1999 Last revised : 17-Jan-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 33.088,w150 55 36.158 Slot Grid coordinates are N 5975721.251, E 385816.095 Slot local coordinates are 407.55 S 2392.15 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <1863-7896'>,,Bergs2A,Bergschrund %2 PMSS <0-8580'>,,Bergs2,Bergschrund 92 PMSS <0-7502'>,,Bergs1,Bergschrund 91 PMSS <0-10504'>,,5PH1,CD#1 PMSS <9499 - ???'>,,5,CD#1 PMSS <0-10897'>,,3,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <472 - 1545'>,,36PH1,CD#1 PMSS <10016 - 11136'>,,32,CD#1 PMSS <0-11067'>,,32PH1,CD%1 PMSS <7950-11950'>,,45,CD#1 PMSS <0-8844'>,,45PH1,CD%1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <0-9357'>,,16PH1,CD#1 PMSS <0-8350'>,,26PH1,CD#1 PMSS <7755-11134'>,,26,CD#1 PMSS <9146 - 13289'>,,39,CD91 PMSS <0-10224'>,,39PH1,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <384 - 14477'>,,23,CD#1 PMSS <0-11300'>,,13,CD#1 PMSS <0-7331'>,,1PH1,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <0-12055'>,,40,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <0-10796'>,,24,CD#1 PMSS <0-10548'>,,19,CD#1 PGMS <0-10255'>,,WD2,CD#1 PMSS <0-9236'>,,22,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 18-Jun-1998 935.7 9440.0 9440.0 27-Aug-1999 2680.4 11489.6 11489.6 7-Ju1-1999 3786.1 50.0 50.0 14-Jan-2000 219.1 261.1 261.1 16-Jan-2000 219.1 261.1 261.1 4-Jan-2000 239.8 250.0 7800.0 23-Dec-1999 150.0 100.0 100.0 22-Dec-1999 90.1 100.0 100.0 4-Jan-2000 90.1 100.0 100.0 4-Jan-2000 90.1 100.0 100.0 23-Dec-1999 42.7 500.0 500.0 4-Jan-2000 42.7 500.0 500.0 16-Nov-1999 179.9 200.0 8137.7 4-Jan-2000 179.9 200.0 391.7 25-0ct-1999 110.0 100.0 11489.6 4-Jan-2000 110.0 100.0 100.0 4-Jan-2000 9.3 272.2 272.2 1-Nov-1999 9.3 272.2 11100.0 22-Sep-1999 100.3 755.6 10640.0 4-Jan-2000 100.3 755.6 755.6 26-Aug-1999 78.2 911.1 11489.6 18-Aug-1999 39.9 100.0 100.0 15-Ju1-1999 139.8 100.0 7580.0 4-Jan-2000 259.6 250.0 250.0 27-Jun-1999 259.6 250.0 250.0 28-Jun-1999 130.0 100.0 455.6 28-Jun-1999 79.9 100.0 477.8 28-Jun-1999 29.9 250.0 250.0 28-Jun-1999 79.6 261.1 261.1 28-Jun-1999 1192.0 272.2 272.2 28-Jun-1999 49.5 261.1 261.1 ARCO Alaska, In(' Post Office :5ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-27 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 February 04, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-27 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robert'son Senior Drilling Engineer <', ?',&',{ ~.-',' ,., ,, /\1{¢;(1 Ahmk;I, i11,:, iz; ;I :;HJn;Jlll;Jl'y ()1 AIJ;ITllir:l{i(:llliuhl(:l)Jlil,.:lly Attachments CC: CD1-27 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com Anchorage · ..:..:,....:..:... :~.-..::...:. .::.-...~-.:,.::.~.-.,.. : , , , ,.. ~-...... ~-~ .:.~.-...~ , ~ , ~ ! ~ ,,~, _._ ~ -. !.!i: .:<.::.:'.-.:..?-.w_,..-::;.:.!.-=.:- --~4':~-'-"'--'::':'-::-:'--; -.:-;',:':'.~"-'.':": ':"-'"?: %, ' ' ' ., ,',., .~., !~.-...ii~i"..--~'-'-:i~{~ ". · , ~' . "r' ,si.,.:. 839, ' ' ~R~...~laak~,....!~,;~.:,.~ ...'., ...'.', .'".'". .... .' '." 0062.~9.": ".:'". ..... "" .::.¢ :-,-~---*--.::**;:::'-,:'~:":-~:-"-.'":'!¢:E~:~'-':~:OUNT, ' ,,' ,'. CHECKNUi~,.EFI.;,,2,..49 ....,,,...,d :...,':.' ,. 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'"'.:-.;=~--~;~'~:~- :':':'-'":=-::::-:-'.:;:~::-:.~i'~."-'-:;';-":':'": - ". ' ;'_~.-.'W~??-"-~-:. 'i':.-'..'. "' "<. ? ........ ' . ,'. h !-~'.-~ :.,!:!~-'.~ ¢~¢ "!;! ":~;:..-:.-..-. -?;:. p.-~y;.---:.;-~-~:- ... ---.--:- .. ---....... . ........ ,..:. :.::: .-:,!, ..... ~.. .. ,. . . , .;,;.~:,, -,,: .... :~.~.~:..,:........:.....:.~:~..:.~;!:.!;:.; (ii}!-:.~.'~.:,.T _1'~:}~.. :!:.sTA~E-(-13.F--- ALAS.K.¢!b.<- .... ~.~%,,~, ........ '"1 ' ' ,: ;'" ' ,' ' '" ' ' ' .... ' ' ~'~!~'i'..:."~;' :~iii'~"":::.;..-:..; -:-;;;~4.~R. ~:-.:.(.-.--. At~.--"~f~'~:'::'~"i~ 8~i'--'.?~:~'~--'¢itl~-.-G..-NS-E--.I~-.:-~'TIU" ~m-- , ' ....I;.. , '~ .,.'.,__; .... ¢,;, ,~, ' . , ' ;~:; ..~::'..~¢...~?:.f '~' ,, ;~ ;¢..:?'""~' ~' ""--'"'-~';" 'i"?' "':" ':':' ..... , <-~,.'-"~,;:' . ' ' *** . ,yom A~ ~u ,.,a~ .... .. ;.. .... .?.' ..... -.- .... ,,-.~. .. .i,~}~¢<?.-.':-~::.'.=.:*.ii? -.:&-:-*.' -'- ~?'~::.:.,' ':.-"--:-~,. 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' ":. :~'ii{' -;ii:.':i~!,. "¢:i'i':i:,, .':.~a~.--,~.:- ' ;::-'.-:'. :-:',-:: ..... :'-:' .... ."'." '~::¢ 8:-¢ "i' ' :' ,' ,, · ':' , · ¢/;.~,:.h;~-..:;d!.*.:':-'/:. ~':¥"; "'/' ; ' ":'<'::'~"' ' ? · '" '' ' ' ' ' '3" :1~:." I~,.,11,.I ..m ' . · .: ~ . -..:...-.-..--.. . .. . . : . '.'.=-,::.'..*~:**i?:??-'-';is*' :, II ..~:::~.~:1= I::...;-~?..,~.~,......,. .. .......... . ...... : ...,...:.......:,:~- ..,: .:...-.,,.... .... .:-.-.- ...... . ......... ..... ....................................................... .... I · . WELL PERMIT CHECKLIST COMPANY ~/~'/"'~ WELL NAMEC_~:?,~' ~--~;;~/"~. ? PROG~M: exp FIELD & POOL /~O/~ . INIT C~SS ~~ ~/~ ADMINISTRATION 1. Permit fee aEached ........................ ~N 2. Lease number appropriate.~ ~ ~.~,~ ./~; ~ Z~ 3. Unique well name and number .................. 4. Well located in a de~ned pool .................. 5. Well located proper distance from drilling unit bounda~ .... 6. Well located proper distance from other wells .......... 7. Su~cient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... ~ 9. Operator only affected pa~y ................... N 10. Operator has appropriate bond in force ............. ~ 11. Permit can be issued without conse~ation order ........ I~ A~PR DATE 12. Permit can be issued without administrative approval ...... I1~ D/' ~'~ 13. Can permit be approved before 15-day wait ........... I~1I ENGINEERING 14. Conductor string provided ................... ~ N 15. SuEace casing protects all known USDWs ........... ~ N ~~%~ ~ devv" redrll serv wellbore seg ann. disposal para req .__ GEOL AREA ~C::?__/~ UNIT# __/"') ~__~,"~ ::::~,/'_,..=.~/'~ ON/OFF SHORE ·, .~~,. DATE ~_~=~__'~ GEOLOGY DATE ANNULAR DISPOSAL APPR DATE 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... ~ 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... -Y H-~ I~ 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 ................ BOPE press rating appropriate; test to ~,~c,(~r,,~ psig. Choke manifold complies w/APl RP-53 (M~y 84) ........ 26. 27. ~ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. ~Y'~Y ~ ~~_ 30. Pe rmit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... '~'~"~- 32. Seismic analysis of shallow gas zones ............. Y N 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory only]~ N 35. With proper cementing records, this plan 1~,,-,.,.3\,c..,.~- \~,,~.~.~-'~ ~'- (A) will contain waste in a suitable receiving zone; ....... ~) N (B) will not contaminate freshwater; or cause drilling waste... to surface; · (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a t~ N Comments/Instructions: 'pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ~"') N GEOL~ ENGINEERING: UICIAnnular COMMISSION: RP~G~I~-~. BE..VV"~. WMt/Xa /z oo DWJ S ..' JDH~ ' RNC / . TE _~~_ ~ 'i~.'~. ",¢,.Z~ CO ~ '/z.(.,, c:\msoffice\wordian\diana\checklist (rev. 09/27/99)