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Home My WebLink About201-191 STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E 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 0 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development 0 Exploratory❑ 201-191 '- 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20393-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075 CRU CD2-34 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 8755 feet Plugs measured None feet true vertical 7210 feet Junk measured None feet Effective Depth measured 8755 feet Packer measured 7328 feet true vertical 7210 feet true vertical 7079 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 59' 16" 96' 96' CAN110 ;- ,b .2 [G�, F~ Surface 2332' 9.625" 2369' 2365' Intermediate Production 7767' 7" 7802' 7202' RECEIVED Liner OCT 0 7 2016 Perforation depth Measured Depth: Open Hole Completion, 7802'- 8755' MD 01 True Vertical Depth: 7202'-7210'TVD AOGCC Tubing(size,grade,measured and true vertical depth) 3.5", L-80, 7640' MD, 7192'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker SAB-3 Packer, 7328' MD, 7079'TVD SSSV: Camco TRM-4E locked out, WRDP installed, 1988' MD, 1984'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7802'-8755' 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: 673490 1187 1231 214 Subsequent to operation: 858 285 1331 1244 212 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development0 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 Anu Sood Email Anu.Sood@cop.com Printed Name Anu Sood Title Production Engineer f I Signature �..y....--- 9 Phone 263-4802 Date /gyp c//(? VTL 10it74i , /4y-4( RBDtPIIS L-l-OCT1 0 2016 Form 10-404 Revised 5/2015 Submit Original Only • • CD2-34 Scale Inhibition Treatment 9/18/16 Hybrid Scale Inhibitor Squeeze Job pumped on 9/18/16 from 08:30 hrs to 12:45 hrs. LRS= Little Red Services - Initial pressure TBG/IA/OA-530/1150/528 - LRS pumped 35 bbls Seawater/WAW5206 pre-flush at 1-1.5 bpm ,TBG/IA/OA-0/1087/334 - LRS pumped 35 bbls Seawater/SCW3001WC scale inhibitor main treatment at 2.5 bpm, TBG/IA/OA—0/1049/304 - LRS pumped 736 bbls Dead Oil over-flush at 3—3.5 bpm,TBG/IA/OA—0/1036/308 Interval treated: 7,802'—8,755' WNS • CD2-34 • ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc, Y .. Wellbore API/UWI Field Name Well Status Incl(') MD(ftKB) Act Btm(ftKB) i ,,;,,,,, 501032039300 ALPINE PROD 92.40 7,936.81 8,755.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ... Well comig:-coza4,12/812012 1207.31 PM SSSV:WRDP Last WO: 43.11 1/1/2002 Schematic-Actual. Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag Rev Reason:SET NEW WRDP ninam 12/8/2012 Casing Strings HANGER,32 - owCasing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.6 96.0 96.0 62.58 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING PUP, SURFACE 9 5/8 8.921 36.6 2,368.8 2,364.5 36.00 J-55 BTC 34 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 35.2 7,801.8 7,202.4 26.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(5...Set Depth(TVD)...String Wt...String...String Top Thrd OPEN HOLE 6 1/8 6.125 7,802.0 8,755.0 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd TUBING 4.5x3.5" 3 1/2 2.992 32.3 7,639.6 7,192.4 9.30 L-80 8RD-MOD 11 Completion Details Top Depth (TVD) Top Incl Nomi... TUBING,36, Top(ftKB) (ftKB) C) Item Description Comment ID(in) CONDUCTOR. • 32.3 32.3 -1.04 HANGER FMC TUBING HANGER 3.958 37-95 ____ 123.0 123.0 0.28 XO Reducing CROSSOVER 4.5 x 3.5" 3.500 XO Reducing, 1,988.3 1,984.1 1.93 SAFETY VLV CAMCO TRM-4E SAFETY VALVE(LOCKED OUT) 2.812 123 7,282.3 7,053.3 55.97 SLEEVE-C BAKER CMPA w/BX-Closed 1/16/02-SS(UP to close w/3.5"shift 2.813 i : tool) 7,327.9 7,078.6 56.66 PACKER BAKER SAB-3 PACKER 3.000 7,407.6 7,120.1 63.77 NIPPLE HES XN NIPPLE 2.750 WRDP,1,988-. r , 1 7,638.3 7,192.1 81.44 WLEG BAKER WIRELINE ENTRY GUIDE 2.992 SAFETY VLV, {I ; 1 1,988 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth - (ND) Top Incl Top(ftKB) (ftKB) P) Description Comment Run Date ID(in) 1,988 1,984.1 1.93 WRDP 2.81"X-LOCK ON 3.5"WRDP(S/N:HWS-698) 11/16/2012 Notes:General&Safety End Date Annotation 2/2/2011 NOTE View Schematic w/Alaska Schematic9.0 SURFACE. .J l 37-2369 E GAS LIFT, 3,391 GAS LIFT, C-- 5,701 GAS LIFT, E,' 7,203 11 SLEEVE-C, 7,282 a PACKER,7,328 NIPPLE,7.408 ;I i. Mandrel Details Top Depth Top Port r---::--._ (ND) Incl OD Valve Latch Size TRO Run Stn Top(RKB) (5369) C) Make Model (in) Send Type Type (in) (psi) Run Date Com... 1 3,390.6 3,386.2 0.97 CAMCO KBUG-M 1 GAS LIFT GLV BK-5 0.188 1,765.0 1/17/2002 7:30 61 WLEG,7,638- 2 5,701.1 5,688.7 15.08 CAMCO KBUG-M 1 GAS LIFT GLV BK-5 0.188 1,748.0 1/17/2002 10:00 3 7,202.8 7,002.6 46.88 CAMCO KBUG-M 1 GAS LIFT OV BK-5 0.188 0.0 1/17/2002 6:00 PRODUCTION, 35-7,802 a OPEN HOLE, 7.802-8,755 TD(C132-34). 8,755 STATE OF ALASKA ALIKA OIL AND GAS CONSERVATION CONIPSSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations 1 Fracture Stimulate r Pull Tubing r Operations Shutdow n Performed: Suspend r Perforate r Other Stimulate n Alter Casing r Change Approved Program Rug for Redrill r- Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Scale Inhibitor Treatment J 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 201-191 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service - 50-103-20393-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075 - • CRU CD2-34 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured ' 8755 feet Plugs(measured) none true vertical . 7210 feet Junk(measured) none Effective Depth measured 8755 feet Packer(measured) 7328 true vertical 7210 feet (true vertical) 7079 Casing Length Size MD TVD Burst Collapse CONDUCTOR 59 16 104 104 SURFACE 2332 9.625 2369 2365 PRODUCTION 7767 7 7802 7202 RECEIVED JAN SEP 7 0 2015 Perforation depth: Measured depth: open hole 7802'-8755' C�� 1 �� True Vertical Depth: 7202'-7210' AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 7640 MD,7193 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER SAB-3 PACKER @ 7328 MD and 7079 TVD SAFETY VLV-CAMCO TRM-4E SAFETY VALVE(LOCKED OUT)W/WRDP INSTALLED @ 1988 MD and 1984 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 657 1102 1069 1095 206 Subsequent to operation 879 1491 1283 1080 211 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory fl Development F7 Service r Stratigraphic fl Copies of Logs and Surveys Run r 16.Well Status after work: , Oil 7 Gas [ WDSPL Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r 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: none Contact Kerry Freedman @ 265-6579 Email Kerry.C.FreedmanAconocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature '/ 71.44-.2---_______ p Phone:265-6579 Date c 'q //S JI/T-L q/jt 115. A 0k0.1" Form 10-404 Revised 5/2015 RBDMS S�P 2015 Submit Original Only 0 • CD2-34 Scale Inhibition Treatment 8/10/15 Hybrid Scale Inhibitor Squeeze Job pumped 8/10/15 from 08:00 to 16:20. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA- 680/1005/760 - LRS pumped 35 bbls Diesel/M209/WAW5206 pre-flush at 2 bpm ,TBG/IA/OA-0/1005/327 - LRS pumped 35 bbls Seawater/SCW3001WC scale inhibitor main treatment at 2 bpm, TBG/IA/OA—0/976/295 - LRS pumped 295 bbls Dead Oil/M209 over-flush at 4 bpm, TBG/IA/OA—18/939/290 - ACF pumped 448 bbls Dead Oil over-flush at 1.3 bpm,TBG/IA/OA—0/925/250 Interval treated: 7,802'—8,755' • • i WNS CD2-34 CQntCtPhIIlIpS Well Attributes ]Max Angle&MD TD 1t1; Wellbore API/UWI Field Name Well Status Incl(^1 MD(ftKB) Act Btm(ftKB) CxxrwmPllgBps.. 501032039300 ALPINE PROD 92.40 7,936.81 8,755.0 °"". Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well cora: coz-34,tzrenz SSSV:WRDP Last WO: 43.11 1/1/2002 Schematicot =Actuatz.o7:3t PM Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:SET NEW WRDP ninam 12/8/2012 � ,,. Casing Strings , HANGER,32 "MI 'Yirs Casing Description String 0String ID_.Top(ftKB) Set Depth(f...Set Dpth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.6 96.0 96.0 62.58 H-40 WELDED uIg Casing Description String 0String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING PUP, " SURFACE 9 5/8 8.921 36.6 2,368.8 2,364.5 36.00 J-55 BTC 34 :, Casing Description String 0String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 'TT PRODUCTION 7 6.276 35.2 7,801.8 7,202.4 26.00 L-80 BTCM II "" Casing Description String 0.. String ID...Top(SKS) Set Depth If...Set Depth(TVD)...String Wt...String...String Top Thrd €i _ OPEN HOLE 6 1/8 6.125 - 7.802.0 8,755.0 Tubing Strings Tubing Description String 0String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String..String Top Thrd TUBING 4.5x3.5" 31/2 2992 323 7,6396 i 7,192.4 9.30 L80 8RD-MOD Corn r letionDetails �:„ .3 wE.... x •^. _ a Top Incl Nom TUBING,36 Top(ftKB) (ftKB) (0) Item Description Comment ID(inn)) CONDUCTOR._ 32.3 -1.04 HANGER FMC TUBING HANGER 3.958 37-� �" 123.0 0 0.28 XO Reducing CROSSOVER 4.5 x 3.5" 3.500 SO Reducin 1,988.3 1.93 SAFETY VLV CAMCO TRM-4E SAFETY VALVE(LOCKED OUT) 2.812 g, : r' 1231 7,282.3 7,053.3 55.97 SLEEVE-C BAKER CMPAw/BX-Closed 1/16/02-SS(UP to close w/3.5"shift 2.813 tool) 7,327.9 7,078.6 56.66 PACKER BAKER SAB-3 PACKER 3.000 7,407.6 7,120.1 63.77 NIPPLE HES XN NIPPLE 2.750 WRET,1,988 SAFETY VLV, 7,638.3 7,192.1 81.44 WLEG BAKER WIRELINE ENTRY GUIDE 2.992 1.988 — Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) l. Top Depth (ND) Top Incl Top(ftKB) (gKB) P1 Description Comment Run Date ID(n) 1,988 19841 193 WRDP 281"X-LOCK ON 35 WRDP(S/N HWS-698) 11/16/2012 i lki Notes:General&Safety End Date Annotation 2/2/2011 NOTE:View Schematic w/Alaska Schematic9.0 ]I SURFACE, 1: iL 37-2,369 #g u GAS LIFT, Ili 3,391 GAS LIFT, 5,701 I GAS L,20IFT3, 7 777 II SLEEVE-C, 7,282 ._. PACKER,7,328 089101' ...._...._.. ' ' i NIPPLE,7,408 Mandrel Details Top Depth Top Port -=- (TVD) Incl OD Valve Latch Size TRO Run Zr Stn Top(ftKB) (ftKB) P1 Make Model lin) SemType Type )in) (psi) Run Date Com... 1 3,390.6 3,386.2 0.97 CAMCO KBUG-M 1 GAS LIFT GLV 8K-5 0.188 1,765.0 1/17/2002 7:30 WLEG,7,638 2 5,701.1 5,688.7 15.08 CAMCO KBUG-M 1 GAS LIFT GLV BK-5 0.188 1,748.0 1/17/2002 10:00 3 7,202.8 7,002.6 46.88 CAMCO KBUG-M 1 GAS LIFT OV BK-5 0.188 0.0 1/17/2002 6:00 PRODUCTION, 35-7,802 OPEN HOLE, 7,802-8,755 TD(CD2-34),N 8,755 STATE OF ALASKA ' ALASKA •AND GAS CONSERVATION COMMISS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell j"" Plug Fbrforations j` Stimulate 17,-0 5t 414 - Other r Alter Casing '°- Pull Tubing f Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r - 201 -191 - 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 •. 50 103 - 20393 - 00.4(0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075 — - CD2 - 9. Field /Pool(s): • Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 8755 feet Plugs (measured) None true vertical 7210 feet Junk (measured) None Effective Depth measured 8755 feet Packer (measured) 7328 true vertical 7210 feet (true vertucal) 7079 Casing Length Size MD TVD Burst Collapse CONDUCTOR 59 16 104 104 SURFACE 2332 9.625 2369 2365 PRODUCTION 7767 7 7802r. "+i: j. A,1,1.: ¢ � E x ... ..- Perforation depth: Measured depth: open hole completion 7802' - 8755' True Vertical Depth: 7202' - 7210' Tubing (size, grade, MD, and TVD) 4.5 x 3.5, L -80, 7638 MD, 7192 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER SAB -3 PACKER @ 7328 MD and 7079 TVD SSSV - CAMCO TRM -4E @ 1988 MD and 1984 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 7802' -8755' 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 1291 2290 394 -- 244 Subsequent to operation 1431 2524 435 -- 247 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development I✓ Service I" Stratigraphic r 15. Well Status after work: , Oil IV Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ I 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 Dan Kolesar (a 263 -4039 Printed Name Dan Koles -, 4 Title WNS Production Optimization Engineer Signature 1 4 o f Phone: 24039 Date 12.2 // RBDMS AUG 04 2011 &% 7,6 $. -a Form 10 -404 Revised 10/2010 Submit Original Only • • CD2 -34 (Hybrid) APD #201 -191 7/16/2011: initial pressure TBG /IA/OA- 600/800/150; LRS pumped 3 bbls dead crude containing 30 gals WAW5206 at 1.5 bpm, 800/800/150; LRS pumped 35.2 bbls SWand SCW3001 WC (220 gal SCW3001WC) at 3.1 bpm, 700/800/150; LRS pumped 3 bbls of dead crude containing 30 gal WAW5206 at 3.1 bpm, 700/800/150; LRS pumped 376 bbls crude at 3.4 bpm overflush, 750/900/150. `r ALCM I 4 2011 C�o • WNS CD2 -34 li Well Attributes _ Max Angle & MD TD 4 '.. .r w. Wellbore APUUWI Field Name ( Well Status Inc! (1 1MD (ftKB) Act Bbn 011103) 4r;x+ Ua,,,„,liw #s' 501032039300 ALPINE PROD 92 40 7,936.81 6755.0 Comment 92S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date SSSV_ I 'Annotation WO 43.11 1/1/2002 , ,.., VyG,c_pii(;g,_,,,Ch234 J/30/2p11 11 952 PM -- Annotation Depth (ftKB) End Date Annotation Last Mod .. End Date Last Tag' _ 1 Rev Reason FORMAT UPDATE Imosbor 4/30/2011 Casing Strings HANGER, 32 1 y i Casing Description String 0... ''String ID ... Top (kKB) Set Depth (f... Set Depth (TVD) .. String Wt.. String . 'String Top Thrd <_ - CONDUCTOR 16 15.062 36.6 96.0 96.0 62.58 1 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (i... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING PUP, SURFACE 95/8 8.921 366 2,368.8 2,364.5 36.00 J - 55 BTC 34 1 Y Casing Description String 0... String ID ... Top (ftKB) Set Depth (8... Set Depth (TVD) .. String Wt... String ... String Top Thnd t PRODUCTION i 7 6.151 352 7,801.8 7,202.4 26.00 L-80 BTCM Casing Description 'String 0... String ID ... Top (kKB) Set Depth (8... Set Depth (TVD) .. String Wt... String ... String Top Thrd OPEN HOLE 6 1/8 6.125 7,802 0 8,755.0 Tubing Strings Tubing Description String 0... Str ng ID . Top (kKB) Sat Depth (1... Set Depth (TVD) .. String Wt... String ... String Top Thrd '�. TUBING 45x3.5' 31/2 I 2.992 I 323 rat � 7,1924 9.30 L-80 8RD-MOD Details Top Depth (TVD) Top Intl TUBING, 36 `___ Top( ft(B) (�) (1 Item Description Comment ID (Id CONDUCTOR, _ 32.3 32.3 -1.04 HANGER FMC TUBING HANGER 3.958 37 - 96 123.0 123.0 0.28 XO CROSSOVER 4.5 x 3.5" 3.958 REDUCING REDUCI i 1,9883 1,984.1 1.93 SAFETY VLV CAMCO TRM-4E SAFETY VALVE (LOCKED OUT) 2.812 123 7,282.3 7,053.3 55.97 SLEEVE -C BAKER CMPA w/ BX - Closed 1/16/02 - SS (UP to dose w/ 3.5" shift 2.813 tool) 7,327.9 7,078.6 56.66 PACKER BAKER SAB-3 PACKER 3.000 SAFETY 1688 7,4oz s 7,120.1 63.77 NIPPLE HES XN NIPPLE 2.750 SAFETY 7 , 63 8 3 7,1921 81 44 WLEG BAKER WIRELINE ENTRY GUIDE 2.992 1,,9 M 18 f � Other In Hole (Wireline retrievable plugs, valves pumps, fish etc.j Top Depth (TVD) Top Ind Topgt(B) (KM (1 Description Comment Run Date ID(in) f' 1,988.3 1,984.1 1.93 WRDP 2.81 WRDP -1 (HWS -648) 3262o 1.094 Notes: General & Safety ! End Date Annotation 22/2011 NOTE: View Schematic w/ Alaska Schematic9.0 SURFACE, 37 -2,369 Ma GAS LIFT, 3,391 GAS LIFT, it 5,701 GAS LIFT,_ 7,203 SLEEVE -C, _ 7,282 lit PAG(ER, 7,328 NIPPLE, 7407 , ..._ _.. Mandrel Details Top Depth Top Port — -- F. _ - -- (ND) Inc! OD Valve Latch Size TRO Run Stn To81988) (kKB) (1 Make Model (in) Soon Type Type (in) (Psi) Run Date Co m... 6 1 3,390.6 3,386.2 0.97 CAMCO KBUG -M 1 GAS LIFT GLV BK -5 0.188 1,765.0 1/172002 WLEG, 7,638 -- 2 5,701.1 5,688.7 15.08 CAMCO KBUG -M 1 GAS LIFT GLV BK -5 0.188 1,748.0 1/17/2002 3 7,202.8 7,002.6 46.88 CAMCO KBUG -M 1 GAS LIFT OV BK -5 0.188 0.0 1/17/2002 PRODUCTION, 35.7,802\ - OPEN HOLE, 7,802- 8,755N TD (CD2 -36), 8,755 '~~~® STATE OF ALASKA ~~ ~~ 2 ~ 200 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT10191~a ~~- ~ Gas cons. crtmnvcc3~r~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^~ Other nChO arse Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 201-191 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20393-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 33' CD2-34 8. Property Designation: 10. Field/Pool(s): ADL 380075 Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 8755' feet true vertical 7210' , feet Plugs (measured) Effective Depth measured 8755' feet Junk (measured) true vertical 7210' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 104' 16" 104' 104' SURFACE 2369' 9-5/8" 2369' 2365' PRODUCTION 7802' 7" 7802' 7202` -~ ._. _,._, .. OPEN HOLE 953' 5-1/2" 8755' 7210' Perforation depth: Measured depth: open hole completion 7802'-8755' true vertical de the 7202'-7210' p ~''~°'~a~,~~a"t .~f. ~vi /.`~`'~~ f~; ~~ ~~~~~,; ~r4.~~~ r Tubing (size, grade, and measured depth) 4.5" x 3.5", L-80, 126' / 7639' MD. Packers &SSSV (type & measured depth) Baker SAB-3 pkr @ 732a' Camco SSSV @ 1988' 12. Stimulation or cement squeeze summary: Intervals treated (measured) pumped 269 bbls, refer to attachment Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1575 2303 193 -- 256 Subsequent to operation 1684 2528 207 -- 252 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: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Tim Schneider @ 265-6859 Printed Name Tim Sc Heider Title Alpine Staff Engineer U Z Signature ~~ A/, Phone: 265-6859 Date / ~ 7 ® f ~L-- ti~1,~1:~ Pr ared b Sharon Allsu Drake 263-4612 Form 10-404 Revised 04/2006 t~. 1 - ~" ~~~ ~ ~ ~~~~ Submit Ori in I Only /~z`Z/ ConocoPhillips Alask~l, ilnc: ALPINE CD2-34 CD2-34 API: 501032039300 Well T e: PROD An le TS: de SSSV Type: TRDP Orig Com letion: 1/1/2002 Angle @ TD: 90 deg @ 8755 Annular Fluid: Last W/O: Rev Reason: Format U date Reference L Ref L Date: Last U date: 11/25/2003 TUBING Last Ta TD: 8755 ftK6 (126-7639, OD:3.500, Last Tag Date: Max Hole Angle: 92 deg @ 7937 ID2.992) Casin Strin -ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 96 96 62.58 H-40 WELDED SURFACE 9.625 0 2369 2365 36.00 J-55 BTC PRODUCTION 7.000 0 7802 7201 26.00 L-80 BTCM OPEN HOLE 6.125 7802 8755 8755 0.00 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread RODUCTION 4.500 0 126 126 12.60 L-80 8rd (0-7802, 1 3.500 126 7639 7192 9.60 L-80 IBTM OD:7.000, ~ ~ I Gas Lift MandrelsNalves Wt:26.00) St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3390 3386 CAMCO KBUG-M GLV 1.0 BK-5 0.188 1765 1/17/2002 2 5701 5689 CAMCO KBUG-M GLV 1.0 BK-5 0.188 1748 1/17/2002 3 7203 7003 CAMCO KBUG-M OV 1.0 BK-5 0.188 0 1!17/2002 Gas ~ Other lu s, a ui ., etc. -JEWELRY MandrelNalve De th TVD T e Descri lion ID 2 (57015702, 126 126 XO 3.500 OD:5.390) 1988 1984 SSSV CAMCO TRM-4E 2.812 7282 7053 SLEEVE-C BAKER CMPA w/BX -Closed 1/16/02 - SS UP to close w/3.5" B shift tool 2.813 7328 7079 PKR BAKER SAB-3 PACKER 3.000 7408 7120 NIP HES'XN' NIPPLE 2.750 ft 7639 7192 WLEG 2.992 Gas Li MandrelNalve 3 (7203-7204, OD:5.390) 1 . SLEEVE-C pzaz-283, OD:5.320) PKR (7328-7329, OD:5.957) NIP (7408-7409 OD:3.500) = I ' : OPEN HOLE (7802$755, OD:6.125) ~ ~ , ~ ' WSR -Well Service Report Well Service Report Page 1 of 1 Well Job Scope CP~,I Rep CD2-34 Scale Inhibition Barreda, Brian Date Daily tiVork Unit Number 4/14/2009 32 Initial & T/IA/OA Start - 900/900/550 Final End - VAC/875/340 Field: ALPINE Pressures: Pump a h brid scale squeeze into well. Starting tubing pressure 900psig decreasin 2~ hr. Summary to VAC when job finished. Pumpe a total of 269 bbls crude 30 bbls of MEG. See detailed report for breakdown of stages and chems. STA.RTTIM..E O.PERAT.ION Pressure test and pump stage 1. Pump 69 bbls crude/WAW5206 starting at 900 psig. 07:55 PM 5.2bpm and ending with well on vac. Pump stages 2, 3, and 4 as follows: pre-flush 7bbls of crude/WAW5206 at 5.2bpm 08:07 PM and 450psig, go to MEG/3001 scale inhibitor stage and pump 35bbls at Sbpm and 5`. psig, then post-flush with 7bbls at Sbpm and 500 psig. Well on vac at end of stage. Over displace the well with 186bb1s of crude at 4 bpm and 450-SOOpsig. Shut down, 08:22 PM well on vac. Rig out equipment. Fluid Type To WeIl From Well Non- recoverable Note COMPLETION 30 MEG FLUID HOT OIL 269 http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=0C7D3 B7... 4/22/2009 Alpine Scale Squeezes • Maunder, Thomas E (DOA) • Page 1 of 2 From: Maunder, Thomas E (DOA) Sent: Monday, September 15, 2008 10:26 AM To: 'Schneider, Tim S.' Cc: Haas, Jeanne L; Kemner, Maria R Subject: RE: Alpine Scale Squeezes Tim, et al, It is acceptable to perform these operations without submitting a sundry. Be sure that the work is documented by submitting a 404 with appropriate attachments. Call or message with any questions. Tom Maunder, PE AOGCC From: Schneider, Tim S. [mailto:Tim.S.Schneider@conocophillips.com] Sent: Monday, September 15, 2008 9:54 AM To: Maunder, Thomas E (DOA) Cc: Haas, Jeanne L; Kemner, Maria R Subject: RE: Alpine Scale Squeezes Tom, Per our conversation, here is our preliminary list of 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) ~9.~~~~ SEr ~ ~ 20~~ We'll incorporate in our plans to submit 10-404's to provide AOGCC with a summary of the treatments: Thanks Tim From: Schneider, Tim S. Sent: Monday, September 15, 2008 9:26 AM To: 'Maunder, Thomas E (DOA)' Subject: RE: Alpine Scale Squeezes Tom, We will be treating the producers: Raugh volumes: Producers with watercut < 25% 60 bbl 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 9n si2aos Alpine Scale Squeezes • goal, but operationally this will be difficult. ~J For Producers with watercut > 25% we'll replace the MEG with seawater as well as the flush. Fage 2 of 2 We plan to perform ~5 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, etc.) The scale inhibitor designs are based on core work done in 2002-2004 to determine a scale inhibitor that would not damage the Alpine reservoir and we were able to identify a product (acrolyte vs. a phosphonate (used at GKA)) that doesn't damage the reservoir. Afield test has not been performed, but the scale inhibitor product is currently being used for surface scale management. Hope this helps explain our plans. Let me know if further information is needed. Thanks, Tim From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Monday, September 15, 2008 9:13 AM To: Schneider, Tim S. Subject: RE: Alpine Scale Squeezes Tim, Can you give me an idea of the number of 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 5. Schneider Subsurtace Development Staff Production Engineer WNS- Alpine 'J~ Phone: 907-265-6859 a" Fax: 907-2b56472 4w Mobile: 907-632-8136 r_I--' Email: tim.s.schneider@conocophillips.com 9/15/2008 S wECC cac rRANSn~rirrac ,~. ProActive Diagnostic Services, Inc. To: State of Alaska - AOGCC Chris~ne Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 c~~1~~~® stP ~ ~ 2~~$ RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing lnspectian(Caliper/ MTT~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal fetter to the following ProActinre Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Ir-ternational Airport Road Suite C Anchorage, AK 99518 Fa~c (907] 245-8952 1) Depth Correlation 24-Aug-OS CD2~4 E~ 2) Depth Correlation 24 Aug-08 CD2-29 EDIT i c~~`c7(~- ~-1 Comb ~~ol'1°t < ~ <<0~6~ ®~ ~----- Signed Print Name: 50-103-20393-00 50.103-20435.70 ~~~ a. ~ _. .; , ~; '1~)J~ Date ~-_`~'~ hs,t~' PROACTIVE DwGNOSTIC SERVICES, INC., 130 W. INTERNanoNAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8957 Fax: (907)2458952 E-INAI~: pdsanchorageCa)memorvlog.com WEe51TE:www.memorV9og.com C:\Documents and Settings)Owner\Deskbop\Transmit_C~toco.~c e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche'CvrPgs _ Inserts\Mìcrofilm _ Marker.doc ) h~ ~ èJ ~ 'f DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 Permitto Drill 2011910 Well Name/No. COLVILLE RIV UNIT CD2-34 Operator CONOCOPHILLIPS ALASKA INC AP~ eO~~-1 ~-:o~o~ I MD 8755 ~ 1-01L Current Status 1-01L UIC N ---------------------------- ------ - ------------------------------------------------------------------ ----- ~ Completion Date 1/1/2002 -- 1VD 7210 Completion Status ---------- --- - ---------------------- -------------------- ----------------------------- ---------- ------------------ REQUIRED INFORMATION Mud Log No Samples No ------------------------------------------------------ _-__n...- - - _____n_- --- ----------- ---- --- --- ----------------- ----------------- ----- ---- ---------- ---- -------- --------------- --------------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Directional Survey No ----------------------------- ------------ (data taken from Logs Portion of Master Well Data Maint) ( Log/ Electr Data Digital Dataset Type Med/Frmt Number Name C '1Í246L1$Verification Log Log Run Interval Scale Media No Start Stop 1 2300 7457 1 2300 7457 1 2300 6700 1 2300 6700 -------------------- -- - - -- -------- /11245 LlSVerificåtiô,1- (/(1., US Vëtification pt (E~C 'tfpt - - - - - - -- LIS.Verificätion' ------------------ ------------- ---------------------------- ---- Well Cores/Samples Information: OH/ CH Received Comments Case 10/28/2002 PB1 Case 10/28/2002 PB1 Case 1 0/28/2002 Case 1 0/28/2002 -----------------------'----------------------- - --- Name Interval Start Stop Received Sample Set Number Comments Sent ADDITIONAL INFORMATION Well Cored? Y /€) Daily History Received? Q/N WN '-- Chips Received? Y/N Formation Tops Analysis Received? ~ ---- ----- -------- - - --- - -- -- -- -------- -- ---- ---- --- ---- ---- - --- --- ------ --- - --- ------------ -- --- - - -- --- --- -- --- ---- - ------ ---- ------ ---- ---- - ------ - - -- ------ ( ~ - ------- ------------- ----------------------------- Comments: ~:~~~:~~:::=~~:~:::~:~~~~ --- - - --~:-:~~~--~~~=----~= .--- ------------------ --- --------------- --- --- - ----- - - -- - ----- - -- ---- -- -- - ------ ------ ---- -- - - -, -- - ---- ---- -- ,-- , ---------'-~-~te~--~"Kì~;]~¥--~~-----'-- Alpine cement lap HII ( 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> ,',' !j ~ 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 individual404'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 AIJI/lt: \.It:IIIt:/lt I UJ -iII " ~ ( ( k Name: AOGCC ALPINE cement top outs 04-16-03.xls ~AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 -."--'-".'-'---'..""'---'.-........,....-....,-...."......,--..,---.--,,--,,-,,--""------""'--"'-""""----'..-.'-'-..---..'-.,..,-..-....",......----.......,...-.........--.,.,.....-.,-..--...,-"--".'-""'--"---.--'-'---.-'---""'.'.'.-.--.---".-"--.""----"--..--'.....-.-.....--..,-,-..---.-.---.. ¡o------- Name: Cement Top Fill AOGCC Letter 04-23-03.doc Dcement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of2 4/24/2003 7:55 AM ( Con ocÓPh ill i pS Alaska " )' \ P.o. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih 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, CD 1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16tl\ 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 l \ { ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WEllS DEPTH VOLUME TYPE SACKS ,,- -------- ------_._-t------- ------- ------ i BBlS Cement ¡ --'--- ---- - \ ~ ~.- () ~ Cq-~_C J?~-- _._~??~ 0. 3 ----~~---- -_._~~-- ;J\X)-\~) _Ç_D1~_?___--~- 9.6 f---~!..._-- 3.6 \~<;.-\-;)O , CD1-3 1_O' 1.4 MI __8.~- !dQO-\\. ~ C~1-~ 7.3_~1 1 -- P 6..0 \<1.t,- \à<6 1 _~D1-5 4' ___9.6 MI 3.6 : :;J::f)-O~~ CD1-6 10.4?' 1.4 -----Q~ 8.~- \ ~c;-ùt;L\ ': _~p'1-=1§__~4.~_~_~-~----- WI _!.~.:_1-_- id()D--\4Ç ~'p1-,!!___~.:7?_: 1.2 P 7.2 d 0\- OG\o : --çp 1-~ -_-.!~----~--,_!~~--~-~L._- --_!~~--- \ <; ,,- )S :). _9 ~!.:~,~-- ---_!:~?~--_.. ____--9~~___- ----p--- -_--.1:_~--,- ,\<;C;-()<O~ ,: JOD... \ \0 -ÇQ1:~~----_J_?_:~-~__~__2.1___- MI___....___12.7 : \ ~~'-t» c.. CD1-24 -- ---- 2' -- O:..~------_..f_--- -- 1.8 d\::þ--t$:)"ÿ; ,~, ~~1:?'~f-_?~6~' 0.8 - P r- 4.8 dOr:r-~ ~ ,__9_1?_1- 21_- ---_J_?_ß?~-_._.._--,----_? :~-- t------_£'._----- r--_1_? 7__- ,d aC)- \ ~ ~ -çp ~~~-- ---§_:Z_~~------ -- 1 P'---_._-_._----~:g-- \ ~ ~ - \ at-{ -çJ?1-=~~--'f---'~:.~.?'---'- ---__--__.1:?__.._---_!:_--,..--- --------_?:_~---- , J.ûQ::.Þ. ~3 l ~ ~ - \ \ ) g ~ t~~~- ~ ~-~Î~: --~~ --~--_._--,;-~~------ -_~=~..~I_._____.._--- ~~ : ;-- ,JC:J;).-: oo~~ -' --gp~..:~,~---- ------~:_?:,----,--- ---_._g.:?_-----_.._----------,~---,_.._---, -------_..~.:9._----_.. \~ ~- \ \ <; ~.Q__1-4_?_- ---~~~~-~------ ____2~_.- ~_.JYl!_------, ------_._!.~._-- .d'Ch1..,,':.~,'-\.~ " CD2-16 11.66' 1.6 INJ 9.7 i d C)) -cJ \ ~ -----ë~2 -1-=' -- .=_1_~:_~~~=, ==~:? 5---"~- Œfj-- --- - 1_§~'-1 -~ . ;) ~.d- \ \ d .- CO2 :~~- -_J_!:?~:__._- -_.__J_:~.._--- ~._-~--_..._-_._-_....__~.:L_- J~-~~) __gD~-2~____..n1~:~~__----- ___1~?___- _._!,~~-----_JQ~- dO d ~} \-\ ;___~D 2 - ?§-- t---_._,~Z~2 5' --- --- 3 .J_-- ---_._.£_,---- f---_? 2 ~---- ;) D \ -£) ~ #-__,__9..12 2 -_?~-- ---~Q:_~~--______1.:~__,_~_-1~~---,--- --------~:.~-- JQ -t> ~'\ --~g_?:.~L______-,._--~-~-~~----_._- -------_!.:?._---- -_!~~-------------~.:?- - :}-() \ - \ ") ~ --_c¿Q~ -3.9 -: --------_Z~._,,----- --____._1______- ----,--_.£>._----- -~,~--- :~~~ J ()~\'J:.lo. - g~~::!-= =1f~~~ +=iJ -- ---it= ðCfd~\()~ -~~~~.Þ.?-~~~-----~ ~=~~~fQ:~~?'~.~..:.~_: :_-:._~-~:J~4_~~~~:_~--,~=-==(~~=~~~~--: -~=~:,~:~~.~~=::-~=-' :;)0 \ -- d\~ CD2-49 9.331 1.3 INJ 7.8 : d- D d"\J~ ----CÕ2~50-- ----{6'6'-'."'._- ."-----Ö~-2-5--------------p-._------- -----no.--rS---. .." d-O\~ \:}'-\ db\ -\ ð 5 Annular Disposal during the first quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-18 31501 100 0 31601 306 0 31907 January March 3S-15, 3S-16, 3S-22, 3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Oec 2002 Jan 2003 3S-10, 35-15, 3S-09, 3S-14 CD2-48 20144 100 0 20244 375 11381 32000 Dee 2002 Feb 2003 CO2-45, CO2-35, CO2-08, CO2-28 CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CO2-08, CO2-48, CO2-46 CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CO2-08, CO2-36, CO2-51 2003 3S-10 21104 100 0 21204 388 0 21592 March March 3S-21, 3S-08 2003 2003 lC-22 26944 100 0 27044 0 0 27044 March March IC-I90,IC-I74 2003 2003 Puviaq #1 4616 100 0 4716 15 0 4731 March March Puviaq I 2003 2003 ]'¡ l\f¡l h. hD. LA h . E . dd . 2003 h fi. A l"fi ota 0 urnes lnto nnu l or W lC lsposa ut OTlzatlon xplre urzng t e lrst quarter . . Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P-427, Heavenly CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Oec 2002 CO2-I3, CO2-37, CO2- 2002 35 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October CO2-38, CO2-44, CO2- 2002 2002 29, CO2-13 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CO2-50, CO2-46, CO2- 22 C ECEIVED APR 1 6 2003 ( .. -I \ Qy- 0 -- \ --. Alaska Oil & Gas Cons. Conmission ~ Anchorage (- ~f Randy Thomas ¿)OJ - /g I Greater Kuparuk Team Leader Drilling & Wells Co no cÓPh ¡IIi ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RL Thomas @ ppco.com January 10, 2003 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal, Fourth Quarter, 2002 Dear Commissioner: Please find attached the fourth quarter 2002 annular disposal for the Kuparuk, Alpine and Cook Inlet Fields. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2002, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2002. Please call me at 265-6830 should you have any questions. Sincerely, \-.~ ' \~ R. Thomas Greater Kuparuk Team Leader RT/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental B. Morrison / R. Overstreet Sharon Allsup-Drake Well Files RECEIVED \ ^ N 1 ¡:~ L"OO~~ f,J, I ,) , '_,'1 " Alaska OU & Gas, Cons. Commission Ancl1orapf: A l D. ld . h fi h 12002 nnu ar lsposa urzng t e ourt quarter 0 . . h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-26 15244 100 0 15344 380 13902 29626 September October CD2-38, CD2-44, CD2-29, 2002 2002 CD2-13 CD2-34 22895 100 0 22995 372 0 23367 Oct 2002 Dee 2002 CD2-13, CD2-37, CD2-35 CD2-48 11281 100 0 11381 375 0 11756 Dee 2002 Dee 2002 CD2-28, CD2-45 3S-07 18155 100 0 18255 216 0 18471 Dee 2002 Dee 2002 35-09,35-14,35-10 3S-18 206 100 0 306 0 0 306 Dee 2002 Dee 2002 35-18 ( ( ) Total Volumes into Annulifor which Disposal Authorization Expired during thefourth (, uarter 2002: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volome Volume Volume Status of Annulus CD2-39 29466 100 0 379 29945 Open, Freeze Protected October Sept 2002 CD2-15, CD2-47, CD2~ 2001 44 CD2-14 30597 100 0 376 31073 Open, Freeze Protected November March CD2-45, CD2-47, CD2- 2001 2002 32, lC-14 32115 100 0 0 32215 Open, Freeze Protected October January lC-109, lR-36, lC-24 2001 . 2002 2P-438 30331 100 0 212 30643 Open, Freeze Protected October December 2P-420, 2P-415, 2P-429 2001 2001 CD2-15 31181 100 0 371 31652 Open, Freeze Protected March 2002 September CD2-50, CD2-25, CD2- 2002 44 CD2-47 26874 100 0 375 27349 Open, Freeze Protected December January CD2-34, CD2-26 2001 2002 CD2-45 22514 100 0 377 22991 Open, Freeze Protected January February CD2-49, CD2-17 2002 2002 C kll A l D. ld . h fi h 2002 00 net nnu ar lsposa urzn~ t e ourt quarter . . h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 472 100 0 572 0 67224 67796 January October Hansen # 1 2002 2002 ( ~ ¿;)OJ-¡9¡ 1/;)tf5 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tl1 Avenue, Suite 100 Anchorage, Alaska 99501-3539 May 15, 2002 RE: MWD Formation Evaluation Logs - CD2-34, AK-MM-11207 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20393-00. ~,~\ Æ.""'" .¡iI" !t"""'~-\I"ì=:"'" I.""', W"~ t;"""" '1 ,~,..."-" - - I ~ ...\~ ~ \. ~ \..t I,', I' q I,~ ,1:;IlJOI¡O ""=,~ rIC""'- 1"'-" 1'.\-- '_~- ~- --"-- -'--' \oN I " ,¡" , " I ~~'"(,;, I:',;"v;;. ß >~~o /'\/" , ~,'-.."....'-'¡.~ ,:',..""."..' . '~j¡;.H¡i&í~.It!.V\ 4' - ¡¡;~._. :'-'i'Y- \,..,f.,""~'}_:I- "'~ . ."., -.,~, <";" : I( ,II \, c:;1 O/-/CJ/ I IdY~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 May 15, 2002 RE: MWD Formation Evaluation Logs - CD2-34 PBl, AK-MM-11207 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AI< 99518 1 LDWG formatted CD Rom with verification listing. , API#: 50-103-20393-70. f~ECEfVE() OCT f: 8 2001,: 1~"(~"'¿14J ,'"v t" -0'. "ìl'-';:-1ft.... '\.11. ,i bZ:'i;; ~.~tFh' /j"'¡'(".'i~- '. " ""v'.' V'i,1hIG6"""Wi\I,n 1~1H7h1~~n~~ (" I f PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 March 22, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-34 and CD2-34PB1 (201-191) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-34 and the plugback operations on CD2-34PB 1. If you have any questions regarding this matter, please contact me at 265-6120 or Vern Johnson at 265-6081. Sincerely, ÂA- e.. {ß(. G. C. Alvord Alpine Drilling Team Leader PAl Drilling GCA/ skad r :' ,., .. \ ,'", -,'" :" ' .:::,_:,.,.' :-'" - ,-I , " , .'- .,' ' "'~'\: :f",,\ H (""'1' ~ ~~,'¡ ,'i\\ 'L' ß:.¡'li~",_":¡1\1'4' ~:- 1!~"4 :1:__li)b_H'\~r\ I- "...,ill\¡'\'~-~\\c (' STATE OF ALASKA (, ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas D Suspended D Abandoned D Service D 2. Name of Operator .. -.'" 7. Permit Number Phillips Alaska, Inc. V!i!~tfD 201-191 1 3. Address Z'J---~'- '\ 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 ß.H~ i- '- 50-1 03-20393-00 1 50-1 03-20393-70 4. location of well at surface ;~'~:-- 9. Unit or lease Name 1905'FNL, 1522'FEL,Sec.2,T11N,R4E, UM (ASP: 371716,5974453) Colville River Unit At Top Producing Interval ; ~¿'.~C?_~ ," 10. Well Number 2403'FNL,461'FEL,Sec.2,T11N,R4E, UM (ASP: 372769, 5973937) CD2-34 & CD2-34PB 1 t~~;-~. At Total Depth " -. -' 11. Field and Pool . , 1842' FSL, 153' FWL, Sec. 1, T11N, R4E, UM (ASP: 373367, 5972891) \'~""~""->"""-:':::::',,:' Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. lease Designation and Serial No. Alpine Oil Pool RKB 33' feet ADL 380075 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions December 17, 2001 December 30, 2001 January 1 ,2002 NIA feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8755' MD / 7210' TVD 8755' MD 1 7210' TVD YES 0 No D 1988' feetMD 1600' MD 22. Type Electric or Other logs Run G R/Res/Neut/Dens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PUllED 16" 62.5# H-40 Surface 104' 42" 580 sx AS 1 9.625" 36# J-55 Surface 2369' 12.25" 333 sx AS III Lite, 242 sx Class G 7" 26# L-80 Surface 7802' 8.5" 158 sx Class G CD2-34 PB 1 cement plug dressed off to 6700' to start CD2-34 sidetrack 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 126' 7328' 3.5" 7640' open hole completion from 7802' - 8755' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7562' - 7053' Plug #1: 216 sx Class G 7053' - 6644' Plug #2: 200 ws Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 25, 2002 ' Flowing Date of Test Hours Tested Production for Oll-BBl GAS-MCF WATER-BBl CHOKE SIZE GAS-Oil RATIO 3/1/2002 12 hours Test Period> 1569 2235 25 100% 1767 Flow Tubing Casing Pressure Calculated Oll-BBl GAS-MCF W A TER-BBl Oil GRAVITY - API (corr) press. 299 psi 1630 psi 24-Hour Rate> 2791 4931 49 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ", -, N/A I'", " ,:"', ,', ,,'..' , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate RBDMS BFL \j\"- MAR ? 7 2002 29. ~. GEOLOGIC MARKERS 30. ( .0 FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase- NAME CD2-34 Top Alpine D Top Alpine C Base Alpine 7492' 7545' 8755' 7154' 7171' 7210' CD2-34 PB1 Top Alpine D Top Alpine C Base Alpine 7332' 7350' 7441' 7154' 7170' 7251' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 Signed A~ L O!.. Chip Alvord Title Aloine Drillina Team Leader Date -~/LL (L'L- Prepared by Sharon Allsup-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 (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ( 'Í' ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-34 Common Well Name: CD2-34 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 12/16/2001 07:00 - 08:30 1.50 MOVE DMOB MOVE 08:30 - 16:30 8.00 MOVE RURD MOVE 16:30 -18:00 1.50 DRILL RIRD SURFAC 18:00 -19:00 1.00 DRILL RIRD SURFAC 19:00 - 00:00 5.00 DRILL OTHR SURFAC 12/17/2001 00:00 - 15:30 15.50 DRILL OTHR SURFAC 12/18/2001 12/19/2001 15:30 - 18:30 3.00 DRILL OTHR SURFAC 18:30 - 20:00 1.50 DRILL PULD SURFAC 20:00 - 21 :00 1.00 DRILL DRLG SURFAC 21 :00 - 00:00 3.00 DRILL PULD SURFAC 00:00 - 12:00 12.00 DRILL DRLG SURFAC 12:00 - 18:45 6.75 DRILL DRLG SURFAC 18:45 - 19:45 1.00 DRILL CIRC SURFAC 19:45 - 21:30 1.75 DRILL WIPR SURFAC 21 :30 - 22:30 1.00 DRILL CIRC SURFAC 22:30 - 00:00 1.50 DRILL TRIP SURFAC 00:00 - 01 :00 1.00 DRILL TRIP SURFAC 01 :00 - 02:30 1.50 DRILL PULD SURFAC 02:30 - 04:00 1.50 CASE RURD SURFAC 04:00 - 04:30 0.50 CASE SFTY SURFAC 04:30 - 09:30 5.00 CASE RUNC SURFAC 09:30 - 10:20 10:20 - 11 :45 0.83 CEMEN PULD SURFAC 1.42 CEMEN CIRC SURFAC 11 :45 - 12:45 1.00 CEMEN PUMP SURFAC Page 1 of 8 Spud Date: 12/13/2001 End: 1/1/2002 Group: Start: 12/11/2001 Rig Release: 1/1/2002 Rig Number: 19 Description of Operations Blow down water & steam lines - unhook ele ctrical - prep to move Move pit mod, skid floor, open cellar doors - move to rig - spot sub on CD2-34 , Move & center rig over well, skid floor - spot motor s & pits, & ball mill Rig up 20" diverter system - Accept rig @ 1 6:30 hrs. 12/16/2001 Rigging up Take on water & clean pits fl OMB usage on CD2-47 Clean & flush MOBM residue f/ pits, lines, h oses, ditches, troughs, & rig - Adjust servi ce loop, service top drive air fittings & hose s while cleaning Perform diverter closure t est - Witnessing of test waived by John Cris p AOGCC Take on spud mud - P/U & stand back 8" dc' s - Held Pre-spud meeting wi crew P/U bit, bit sub 1 std HWDP - fill stack & ch eck for leaks - Pressure test mud lines to 3 500 psi - C/O conductor f/ 60' to 104' Spud in & drill 121/4" hole fl 104' to 185' w I HWDP - Pullout & std back HWDP - LID bi t & bit sub MU BHA # 1 Drill from 185' to 1840'. ART=5.2 AST=2.4 Ran Gyro surveys to 366'. Drill from 1840' to 2375'. ART=5.7 AST=0.1 Pump 40 bbl 300 fv sweep and circ hole clea n, flow check, static. Blow down Top Drive, wipe hole to 1275' 15- 40k over, RIH. Pump 40 bbls 300 fv sweep and circ hole cle an, flow check, static. POH, 362' @ midnight, max overpull 10k. POH, stand back HWDP and 8" collars. LD MWD, XC's, stab, bit and motor. Rig up slips, elevators, tongs, change out t 0 long bails to run 9-5/8" casing. Held prejob safety and operations meeting. Ran 55 joints of 9-5/8",36#, J-55, BTC. MU hanger and landing joint, landed casing with shoe @ 2369', FC @ 2282'. LD fill up tool, MU cement head. Staged pumps up to 8 bpm, 340 psi. Circ an d cond mud, reciprocated casing 25', full ret urns throughout. PJSM. Pumped 40 bbls of Biozan spacer with nutpl ug marker, test cement lines to 2500 psi. Pu mped 50 bbls of 10.5 ppg ARCO Spacer, 260 bbls of 10.7 ppg lead and 50 bbls of 15.8 P pg tail cement. Printed: 3/1/2002 9:41 :07 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( { PHilliPS ALASKA INC. Operations Summary Report CD2-34 CD2-34 ROT - DRILLING doyon1 @ppco.com Doyon 19 Date Sub From - To Hours Code Code Phase 12/19/2001 12:45 - 13:30 0.75 CEMEN DISP SURFAC 13:30 - 14:30 1.00 CASE RURD SURFAC 14:30 - 20:30 6.00 CASE NUND SURFAC 20:30 - 20:45 0.25 WELCT SFTY SURFAC 20:45 - 00:00 3.25 WELCT BOPE SURFAC 12/20/2001 00:00 - 01 :00 1.00 WELCT BOPE SURFAC 01 :00 - 05:00 4.00 DRILL PULD SURFAC 05:00 - 07:00 2.00 DRILL TRIP SURFAC 07:00 - 09:00 2.00 RIGMNT RSRV SURFAC 09:00 - 09:30 0.50 DRILL TRIP SURFAC 09:30 - 11 :00 1.50 CASE DEQT SURFAC 11 :00 - 12:30 1.50 CEMEN DSHO SURFAC 12:30 - 16:30 4.00 RIGMNT RGRP SURFAC 16:30 - 17:00 0.50 CEMEN DSHO SURFAC 17:00 - 17:30 0.50 CEMEN LOT SURFAC 17:30 - 18:30 1.00 CEMEN LOT SURFAC 18:30 - 00:00 5.50 DRILL DRLG INTRM1 12/21/2001 00:00 - 12:30 12:30 - 13:15 12.50 DRILL 0.75 DRILL DRLG INTRM1 CIRC INTRM1 13:15 - 13:30 0.25 DRILL OBSV INTRM1 13:30 - 16:00 2.50 DRILL WIPR INTRM1 16:00 -16:30 0.50 DRILL CIRC INTRM1 16:30 - 00:00 7.50 DRILL DRLG INTRM1 12/22/2001 00:00 - 23:45 23.75 DRILL DRLG INTRM1 23:45 - 00:00 0.25 DRILL CIRC INTRM1 12/2312001 00:00 - 01 :00 1.00 DRILL CIRC INTRM1 01:00-01:15 0.25 DRILL OBSV INTRM1 01 :15 - 03:30 2.25 DRILL TRIP INTRM1 Page 2 of 8 Spud Date: 12/13/2001 End: 1/1/2002 Group: Start: 12/11/2001 Rig Release: 1/1/2002 Rig Number: 19 Description of Operations Dispalced cement with 20 bbls FW and 158 b bls of mud at 8-10 bpm. Bumped plugs, float s held, annulus static, full returns during jo b with 97 bbls of 10.7 ppg cement returns to surface. CIP @ 1308 hrs, ETOC @ 2255'. Flush surface equipment, LD cement head a nd landing joint and running tools. ND Divertor system, NU wellhead and test m 1m seal to 1000 psi. NU BOP Stack. PJ SM. RU and test BOPE, 250/5000 psi, annular pr eventor 250/3500 psi. Test floor safety valves 250/5000 psi. Pull t est plug and install wear bushing. MU BHA #2, initialize LWD, load source. RIH to 1500', shallow test tools, blow down iTop Drive. Slip and cut drilling line, service Drawworks and Top Drive. RIH, wash down and tag cement @ 2250'. Blow down Top Drive. RU and test casing to 2500 psi for 30 min. Blow down lines. Drill out float collar @ 2382', clean out cern ent to 2342'. Repair oil leak on Top Drive Torque tube As sembly. Drill out cement and 20' of new hole to 2395 Circ hole clean prior to LOT. RU and perform LOT, established EMW of 15 .5 ppg. Blow down lines. Drill from 2395' to 3106', ART=3.5 AST=O. C hanged of to 9.4 ppg LSND mud while drillin g ahead from 2395'. Drill from 3106' to 4919'. ART= 8.5 AST= 0 Pumped 40 bbl 150 FV sweep and circ hole c lean. Moderate increase in cuttings return w ith sweep. Monitor well, static, blow down Top Drive Wipe hole to shoe 10-20K over. Monitor well , static, RIH to 4828', no problems. Precautionary wash and ream from 4828' to 4919' . Drill from 4919' to 5587'. ART=2.9 AST= 2. 9 Drill from 5587' to 7562', pilot hole TO. ART = 12.4 AST= 4.9 Top of Alpine C @ 7350' md, base @ 7430' md. Pump 40 bbls 150 FV sweep and circ. Circ hole clean, minimal increase in cuttins with sweep back. Monitor well, static. Pump out to 7210', POH to 6255' 10-20k ove Printed: 3/1/2002 9:41 :07 AM ( ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-34 Common Well Name: CD2-34 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 12/23/2001 01 :15 - 03:30 2.25 DRILL TRIP INTRM1 03:30 - 04:00 0.50 DRILL CIRC INTRM1 04:00 - 09:30 5.50 DRILL TRIP INTRM1 09:30 - 10:30 1.00 DRILL TRIP INTRM1 1 0:30 - 12: 15 1.75 DRILL PULD INTRM1 12:15 - 14:00 1.75 ABAND TRIP INTRM1 14:00 - 17:00 3.00 ABAND TRIP INTRM1 17:00 - 18:30 1.50 ABAND CIRC INTRM1 18:30 - 20:00 1.50 CEMEN PLUG INTRM1 20:00 - 20:15 20:15 - 21:30 21 :30 - 22:45 0.25 CEMEN CIRC INTRM1 1.25 CEMEN PLUG INTRM1 1.25 ABAND CIRC INTRM1 22:45 - 00:00 1.25 ABAND TRIP INTRM1 12/24/2001 00:00 - 01 :00 1.00 ABAND TRIP ABANDN 01 :00 - 03:30 2.50 ABAND TRIP ABANDN 03:30 - 06:00 2.50 DRILL PULD INTRM1 06:00 - 07:30 1.50 DRILL TRIP INTRM1 07:30 - 09:00 1.50 RIGMNT RSRV INTRM1 09:00 - 11 :30 2.50 DRILL TRIP INTRM1 11 :30 - 12:30 1.00 DRILL REAM INTRM1 12:30 - 13:30 1.00 DRILL DRLG INTRM1 13:30 - 00:00 10.50 DRILL DRLG INTRM1 12/2512001 00:00 - 18:00 18:00 - 19:00 19:00 - 21:00 18.00 DRILL DRLG INTRM1 1.00 DRILL CIRC INTRM1 2.00 DRILL WIPR INTRM1 Page 3 of 8 Spud Date: 12/13/2001 End: 1/1/2002 Group: Start: 12/11/2001 Rig Release: 1/1/2002 Rig Number: 19 Description of Operations r. Pump dry job, blow down Top Drive. POH, wiped several tight spots from 6620' t 0 5686',10- 40k over. continue to POH, mon itor well at shoe, static. POH,stand back H WDP. PJSM. Remove source from LWD, download t 00 Is. LD BHA, clear tools from rig floor. RU and PU 30 joints of 3-1/2" tubing. RIH with tubing tail below 4" drill pipe to 75 62' . Circulate and condition mud at 14 bpm, 2000 psi, 40 rpm. PJSM. RU and test cement lines to 3000 psi. Plugg ed back 8 1/2" open hole from 7562' with 21 6 sxs of 15.8 ppg G cement, displaced to.eq ualization. CIP @ 1920 hrs. ETOC 7053' (wi 25% excess). Pulled up to 70?3'. Circ to clean pipe and move any excess cem ent up hole. RU and test cement lines to 3000 psi. Plug back 8 1/2" open hole from 7053' with 200 s xs of 17 ppg G cement, displace to equaliza tion. CIP @ 2100 hrs. ETOC @ 6644' (wi 25 % excess). Pulled up to 6644'. Circ and cond mud 10 bpm, 1100 psi. Dumpe d 60 bbls of cement contaminated mud. Moni tor well, static, pump dry job. POH, 2857' @ midnight. POH with 4" drill pipe. RU and LD 30 jts of 3 1/2" tubing, RD tongs. MU BHA #3, scribe tools, initialize MWD/LW D. RIH to 2020', shallow test tools, BDTD. Slip and cut drilling line, service Top Drive and Drawworks. RIH to 6255'. Wash and ream from 6255', tagged cement @ 6640'. Polish off cement plug from 6640' to 6700'. Control drill to side track off of plug @ 20 f ph from 6700' to 6740', drill from 6740' to 7 114'. ART= 3.2 AST= 5.0 Drill from 7114' to 7812' (7203' TVD). ART= 2.2 AST=10.6 Pump 40 bbls 180 FV sweep and circ clean, large increase in 1/2" to 1" sharp edged pei ces of shale back. Monitor well, static, pump out to 7368', pull ed to 6314'. Worked through tight hole from 6510' to 6490', 50k over. Printed: 3/1/2002 9:41 :07 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/25/2001 12/26/2001 12/27/2001 if '" ~, PHilliPS ALASKA INC. Operations Summary Report CD2-34 CD2-34 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub From - To Hours Code Code Phase 21 :00 - 23:00 23:00 - 00:00 00:00 - 03:00 2.00 DRILL WIPR INTRM1 1.00 DRILL CIRC INTRM1 3.00 DRILL CIRC INTRM1 03:00 - 05:45 2.75 DRILL TRIP INTRM1 05:45 - 06:15 0.50 DRILL CIRC INTRM1 06:15 - 09:45 3.50 DRILL TRIP INTRM1 09:45 . 12:00 2.25 DRILL PULD INTRM1 12:00 - 12:30 12:30 - 14:00 14:00.16:00 0.50 CASE NUND INTRM1 1.50 WELCT EaRP INTRM1 2.00 WELCT BOPE INTRM1 16:00.16:30 0.50 CASE RURD INTRM1 16:30 - 17:30 1.00 RIGMNT RGRP INTRM1 17:30 - 19:00 1.50 CASE RURD INTRM1 19:00 -19:15 0.25 CASE SFTY INTRM1 19:15-22:15 3.00 CASE RUNC INTRM1 22:15.22:35 0.33 CASE CIRC INTRM1 22:35 - 00:00 00:00 - 02:45 02:45 . 03:30 03:30 - 05:30 05:30 - 06:00 06:00 - 07:45 1.42 CASE 2.75 CASE 0.75 CASE RUNC INTRM1 RUNC INTRM1 CIRC INTRM1 2.00 CASE RUNC INTRM1 0.50 CASE CIRC INTRM1 1.75 CASE RUNC INTRM1 Page 4 of 8 Spud Date: 12/13/2001 End: 1/1/2002 Group: Start: 12/11/2001 Rig Release: 1/1/2002 Rig Number: 19 Description of Operations RIH pipe stopped @ 7288' (12 degree dogleg , 54 degrees Inc.). Wash and ream with slig ht effort from 7280' to 7460'. RIH to 7812'. Establish eire, re-survey @ 7750' & 7723'. P umped 40 bbls 170 FV sweep and condition mud, continued to see lots of 1/2" to 1" peic es of shale across shakers, increase mud wt . to 9.8 ppg. Circ and cond mud 550 gpm, 2950 psi, 40 rp m. Increased mud wt. to 10.2 ppg, pumped 4 0 bbls 190 FV sweep, minimal cuttings with sweep back. Pump out to 7335', POH slowly to 5903', no problems. Pump dry job, blow down Top Drive. POH, no problems,stand back hwdp. Monitor ed well at shoe and at HWDP, static. LD 3 flex collars, down load LWD, LD LWD, MWD, xo's, motor and bit. Cleared tools and cleaned rig floor. Flush stack and wellhead with wash sub. Changed top pipe rams to 7"1 changed Top D rive saver sub to 4-1/2 IF. Pull wear bushing, install test plug and 7" t est joint. Test pipe rams to 250/5000 psi. P ulled test joint and plug, install thin wear b ushing. RU to run casing. Replace failed high drum drive chain in Dra wworks transmission. RU fill up tool, PU long bails, RU slips, ele vators and tongs. Held safety and operations meeting with ere w. Ran 57 joints of 7",26#, N-80, BTCM to 233 5' . Stage pumps up to 8 bpm, 510 psi and circ 0 ne casing volume. PUW 130k SOW 125 k. Continue to run casing, 3676' @ midnight. Run casing to 5727'. Staged pumps up to 6.0 bpm initial pressure 680 psi. Reciprocate pipe PUW 200k SOW 1 83k, circ and cond mud, final pressure 570 psi. Run casing to 7185', no returns last 2 joints Reciprocate pipe PUW 275-300k SOW 175-20 Ok, pump at 1.5-3 bpm attempting to regain returns, no returns, lost 48 bbls of mud. Continue to run casing, MU LJ and hanger, I and casing with FS @ 7802', FC @ 7714'. LD fill-up tool and MU cement head. Printed: 3/1/2002 9:41:07 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/27/2001 \( ( Page 5 of 8 PHilliPS ALASKA INC. Operations Summary Report CD2-34 CD2-34 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub From - To Hours Code Code Phase 07:45 - 09:45 09:45 - 10:20 10:20 - 11 :30 11 :30 - 12:00 12:00 - 13:00 13:00 - 15:00 15:00 - 21 :30 2.00 CEMEN CI RC INTRM1 0.58 CEMEN PUMP INTRM1 1.17 CEMEN DISP INTRM1 0.50 CEMEN PULD INTRM1 1.00 CASE RURD INTRM1 2.00 CASE NUND INTRM1 6.50 WELCT BOPE INTRM1 21 :30 - 00:00 2.50 RIGMNT RGRP INTRM1 12/28/2001 00:00 - 01 :30 1.50 RIGMNT RGRP INTRM1 01 :30 - 02:00 0.50 WELCT BOPE INTRM1 02:00 - 05:00 3.00 RIGMNT RGRP INTRM1 05:00 - 08:00 3.00 DRILL PULD INTRM1 08:00 - 09:00 1.00 DRILL TRIP INTRM1 09:00 - 10:00 1.00 DRILL DEOT INTRM1 10:00 - 14:00 14:00 - 14:45 14:45 - 16:00 16:00 - 18:00 18:00 - 18:30 18:30 - 19:30 19:30 - 20:30 20:30 - 22:00 4.00 DRILL TRIP INTRM1 0.75 CEMEN COUT INTRM1 1.25 CASE DEOT INTRM1 2.00 CEMEN DSHO INTRM1 0.50 DRILL DRLG INTRM1 1.00 CEMEN CIRC INTRM1 1.00 CEMEN FIT INTRM1 1.50 DRILL CIRC PROD Spud Date: 12/13/2001 End: 1/1/2002 Group: Start: 12/11/2001 Rig Release: 1/1/2002 Rig Number: 19 Description of Operations Reciprocate casing 50' PUW 275k, SOW 200 k, pump with 2-4 bpm maximum pressure 420 psi. Pumped 40 bbls with 12.5 ppb LCM and continue to regain returns. Pumped second 40 bbls pill with12.5 ppb LCM, no returns e stablished. Line up to cementers and test lines to 3200 psi. Pumped 20 bbls of preflush, 50 bbls of 12.5 ppg spacer and 32 bbls of 15.8 tail ce ment. Displaced cement with 20 bbls of FW from c ementers, and 274 bbls of mud with rig pum ps at 5-6 bpm, had partial returns last 50 b bls of displacement, reciprocated pipe untill last 10 bbls. Bumped plugs, CIP @ 1120, fl oats held. Blow down lines and RD cement head. LD landing jnt, remove long bails, clear run ning tools from rig floor. Install and test packoff to 5000 psi. Change d top pipe rams to 3 1/2" X 6". Test pipe and blind rams, choke, kill and ma nifold valves, IBOP and floor safety valves t 0 250/5000 psi. Test annular preventor 2501 3500 psi. Pull test plug and install wear bus hing, blow down lines. Upper IBOP valve (au to) leaked. AOGCC ( Chuck Sheve) waived w itnessing test. Change out IBOP valve. Change out IBOP on Top Drive. RU and test IBOP to 250/5000 psi, blow dow n Ii n e s. Assembly spline ring, clamps and Actuator f or IBOP valve. MU BHA # 4, initialize tools. PU 30 joints of 4" drill pipe from shed. Fill pipe and shallow test tools. High pressu re test repair to standpipe. Blow down lines. RIH to 7611', filled pipe at 3315' and 5609'. Wash and ream from 7611', tagged cement @ tagged cement 2 7650', cleaned out to 77 05' . RU and test 7" casing to 3500 psi for 30 min . RD, blow down lines. Drill wiper plugs and cement in shoe track, clean out rathole to 7812'. Drill 20' of new hole to 7832'. Circ and cond mud for FIT. RU to Dowell test lines to 2000 psi. Perform FIT to 12.4 ppg EMW. Blow down lines. PJSM. Circ and change well over to 9.2 ppg Flo-pro mud. Printed: 3/1/2002 9:41 :07 AM ..... ..... ~~pHiLLìPS) ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/28/2001 12/29/2001 12/30/2001 ( ( PHilliPS ALASKA INC. Operations Summary Report CD2-34 CD2-34 ROT - DRILLING doyon1 @ppco.com Doyon 19 Page 6 of 8 Spud Date: 12/13/2001 End: 1/1/2002 Group: Start: 12/11/2001 Rig Release: 1/1/2002 Rig Number: 19 Description of Operations Sub From - To Hours Code Code Phase 22:00 - 00:00 00:00 - 18:00 18:00 - 19:30 19:30 - 20:30 20:30 - 00:00 00:00 - 02:30 02:30 - 04:00 04:00 - 06:00 06:00 - 12:00 12:00 - 14:30 14:30 - 16:00 16:00 - 19:30 2.00 DRILL 18.00 DRILL 1.50 DRILL DRLG PROD DRLH PROD OBSV PROD 1.00 DRILL OTHR PROD 3.50 DRILL OTHR PROD 2.50 DRILL OBSV PROD 1.50 DRILL DRLG PROD 2.00 DRILL OBSV PROD 6.00 DRILL OBSV PROD 2.50 DRILL OBSV PROD 1.50 DRILL OBSV PROD 3.50 DRILL OBSV PROD Drill from 7832' to 7930'. ART= 1.5 AST= 0 Drill from 7930' to 8669'. ART=9.5 AST=2.3 Lost all returns, reduce pump rate to 2 bpm, 450 psi, no returns. Monitor static fluid los ses while mixing LCM pill, 10 bph. Pumped 40 bbl pill with 35 ppb of MI seal ( med) displaced pill @ 3 bpm first 120 bbls 0 f displacement mud with 20 ppb of mix II co arse, slight returns until I pill out bit. Regai ned full returns 15 bbls around bit, drilled 1 l' to 8680' full returns. While orientating m otor to slide lost all returns again. Monitor annulus, no static losses. Continue to pump at 3 bpm, 720 psi adding 15 ppb Safe carb & Mix II course, slight ret urns. Mix and pump second 40 bbl pill with 35 ppb of MI Seal (med). Displaced @ 4 bpm ,840 psi with slight returns. After 15 bbls 0 ut the bit returns increased to 80% untill all the pill was around the bit then dropped to zero on the % flow indicator. Monitor annul us, 8 bph static losses. Mix third LCM pill. Total losses to midnite 528 bbls Mix and pump 40 bbl pill with 35 ppb Mix II f ine and safe carb coarse at 3.0 bpm 470 psi , drilled 5" of hole to 6885'. Regained 50% r eturns after pill out bit, increased rate to 4 bpm, monitor returns, maintained 60% return s. Drilled from 6885' to 8755', with 60% return s, pumped 40 bbl pill with 35 ppb LCM. Shut down pumps, monitor static losses, initial 8- 10 bpm increased to >200 bph. Fill hole down annulus, mix and pump 40 bbl pill with 35 ppb LCM, maitained 20 ppb LC M in displacement fluids, no returns. Pulled to 8564', losses continued at 180 bph Pumped 35 bbl pill with 40 ppb IMG-400, n 0 improvement. Mix and pumped 33 bbls For m-A-Set pill, squezed pill with 2.5 bpm 500- 720 psi. Monitor well, losses continued +1- 190 bph. Maintain hole full pumping down annulus, re duced mud wt. to 9.0 ppg. Mix and pump 280 bbls with 50 ppb safecarb finelmed, monito red static losses 138 bph. Mix and pump 140 bbls with 25 ppb MI seal f ine, displaced at 3 bpm 530 psi, gained part ial returns back. Monitor static losses +1- 8 0 bph. Lower fluid wt. to 8.9 ppg. Mix and pump 140 bbls with 25 ppb MI seal f ine at 3 bpm 690 psi, monitor static losses 60-90 bph. Printed: 3/1/2002 9:41 :07 AM ¡i'" ~ ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-34 Common Well Name: CD2-34 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 12/30/2001 19:30 - 21 :00 1.50 DRILL TRIP PROD 21:00 - 21:30 0.50 DRILL OBSV PROD 21 :30 - 00:00 2.50 DRILL TRIP PROD 12/31/2001 00:00 - 02:30 2.50 DRILL TRIP PROD 02:30 - 05:30 3.00 DRILL PULD PROD 05:30 - 06:30 1.00 DRILL PULD PROD 06:30 - 12:00 5.50 DRILL TRIP PROD 12:00 - 12:15 0.25 DRILL OBSV PROD 12:15 - 16:00 3.75 DRILL TRIP PROD 16:00 - 16:30 0.50 DRILL PULD PROD 16:30 - 18:00 1.50 CMPL TN RURD CMPL TN 18:00 - 18:30 0.50 CMPL TN SFTY CMPL TN 18:30 - 20:00 1.50 CMPL TN PULD CMPL TN 20:00 - 00:00 4.00 CMPL TN PULD CMPL TN 1/1/2002 00:00 - 01 :30 1.50 CMPLTN RUNT CMPL TN 01 :30 - 02:00 0.50 CMPL TN RUNT CMPL TN 02:00 - 05:30 3.50 CMPL TN RUNT CMPL TN 05:30 - 06:00 06:00 - 08:30 08:30 - 12:00 0.50 CMPL TN RUNT CMPL TN 2.50 CMPL TN RUNT CMPL TN 3.50 CMPL TN NUND CMPL TN 12:00 - 12:30 0.50 CMPL TN SEaT CMPL TN 12:30 - 13:30 1.00 CMPL TN OTHR CMPL TN 13:30 - 14:00 0.50 CMPL TN OTHR CMPL TN 14:00 - 16:00 2.00 CMPL TN PCKR CMPL TN 16:00 - 21:00 5.00 CMPL TN FRZP CMPL TN Page 7 of 8 Spud Date: 12/13/2001 End: 1/1/2002 Group: Start: 12/11/2001 Rig Release: 1/1/2002 Rig Number: 19 Description of Operations Pump out to 7514',2 bpm 320 psi. 80-90 bp h losses. Monitor static losses 97 bph. POH, 4365' at midnight.Tight spot @ 7383' 1 Ok over, 6050' 5-10k over, average losses 7 0 bph. Total losses last 24 hours= 2402 bbls POH, fluid losses averaged 68 bph. Down load LWD, LD BHA. Cleared tools and cleaned rig floor. PU 6 1/8" bit & casing scraper, MU BHA. RIH to 7539', no new problems. Monitor well, static losses at 54 bph. POH, no problems other than fluid losses. LD BHA. Pull wear bushing, RU to run 3 1/2" tubing. Held safety and operations meeting with rig crew. PU 7 its of tail pipe, XN nipple, SAB3 packe r, CMPA sliding sleeve and first GLM. PU 3 1/2" tubing and RIH to 4400'. Fluid 10 sses @ 100 bph. Total losses last 24 hours 1859 bbls. Continue RIH 3 1/2" tbg & completion to 563 6' (176 its.) P/U SSSV - Connect control line & test to 5 000 psi Continue RIH wi 3 12/" tbg wi control line (2 35 Jts. total 3 112" 9.3 # L-80, 8rd Mod) - P U XO, 2 its. 4 1/2" tbg, & hanger MU control line to tbg hanger & test to 5000 psi Land tbg hanger in wellhead - test seals to 500 psi - LD landing it. A set TWC - PU land ing it B - test metal to metal seals to 5000 psi - LD landing it. B ND BOPE & NU tree (pumping down annulus to keep hole full - Average losses 140 bblsl h r) Test tree to 5000 psi RU lubicator - pull TWC - open SSSV - Drop ball & rod for packer setting RU test manifold and lines to tbg & annulus - test lines to 4000 psi Pressure up on tbg to 3500 psi to set packe r - test tbg for 30 mins. - bleed tbg down to 1500 psi - fill annulus took 25 bbls - press ure test annulus to 3500 psi for 30 mins. - b leed tbg to 0 psi to shear open slidling slee ve - observed shear out Displace well wi 139 bbls 9.6 ppg inhibited brine & 116 bbls diesel to freeze protect - s hut well in ( pumped brine @ 1 bbl / min @ Printed: 3/1/2002 9:41:07 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/1/2002 From - To 16:00 - 21 :00 21 :00 - 22:30 22:30 - 00:00 ( ( PHilliPS ALASKA INC. Operations Summary Report CD2-34 CD2-34 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub Hours Code Code 5.00 CMPL TN FRZP CMPL TN Phase 1.50 CMPL TN OTHR CMPL TN 1.50 CMPLTN OTHR CMPLTN Page 8 of 8 Spud Date: 12/13/2001 End: 1/1/2002 Group: Start: 12/11/2001 Rig Release: 1/1/2002 Rig Number: 19 Description of Operations 1840 psi & diesel @ 1.1 bbl I min @ 2200 ps i-appeared as though the sleeve didn't shif t open fully) - Vac line wi hydrocarbon truck - rig down lines RU lubicator & set BPV - secure well LD 16 stds excess DP fl derrick in mouse ho Ie - Release rig @ 23:59 hrs.1/1/2002 * N OTE - fluid loss past 24 hrs. 1997 bbls Total losses 5147 bbls Printed: 3/1/2002 9:41:07 AM . . . . . - - - - - - - - - - - - - - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00112 Sidetrack No. Page 1 of 4 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/34PH1 - 34 Survey Section Name CD2-34PB1 MWD BHI Rep. NEWLON I MATTESON 'I\IT£Q WELL DATA Target TVD (Fl) Target Coord. NIS Slot Coord. NIS -1904.11 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W -1520.99 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 1OmD Vert. Sec. Azim. 104.29 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Inc!. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (Fl) (DO) (DO) (Fl) (Fl) (Fl) (Fl) (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT -- 18-DEC-01 MWD 104.00 0.00 0.00 104.00 104.00 0.00 0.00 0.00 0.00 0.00 18-DEC-01 MWD 270.00 2.40 45.00 166.00 269.95 1.78 2.46 2.46 1.45 1.45 18-DEC-01 MWD 307.51 3.29 29.99 37.51 307.42 2.47 3.95 3.55 3.08 2.37 18-DEC-O1 MWD 398.44 6.21 63.66 90.93 398.04 6.91 8.39 9.27 4.31 3.21 37.03 18-DEC-01 MWD 490.91 7.46 86.30 92.47 489.87 16.42 11.00 19.74 3.18 1.35 24.48 18-DEC-01 MWD 577 .96 7.98 87.35 87.05 576.13 27.57 11.64 31.42 0.62 0.60 1.21 18-DEC-O1 MWD 666.03 6.72 96.01 88.07 663.47 38.52 11.38 42.65 1.90 -1.43 9.83 18-DEC-O1 MWD 756.37 6.45 98.37 90.34 753.22 48.80 10.09 52.92 0.42 -0.30 2.61 18-DEC-01 MWD 846.29 4.63 103.99 89.92 842.72 57.45 8.48 61.44 2.11 -2.02 18-DEC-01 MWD 934.56 3.21 103.93 88.27 930.78 63.48 7.02 67.30 1.61 -1.61 18-DEC-01 MWD 1030.72 1.22 170.31 96.16 1026.87 66.59 5.36 70.09 3.06 -2.07 " / 18-DEC-O1 MWD 1125.62 1.40 199.17 94.90 1121.75 66.90 3.27 69.87 0.71 0.19 -~, - 18-DEC-01 MWD 1219.97 1.26 188.59 94.35 1216.07 66.91 1.16 69.34 0.30 -0.15 18-DEC-01 MWD 1315.03 1.43 193.88 95.06 1311.11 67.02 -1.03 68.90 0.22 0.18 18-DEC-01 MWD 1411.40 1.43 191.35 96.37 1407.45 67.09 -3.37 68.38 0.07 0.00 18-DEC-01 MWD 1506.30 1.26 168.47 94.90 1502.32 67.61 -5.55 68.35 0.59 -0.18 18-DEC-01 MWD 1602.11 1.40 149.40 95.81 1598.11 68.89 -7.59 69.16 0.48 0.15 18-DEC-01 MWD 1697.47 1.76 110.18 95.36 1693.43 71.17 -9.10 71.13 1.17 0.38 1 8-DEC-01 MWD 1793.25 1.95 109.37 95.78 1789.16 74.26 -10.15 74.04 0.20 0.20 - 18-DEC-01 MWD 1887.26 1.91 110.32 94.01 1883.12 77.41 -11 .22 77.02 0.05 -0.04 18-DEC-01 MWD 1983.84 1.98 108.84 96.58 1979.64 80.67 -12.32 80.11 0.09 0.07 18-DEC-01 MWD 2078.99 1.00 82.98 95.15 2074.76 83.08 -12.75 82.49 1.22 -1.03 18-DEC-01 MWD 2173.85 0.85 70.13 94.86 2169.61 84.44 -12.41 83.97 0.27 -0.16 - - - - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00112 Sidetrack No. Page 2 of A - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/34PH1 - 34 Survey Section Name CD2-34PB1 MWD BHI Rep. NEWLON I MATTESON ,~ WELL DATA Target TVD (F1) Target Coord. NIS Slot Coord. N/S -1904.11 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. E/W Slot Coord. E/W -1520.99 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Builcl\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 104.29 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F1) (DO) (DO) (F1) (F1) (F1) (F1) (Per 100 F1) Drop (-) Left (-) 18-DEC-01 MWD 2269.13 0.95 76.13 95.28 2264.88 85.72 -11 .98 85.40 0.14 0.10 -'-, 18-DEC-01 MWD 2320.65 0.87 74.80 51.52 2316.39 86.44 -11.78 86.20 0.16 -0.16 20-DEC-01 MWD 2463.95 0.88 88.77 143.30 2459.67 88.44 -11.47 88.35 0.15 0.01 20-DEC-01 MWD 2558.33 1.00 81.47 94.38 2554.04 89.90 -11.33 89.89 0.18 0.13 20-DEC-01 MWD 2653.65 0.72 77.67 95.32 2649.35 91.20 -11.08 91.29 0.30 -0.29 20-DEC-01 MWD 2749.57 0.84 84.74 95.92 2745.26 92.40 -10.89 92.58 0.16 0.13 20-DEC-01 MWD 2844.72 0.85 79.43 95.15 2840.40 93.70 -10.69 93.97 0.08 0.01 20-DEC-01 MWD 2941.17 0.89 75.58 96.45 2936.84 95.01 -10.37 95.40 0.07 0.04 20-DEC-01 MWD 3036.62 0.87 78.40 95.45 3032.28 96.31 -10.04 96.83 0.05 -0.02 21-DEC-01 MWD 3131.92 0.82 86.56 95.30 3127.57 97.61 -9.86 98.22 0.14 -0.05 21-DEC-01 MWD 3227.81 0.83 93.97 95.89 3223.45 98.95 -9.86 99.59 0.11 0.01 21-DEC-01 MWD 3323.68 0.84 96.92 95.87 3319.31 100.33 -10.00 100.98 0.05 0.01 21-DEC-01 MWD 3418.30 1.02 95.37 94.62 3413.91 101 .85 -10.16 102.51 0.19 0.19 ,-="o'-,,~ , 21-DEC-01 MWD 3513.78 0.94 108.52 95.48 3509.38 103.47 -10.49 104.10 0.25 -0.08 - 21-DEC-O1 MWD 3609.11 0.80 98.83 95.33 3604.70 104.91 -10.84 1 05.50 0.21 -0.15 21-DEC-01 MWD 3704.93 0.97 106.35 95.82 3700.51 106.39 -11.17 106.94 0.21 0.18 21-DEC-01 MWD 3800.06 1.04 103.42 95.13 3795.62 108.05 -11.60 108.55 0.09 0.07 21-DEC-01 MWD 3895.58 1.06 100.42 95.52 3891.13 109.80 -11.96 110.26 0.06 0.02 21-DEC-01 MWD 3991.49 1.13 108.32 95.91 3987.02 111 .63 -12.42 112.03 0.17 0.07 21-DEC-01 MWD 4085.71 1.10 107.39 94.22 4081 .22 113.46 -12.98 113.78 0.04 -0.03 21-DEC-01 MWD 4182.52 0.96 102.94 96.81 4178.02 115.20 -13.44 115.46 0.17 -0.14 21-DEC-O1 MWD 4276.92 0.84 105.22 94.40 4272.40 116.68 -13.80 116.89 0.13 -0.13 21-DEC-01 MWD 4372.53 0.78 97.95 95.61 4368.00 118.03 -14.07 118.21 0.12 -0.06 21-DEC-01 MWD 4467.63 0.89 108.00 95.10 4463.09 119.41 -14.39 119.56 0.19 0.12 . . . . . . . . . -. . - - - - - - - - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00112 Sidetrack No. Page 3 of 4 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/34PH1 - 34 Survey Section Name CD2-34PB1 MWD BHI Rep. NEWLON I MATTESON II\ITEQ WELL DATA Target TVD (FT) Target Coord. NIS Slot Coord. N/S -1904.11 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W -1520.99 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 3OmD 1OmD Vert. Sec. Azim. 104.29 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Inc!. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical Build (+) Right (+) Comment Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (Fì) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) -... 21-DEC-01 MWD 4563.56 0.65 11 0.20 95.93 4559.02 120.69 -14.81 120.78 0.25 -0.25 " 21-DEC-01 MWD 4659.37 0.54 112.39 95.81 4654.82 121.68 -15.17 121.70 0.12 -0.11 21-DEC-01 MWD 4753.93 0.46 1 05.17 94.56 4749.38 122.50 -15.43 122.48 0.11 -0.08 21-DEC-01 MWD 4849.59 0.32 92.18 95.66 4845.03 123.15 -15.54 123.12 0.17 -0.15 21-DEC-01 MWD 4945.14 0.19 141.46 95.55 4940.58 123.54 -15.68 123.49 0.25 -0.14 21-DEC-01 MWD 5040.61 0.19 204.96 95.47 5036.05 123.63 -15.95 123.52 0.21 0.00 21-DEC-01 MWD 5136.09 2.10 98.19 95.48 5131.51 125.34 -16.34 125.18 2.26 2.00 21-DEC-O1 MWD 5231.32 4.68 96.65 95.23 5226.57 130.93 -17.04 130.77 2.71 2.71 21-DEC-01 MWD 5326.35 7.42 98.61 95.03 5321 .06 140.88 -18.41 140.69 2.89 2.88 2.06 21-DEC-01 MWD 5421.74 9.19 100.06 95.39 5415.45 154.61 -20.66 154.28 1.87 1.86 1.52 21-DEC-01 MWD 5517.29 10.53 1 01.46 95.55 5509.58 170.94 -23.73 170.35 1.42 1.40 1.47 22-DEC-01 MWD 5611 .91 13.17 106.48 94.62 5602.18 190.35 -28.50 189.16 2.99 2.79 5.31 22-DEC-01 MWD 5708.70 15.24 107.57 96.79 5696.01 214.07 -35.47 211 .87 2.16 2.14 1.13 ---, - 22-DEC-01 MWD 5804.59 17.62 103.81 95.89 5787.98 241.17 -42.74 237.98 2.72 2.48 -3.92 22-DEC-01 MWD 5897.31 21.32 100.66 92.72 5875.38 272.03 -49.21 268.18 4.15 3.99 -3.40 22-DEC-01 MWD 5995.01 24.76 99.57 97.70 5965.27 310.16 -55.90 305.82 3.55 3.52 -1.12 22-DEC-01 MWD 6086.87 27.10 101 .20 91.86 6047.88 350.23 -63.16 345.32 2.66 2.55 1.77 22-DEC-01 MWD 6185.93 26.47 100.34 99.06 6136.31 394.79 -71.51 389.18 0.75 -0.64 -0.87 22-DEC-01 MWD 6281.20 26.82 101.84 95.27 6221 .47 437.44 -79.73 431.10 0.80 0.37 1.57 22-DEC-01 MWD 6376.08 27.04 103.97 94.88 6306.06 480.39 -89.33 472.98 1.04 0.23 2.24 22-DEC-01 MWD 6472.25 27.72 106.25 96.17 6391 .46 524.61 -100.87 515.67 1.30 0.71 2.37 22-DEC-01 MWD 6567.37 28.38 107.12 95.12 6475.40 569.30 -113.71 558.51 0.82 0.69 0.91 22-DEC-01 MWD 6663.04 27.98 106.70 95.67 6559.73 614.43 -126.85 601.74 0.47 -0.42 -0.44 22-DEC-01 MWD 6758.93 28.01 107.00 95.89 6644.40 659.39 -139.90 644.81 0.15 0.03 0.31 . . . . . . ------- = SURVEY CALCULATION AND FIELD WORKSHEET Job No, 0450-00112 Sidetrack No, Page ~ of ~ - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/34PH1 - 34 Survey Section Name CD2-34PB1 MWD BHI Rep. NEWLON I MATTESON II\I'TEQ. WELL DATA TargetTVD (Fl) TargetCoord.N/S SlotCoord.N/S -1904.11 Grid Correction 0.000 Depths Measured From: RKB~ MSLO SSD Target Description Target Coord. E/W Slot Coord. E/W -1520.99 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 3OmD 10mO Vert. Sec. Azim. 104.29 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl Hole Course V . I Total Coordinate Build Rate Walk Rate Date Tool Depth Angie Direction Length TVD s:~~~an N{+) / S{-) E{+) /W{-) DL Build (+) Right (+) Comment Type (Fl) (DO) (DO) (F1) (F1) (Fl) (Fl) (Per 100 F1) Drop (-) Left (-) 22-DEC-O1 MWD 6854.42 27.95 106.91 95.49 6728.73 704.15 -152.96 687.67 0.08 -0.06 -0.09 ~" 22-DEC-01 MWD 6949.34 27.94 107.13 94.92 6812.59 748.58 -165.98 730.20 0.11 -0.01 0.23 22-DEC-01 MWD 7045.31 27.35 107.50 95.97 6897,60 793.04 -179,24 772.71 0.64 -0.61 0.39 22-DEC-01 MWD 7140.68 26.71 107.71 95.37 6982.55 836.31 -192,34 814.02 0.68 -0.67 0.22 22-DEG-01 MWD 7236.37 26.27 108.42 95.69 7068.19 878.90 -205.58 854.60 0.57 -0.46 0,74 22-DEC-01 MWD 7332.01 26.32 108.08 95.64 7153.94 921.17 -218.85 894.84 0.17 0,05 -0.36 22-DEG-01 MWD 7427.18 26.65 108.35 95.17 7239.12 963,51 -232.11 935,15 0.37 0.35 0.28 22-DEG-01 MWD 7491.42 26.79 107.39 64.24 7296.50 992.34 -240.97 962.64 0.71 0.22 -1.49 - 22-DEG-01 MWD 7562.00 26.79 107.39 70.58 7359.50 1024.10 -250.48 993.00 0.00 0.00 0.00 Projected Data - NO SURVEY -..,- . . . . - . . - - - - - - - - - - - - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00112 Sidetrack No.1 Page 1 of 2 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/34PH1 - 34 Survey Section Name CD2-34 MWD BHI Rep. NEWLON / MATTESON I BALLOU I NTEQ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1904.11 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSD Target Description Target Coord. E/W Slot Coord. E/W -1520.99 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 1 00ft~ 3OmD 1OmD Vert. Sec. Azim. 151.86 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey 'nc!. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (Fl) (F1) (F1) (F1) (Per 100 Fì) Drop (-) Left (-) MWD 6663.04 27.98 106.70 6559.74 395.98 -126.85 601.74 TIE IN POINT --. 24-DEC-01 MWD 6701.48 27.94 107.76 38.44 6593.69 408.48 -132.19 618.95 1.30 -0.10 2.76 24-DEC-01 MWD 6737.12 28.16 111.93 35.64 6625.15 420.93 -137.88 634.71 5.54 0.62 11.70 24-DEC-01 MWD 6769.80 28.58 114.79 32.68 6653.91 433.08 -144.03 648.96 4.35 1.29 8.75 24-DEC-01 MWD 6832.95 28.87 115.63 63.15 6709.29 457.43 -156.96 676.42 0.79 0.46 1.33 24-DEC-01 MWD 6928.70 32.92 119.35 95.75 6791.44 498.03 -179.73 719.96 4.67 4.23 3.89 24-DEC-01 MWD 6959.91 34.97 121 .98 31.21 6817.33 512.94 -188.62 734.94 8.08 6.57 8.43 24-DEC-O1 MWD 6986.38 36.18 124.23 26.47 6838.86 526.44 -197.03 747.84 6.73 4.57 8.50 24-DEC-01 MWD 7023.83 36.35 126.32 37.45 6869.06 546.25 -209.83 765.92 3.33 0.45 5.58 24-DEC-01 MWD 7055.23 36.92 128.08 31 .40 6894.25 563.28 -221.15 780.84 3.81 1.82 5.61 24-DEC-01 MWD 7087.18 38.75 129.56 31.95 6919.49 581.31 -233.44 796.10 6.39 5.73 4.63 25-DEC-O1 MWD 7118.23 41.79 131.48 31.05 6943.18 600.01 -246.49 811.35 10.57 9.79 6.18 25-DEC-01 MWD 7146.49 44.65 132.51 28.26 6963.77 618.21 -259.44 825.73 10.42 10.12 3.64 ~ 25-DEC-01 MWD 7182.48 46.76 133.99 35.99 6988.90 642.62 -277.09 844.48 6.56 5.86 4.11 25-DEC-O1 MWD 7214.29 47.89 133.46 31.81 7010.46 664.84 -293.25 861.39 3.76 3.55 -1.67 25-DEC-01 MWD 7246.33 50.70 134.81 32.04 7031.36 687.98 -310.17 878.81 9.33 8.77 4.21 - 25-DEC-01 MWD 7277.42 54.27 133.47 31.09 7050.29 711 .46 -327.33 896.51 11.98 11.48 -4.31 25-DEC-01 MWD 7308.96 56.37 133.73 31.54 7068.23 736.09 -345.22 915.29 6.69 6.66 0.82 25-DEC-01 MWD 7342.70 56.88 134.92 33.74 7086.79 762.96 -364.91 935.45 3.31 1.51 3.53 25-DEC-01 MWD 7374.66 58.57 134.40 31.96 7103.86 788.77 -383.90 954.67 5.46 5.29 -1.63 25-DEC-01 MWD 7405.28 61.82 135.14 30.62 7119.08 814.16 -402.61 973.53 10.82 10.61 2.42 25-DEC-O1 MWD 7438.01 65.80 136.18 32.73 7133.52 842.36 -423.62 994.04 12.49 12.16 3.18 25-DEC-01 MWD 7468.00 67.80 136.11 29.99 7145.34 868.90 -443.49 1013.14 6.67 6.67 -0.23 25-DEC-01 MWD 7500.47 70.06 138.06 32.47 7157.01 898.19 -465.68 1033.77 8.94 6.96 6.01 :_- ,- :- ~ ~ '- L- -...- --- ~- ~ - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00112 Sidetrack No.1 Page 2 of 2 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD Well Name & No. PAD CD#2/34PH1 - 34 Survey Section Name CD2-34 MWD BHI Rep. NEWLON I MATTESON I BALLOU I N7EQ WELL DATA . Target TVD (FT) Target Coord. N/S Slot Coord. NIS -1904.11 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. E/W Slot Coord. E/W -1520.99 Magn. Declination 0.000 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 151.86 Magn. to Map Corr. 0.000 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) -- 25-DEC-01 MWD 7533.69 72.23 139.03 33.22 7167.74 928.78 -489.24 1 054.58 7.09 6.53 2.92 . " 25-DEC-01 MWD 7565.17 73.95 140.66 31.48 7176.90 958.24 -512.26 1074.00 7.38 5.46 5.18 25-DEC-O1 MWD 7597.12 77.12 141.07 31.95 7184.88 988.60 -536.26 1 093.52 10.00 9.92 1.28 25-DEC-01 MWD 7629.69 80.76 142.22 32.57 7191 .13 1020.06 -561 .32 1113.35 11.70 11.18 3.53 25-DEC-01 MWD 7661.47 83.11 142.90 31.78 7195.59 1051.11 -586.30 1132.48 7.69 7.39 2.14 25-DEC-01 MWD 7723.22 87.55 143.82 61.75 7200.61 1111.96 -635.67 1169.19 7.34 7.19 1.49 25-DEC-01 MWD 7757.24 88.73 146.26 34.02 7201.72 1145.72 -663.54 1188.68 7.96 3.47 7.17 29-DEC-O1 MWD 7840.88 91.97 148.06 83.64 7201.21 1229.06 -733.80 1234.02 4.43 3.87 2.15 29-DEC-O1 MWD 7936.82 92.40 148.18 95.94 7197.55 1324.73 -815.20 1284.66 0.47 0.45 0.13 29-DEC-O1 MWD 8031 .85 91.29 150.02 95.03 7194.49 1419.59 -896.70 1333.43 2.26 -1.17 1.94 29-DEC-01 MWD 8126.83 89.69 151.39 94.98 7193.68 1514.54 -979.53 1379.90 2.22 -1.68 1.44 29-DEC-O1 MWD 8221 .84 89.20 151.70 95.01 7194.60 1609.55 -1063.05 1425.17 0.61 -0.52 0.33 29-DEC-01 MWD 8318.25 87.97 151.67 96.41 7196.98 1705.92 -1147.90 1470.88 1.28 -1.28 -0.03 --"" 1 29-DEC-01 MWD 8413.71 88.09 151.41 95.46 7200.26 1801 .33 -1231.77 1516.35 0.30 0.13 -0.27 29-DEC-01 MWD 8509.43 88.03 151 .81 95.72 7203.50 1896.99 -1315.93 1561.83 0.42 -0.06 0.42 29-DEC-01 MWD 8605.28 87.85 152.24 95.85 7206.94 1992.78 -1400.53 1606.77 0.49 -0.19 0.45 30-pEC-01 MWD 8755.00 90.00 152.00 149.72 7209.75 2142.46 -1532.84 1676.76 1.44 1.44 -0.16 Projected Data - NO SURVEY . , J , " I~ è;lo t- rCj / 14-Jan-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-34PB 1 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0 . 00' M D 'MD 0.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JAN 1 7 2002 Alaska Oil & Gas Cons. Commissjof! Anchorage -- .(J" --... . j -- () m -." ~ - , c,-,,-< Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-34 CD2-34PB 1 Gyro Job No. AKFO11207, Surveyed: 22 December, 2001 SURVEY REPORT 11 January, 2002 Your Ref: 501032039370 Surface Coordinates: 5974452.65 N, 371716.13 E (70020' 18.3696" N, 151002'27.4076" W) Surface Coordinates relative to Project H Reference: 974452.65 N, 128283.87 W (Grid) Surface Coordinates relative to Structure: 9.72 N, 1.53 W (True) Kelly Bushing: 51.9Oft above Mean Sea Level "- spa"""""Y-5UIl DAILLING seAVlces A Halliburton Company Survey Ref: 5vy9800 . - .. Kuparuk River Unit Measured Depth Incl. Azim. (ft) 0.00 0.000 0.000 104.00 0.000 0.000 270.00 2.400 45.000 Sub-Sea Depth (ft) Vertical Depth (ft) -51.90 52.10 218.05 0.00 104.00 269.95 Sperry-Sun Drilling Services Survey Report for CD2-34PB1 Gyro Your Ref: 501032039370 Job No. AKFO11207, Surveyed: 22 December, 2001 Local Coordinates Northlngs Eastlngs (ft) (ft) O.OON O.OON 2.46N O.OOE O.OOE 2.46 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. -~~' Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.155° (11-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 151.860~ (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 270.00ft., The Bottom Hole Displacement is 3.48ft., in the Direction of 45.000° (True). Survey tool program for CD2-34PB1 Gyro From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 270.00 269.95 "-=",, 11 January, 2002 - 13: 10 Survey Tool Description Tolerable Gyro 0- ---._u-- --- --------- Page 2 of 2 Global Coordinates Northings Eastings (ft) (ft) 5974452.65 N 5974452.65 N 5974455.07 N 371716.13 E 371716.13 E 371718.63 E Dogleg Rate (0/100ft) 0_000 1.446 Vertical Section 0.00 0.00 -1.01 . North Slope, Alaska Alpine CD-2 Comment Tolerable Gyro DrillQuest 2.00.09.003 ,¡( , ( a,o-,.., """,--":"1'::'",,,,,,- , J- /0 J" ," , :. - "!,,, ".' "., "" ' 14-Jan-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-34 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 6,663.04' MD 6,701.48' MD 8,755.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JAN 1 7 2002 Alaska Oil & Gas Cons. Comm_n Anchorage ~ ~ ........ ."\ ~'""'- .-4) ~ >--~_. Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-34 CD2-34 Job No. AKMM11207, Surveyed: 30 December, 2001 SUR V E Y R EPO R T 11 January, 2002 Your Ref: 501032039300 Surface Coordinates: 5974452.65 N, 371716.13 E (70020' 18.3696" N, 151002'27.4076" W) Surface Coordinates relative to Project H Reference: 974452.65 N, 128283.87 W (Grid) Surface Coordinates relative to Structure: 9.72 N, 1.53 W (True) Kelly Bushing: 51.9Oft above Mean Sea Level --- 5pe"""""y-5UI! DRILLING SERViCeS A Halliburton Company Survey Ref: 5vy9803 Sperry-Sun Drilling Services . Survey Report for CD2-34 Your Ref: 501032039300 Job No. AKMM11207, Surveyed: 30 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6663.04 27.980 106.700 6507.84 6559.74 126.85 5 601.74 E 5974315.52 N 372315.61 E 395.65 Tie on Point 6701.48 27.940 107.760 6541.79 6593.69 132.19 S 618.95 E 5974309.89 N 372332.73 E 1.297 408.48 Window Point 6737.12 28.160 111.930 6573.25 6625.15 137.88 S 634.70 E 5974303.93 N 372348.38 E 5.536 420.93 6769.80 28.580 114.790 6602.00 6653.90 144.04 S 648.96 E 5974297.53 N 372362.53 E 4.352 433.08 6832.95 28.870 115.630 6657.38 6709.28 156.97 S 676.41 E 5974284.14 N 372389.76 E 0.787 457.43 ~~---- 6928.70 32.920 119.350 6739.54 6791.44 179.73 S 719.96 E 5974260.63 N 372432.91 E 4.675 498.04 6959.91 34.970 121.980 6765.43 6817.33 188.62 S 734.94 E 5974251.48 N 372447.73 E 8.079 512_94 6986.38 36.180 124.230 6786.96 6838.86 197.04 S 747.83 E 5974242.85 N 372460.48 E 6.734 526.44 7023.83 36.350 126.320 6817.15 6869.05 209.83 S 765.91 E 5974229.75 N 372478.34 E 3.332 546.25 7055.23 36.920 128.080 6842.35 6894.25 221.16 S 780.84 E 5974218.17 N 372493.07 E 3.805 563.28 7087.18 38.750 129.560 6867.58 6919.48 233.45 S 796.10 E 5974205.62 N 372508.12 E 6.393 581.31 7118.23 41 .790 131.480 6891.27 6943.17 246.49 S 811.35 E 5974192.31 N 372523.14 E 10.574 600.01 7146.49 44.650 132.510 6911.87 6963.77 259.44 5 825.72 E 5974179.12 N 372537.30 E 10.423 618.21 7182.48 46.760 133.990 6937.00 6988.90 277.09 S 844.48 E 5974161.15 N 372555.75 E 6.560 642.62 7214.29 47.890 133.460 6958.56 7010.46 293.26 S 861.38 E 5974144.70 N 372572.37 E 3.758 664.85 7246.33 50.700 134.810 6979.46 7031.36 310.17 S 878.81 E 5974127.49 N 372589.50 E 9.333 687.98 7277.42 54.270 133.470 6998.39 7050.29 327.34 S 896.51 E 5974110.02 N 372606.91 E 11.980 711 .46 7308.96 56.370 133.730 7016.33 7068.23 345.22 S 915.29 E 5974091.82 N 372625.38 E 6.693 736.09 7342.70 56_880 134.920 7034.89 7086.79 364.91 S 935.44 E 5974071.79 N 372645.19 E 3.311 762_96 7374.66 58.570 134.400 7051.96 7103.86 383.90 S 954.66 E 5974052.47 N 372664.09 E 5.464 788.77 7405.28 61.820 135.140 7067.18 7119.08 402.61 S 973.52 E 5974033.44 N 372682.62 E 10.819 814.16 '-c...- 7438.01 65.800 136.180 7081.62 7133.52 423.62 S 994.04 E 5974012.09 N 372702.78 E 12.490 842.36 7468.30 67.810 136.110 7093.55 7145.45 443.69 S 1013.33 E 5973991.68 N 372721.72 E 6.639 869.16 7500.47 70.060 138.060 7105.11 7157.01 465.68 S 1033.77 E 5973969.35 N 372741.78 E 8.995 898.19 7533.69 72.230 139.030 7115.85 7167.75 489.24 S 1054.58 E 5973945.44 N 372762.18 E 7.093 928.78 7565.17 73.950 140.660 7125.00 7176.90 512.26 S 1073.99 E 5973922.09 N 372781.20 E 7.375 958.24 7597.12 77.120 141.070 7132.98 7184.88 536.25 S 1093.52 E 5973897.77 N 372800.31 E 9.999 988_60 7629.69 80.760 142.220 7139.23 7191.13 561.32 S 1113.35 E 5973872.37 N 372819.71 E 11.701 1020.05 7661.47 83.110 142.900 7143.69 7195.59 586.30 S 1132.47 E 5973847.06 N 372838.41 E 7.692 1051.10 7723.22 87.550 143.820 7148.71 7200.61 635.67 S 1169.19 E - 5973797.07 N 372874.28 E 7.342 1111.96 ---..---- ---------- - 11 January, 2002 - 16: 15 Page 2 of 4 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for CD2-34 Your Ref: 501032039300 Job No. AKMM11207, Surveyed: 30 December, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (a/100ft) 7757.24 88.730 146.260 7149.82 7201.72 663.54 S 1188.67 E 5973768.88 N 372893.28 E 7.963 7840.88 91.970 148.060 7149.31 7201.21 733.79 S 1234.02 E 5973697.85 N 372937.42 E 4.431 7936.82 92.400 148.180 7145.65 7197.55 815.20 S 1284.66 E 5973615.59 N 372986.65 E 0.465 8031.85 91.290 150.020 7142.59 7194.49 896.70 S 1333.43 E 5973533.27 N 373034.02 E 2.260 8126.83 89.690 151.390 7141.78 7193.68 979.52 S 1379.90 E 5973449.66 N 373079.07 E 2.218 <-~ 8221.84 89.200 151.700 7142.70 7194.60 1063.05 S 1425.17E 5973365.37 N 373122.90 E 0.610 8318.25 87.970 151.670 7145.08 7196.98 1147.90 S 1470.88 E 5973279.75 N 373167.16 E 1.276 8413.71 88.090 151.410 7148.36 7200.26 1231.77 S 1516.34 E 5973195.12 N 373211.18 E 0.300 8509.43 88.030 151.810 7151.60 7203.50 1315.93 S 1561.83 E 5973110.19 N 373255.22 E 0.422 8605.28 87.850 152.240 7155.05 7206.95 1400.53 S 1606.76 E 5973024.84 N 373298.70 E 0.486 8755.00 90.000 152.000 7157.86 7209.76 1532.84 S 1676.76 E 5972891.35 N 373366.42 E 1 .445 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.1540 (11-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 151.8600 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8755.000., The Bottom Hole Displacement is 2271.81ft, in the Direction of 132.4330 (True). --- _u_-- u.._u 11 January, 2002 - 16:15 Page 3 of 4 Vertical Section 1145.72 1229.06 1324.72 1419.59 1514.54 1609.54 1705.92 1801.32 1896.99 1992.78 2142.46 . North Slope, Alaska Alpine CD-2 Comment Projected Survey DrillQuest 2.00.09.003 ~ Kuparuk River Unit Comments Measured Depth (ft) -~ 6663.04 6701.48 8755.00 Sperry-Sun Drilling Services; Survey Report for CD2-34 Your Ref: 501032039300 Job No. AKMM11207, Surveyed: 30 December, 2001 . 126.85 S 132.19S 1532.84 S Survey too/ program for CD2-34 North Slope, Alaska Alpine CD-2 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6559.74 6593.69 7209.76 From Measured Vertical Depth Depth (ft) (ft) 0.00 270.00 ',- 11 January, 2002 - 16:15 0.00 269.95 To Measured Vertical Depth Depth (ft) (ft) 270.00 8755.00 269.95 7209.76 Comment 601.74 E 618.95 E 1676.76 E Tie on Point Window Point Projected Survey Survey Tool Description Tolerable Gyro (CD2-34PB1 Gyro) MWD Magnetic (CD2-34PB1) .-- ------ Page 4 of 4 DrillQuest 2.00.09.003 ~' ( ~"tl1J",,""1 I G GJ!Ifi~l~:I' it ' '" 14-Jan-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-34PB 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 270.00' MD 'MD 7,562.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED , i\~J 1\ -.1' 2002 ....1 " ~ Ai.a Oil & Gas Cons. Commi8S\on .Anchorage ....;... St. ~ Q) 'ð DEFINlllVE ~~- Kuparuk River Unit North Slope, Alaska Alpine CD-2, Slot CD2-34 CD2-34PB 1 Job No. AKMM11207, Surveyed: 22 December, 2001 SURVEY REPORT 11 January, 2002 Your Ref: 501032039370 Surface Coordinates: 5974452.65 N, 371716.13 E (70020' 18.3696" N, 151002'27.4076" W) Surface Coordinates relative to Project H Reference: 974452.65 N, 128283.87 W (Grid) Surface Coordinates relative to Structure: 9.72 N, 1.53 W (True) ~ Kelly Bushing: 51.90ft above Mean Sea Level -,-~ 5 P a ........... Y - 5 U ., DRILLING SERVices A Halliburton Company Survey Ref: svy9801 . - . Sperry-Sun Drilling Services Survey Report for CD2-34PB1 Your Ref: 501032039370 Job No. AKMM11207, Surveyed: 22 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastings Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 270.00 2.400 45.000 218.05 269.95 2.46 N 2.46 E 5974455.07 N 371718.63 E 1.78 Tie on point MWD Magnetic 307.51 3.290 29.990 255.52 307.42 3.95 N 3.55 E 5974456.53 N 371719.75 E 3.075 2.47 398.44 6.210 63.660 346.14 398.04 8.39 N 9.27E 5974460.88 N 371725.54 E 4.311 6.91 490.91 7.460 86.300 437.97 489.87 11.00 N 19.74 E 5974463.31 N 371736.06 E 3_184 16.42 ~~ 577.96 7.980 87.350 524.23 576.13 11.64 N 31.42 E 5974463.75 N 371747.74 E 0.619 27.57 666.03 6.720 96.010 611.57 663.47 11 .38 N 42.65 E 5974463.30 N 371758.97 E 1.901 38.52 756.37 6.450 98.370 701.32 753.22 10.09 N 52.92 E 5974461.83 N 371769.22 E 0.423 48.80 846.29 4.630 103.990 790.82 842.72 8.48 N 61.44 E 5974460.08 N 371777.71 E 2.110 57.45 934.56 3.210 103.930 878.88 930.78 7.02N 67.30 E 5974458.52 N 371783.54 E 1.609 63.48 1030.72 1.220 170.310 974.97 1026.87 5.36N 70.09 E 5974456.82 N 371786.30 E 3.059 66.59 1125.62 1 .400 199.170 1069.85 1121.75 3.27N 69.87 E 5974454.73 N 371786.05 E 0.712 66.90 1219.97 1.260 188.590 1164_17 1216.07 1.16 N 69.34 E 5974452.62 N 371785.48 E 0.299 66.91 1315.03 1.430 193.880 1259.21 1311.11 1.038 68.90 E 5974450.45 N 371785.00 E 0.221 67.02 1 411 .40 1 .430 191.350 1355.55 1407.45 3.378 68.38 E 5974448.11 N 371784.44 E 0.066 67.09 1506.30 1.260 168.4 70 1450.42 1502.32 5.558 68.35 E 5974445.93 N 371784.38 E 0.589 67.61 1602.11 1.400 149.400 1546.21 1598.11 7.598 69.16 E 5974443.87 N 371785.15 E 0.482 68.89 1697.47 1.760 110.180 1641.53 1693.43 9.108 71.13 E 5974442.33 N 371787.09 E 1.168 71.17 1793.25 1.950 109.370 1737.26 1789.16 10.158 74.04 E 5974441.23 N 371789.99 E 0.200 74.26 1887.26 1.910 110.320 1831.22 1883.12 11.22 8 77.02 E 5974440.11 N 371792.95 E 0.054 77.41 1983.84 1.980 108.840 1927.74 1979.64 12.32 8 80.11 E 5974438.96 N 371796.02 E 0.089 80.67 "- 2078.99 1.000 82.980 2022.86 2074.76 12.75 S 82.49 E 5974438.49 N 371798.39 E 1.224 83.08 2173.85 0_850 70.130 2117.71 2169.61 12.41 8 83.97 E 5974438.80 N 371799.88 E 0.269 84.44 2269.13 0.950 76.130 2212.98 2264.88 11.98 8 85.40 E 5974439.21 N 371801.32 E 0.144 85.72 2320.65 0.870 74.800 2264.49 2316.39 11.78 8 86.20 E 5974439.40 N 371802.11 E 0.161 86.44 2463.95 0.880 88.770 2407.77 2459.67 11.478 88.35 E 5974439.67 N 371804.27 E 0.149 88.44 2558.33 1.000 81.470 2502.14 2554.04 11.33 8 89.89 E 5974439.78 N 371805.81 E 0.179 89_90 2653.65 0.720 77.670 2597.45 2649.35 11.08 S 91.29 E 5974440.01 N 371807.22 E 0.300 91.20 2749.57 0.840 84.740 2693.36 2745.26 10.898 92.58 E 5974440.18 N 371808.51 E 0_160 92.40 2844.72 0.850 79.430 2788.50 2840.40 10.69 S 93.97 E 5974440.35 N 371809.90 E 0.083 93.70 2941 .17 0.890 75.580 2884.94 2936.84 10.37 S 95.40 E 5974440.64 N 371811.34E 0.073 95.01 --------- 11 January, 2002 - 13: 11 Page 2 of 5 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for CD2-34PB1 Your Ref: 501032039370 Job No. AKMM11207, Surveyed: 22 December, 2001 North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3036.62 0.870 78.400 2980.38 3032.28 10.04 S 96.83 E 5974440.95 N 371812.77 E 0.050 96.31 3131.92 0.820 86.560 3075.67 3127.57 9.865 98.22 E 5974441.11 N 371814.16 E 0.137 97.61 3227.81 0.830 93.970 3171.55 3223.45 9.875 99.59 E 5974441.08 N 371815.54 E 0.112 98.95 3323.68 0.840 96.920 3267.41 3319.31 10.00 S 1 00.98 E 5974440.93 N 371816.93 E 0.046 100.33 3418.30 1.020 95.370 3362.02 3413.92 1 0.16 5 102.51 E 5974440.74 N 371818.45 E 0.192 101.85 ~ 3513.78 0.940 108.520 3457.48 3509.38 10.49 S 104.10 E 5974440.38 N 371820.04 E 0.249 103.47 3609.11 0.800 98.830 3552.80 3604.70 10.84 5 105.50 E 5974440.01 N 371821.43 E 0.213 104.91 3704.93 0.970 106.350 3648.61 3700.51 11.175 106.94 E 5974439.65 N 371822.86 E 0.215 106.39 3800.06 1.040 103.420 3743.72 3795.62 11.60 5 1 08.55 E 5974439.20 N 371824.47 E 0.091 108.05 3895.58 1.060 100.420 3839.23 3891.13 11.96 5 110.26 E 5974438.81 N 371826.17 E 0.061 109.80 3991.49 1.130 108.320 3935.12 3987.02 12.42 S 112.03 E 5974438.32 N 371827.93 E 0.173 111.63 4085.71 1.100 1 07.390 4029.32 4081.22 12.985 113.78 E 5974437.73 N 371829.67 E 0.037 113.46 4182.52 0.960 102.940 4126.12 4178.02 13.44 S 115.46 E 5974437.24 N 371831.34 E 0.166 115.20 4276.92 0.840 105.220 4220.51 4272.41 13.80 S 116.89 E 5974436.86 N 371832.77 E 0.133 116.68 4372.53 0.780 97.950 4316.11 4368.01 14.075 118.21 E 5974436.56 N 371834.09 E 0.124 118.03 4467.63 0.890 108.000 4411.20 4463.1 0 14.395 119.56 E 5974436.22 N 371835.42 E 0.192 119.41 4563.56 0.650 110.200 4507.12 4559.02 14.81 5 120.78 E 5974435.78 N 371836.64 E 0.252 120.69 4659.37 0.540 112.390 4602.92 4654.82 15.17 S 121.70 E 5974435.40 N 371837.56 E 0.117 121.68 4753.93 0.460 105.170 4697.48 4749.38 15.43 S 122.48 E 5974435.12 N 371838.33 E 0.108 122.50 4849.59 0.320 92.180 4793.14 4845.04 15.55 S 123.12 E 5974435.00 N 371838.97 E 0.172 123.15 4945.14 0.190 141.460 4888.69 4940.59 15.685 123.49 E 5974434.86 N 371839.33 E 0.255 123.54 -- 5040.61 0.190 204.960 4984.15 5036.05 15.955 123.52 E 5974434.59 N 371839.36 E 0.209 123.63 5136.09 2.100 98.190 5079.61 5131.51 16.345 125.18 E 5974434.17 N 371841.01 E 2.265 125.34 5231.32 4.680 96.650 5174.67 5226.57 17.045 130.77 E 5974433.38 N 371846.59 E 2.711 130.93 5326.35 7.420 98.610 5269.16 5321.06 18.41 5 140.69 E 5974431.84 N 371856.48 E 2.891 140.88 5421.74 9.190 100.060 5363.55 5415.45 20.66 5 154.28 E 5974429.35 N 371870.03 E 1.868 154.61 5517.29 10.530 101.460 5457.68 5509.58 23.73 5 170.35 E 5974426.01 N 371886.05 E 1 .425 170.94 5611.91 13.170 106.480 5550.28 5602.18 28.50 5 189.16 E 5974420.91 N 371904.78 E 2.993 190.35 5708.70 15.240 107.570 5644.11 5696.01 35.47 5 211.87 E 5974413.56 N 371927.36 E 2.156 214.07 5804.59 17.620 103.810 5736.08 5787.98 42.745 237.98 E 5974405.84 N 371953.35 E 2.717 241.17 --- -_un - ~ 11 January, 2002 - 13: 11 Page 3 of 5 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for CD2-34PB1 Your Ref: 501032039370 Job No. AKMM11207, Surveyed: 22 December, 2001 . North Slope, Alaska Kuparuk River Unit Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5897.31 21 .320 100.660 5823.48 5875.38 49.21 S 268.18 E 5974398.86 N 371983.43 E 4.147 272.03 5995.01 24.760 99.570 5913.38 5965.28 55.90 S 305.82 E 5974391.53 N 372020.95 E 3.548 310.16 6086.87 27.100 101.200 5995.98 6047.88 63.16 S 345.32 E 5974383.59 N 372060.32 E 2.663 350.23 6185.93 26.470 100.340 6084.42 6136.32 71 .51 S 389.18 E 5974374.49 N 372104.03 E 0.747 394.79 6281.20 26.820 101.840 6169.57 6221.47 79.73 S 431.10 E 5974365.56 N 372145.80 E 0.796 437.44 <--, 6376.08 27.040 103.970 6254.16 6306.06 89.33 S 472.98 E 5974355.24 N 372187.51 E 1.043 480.39 6472.25 27.720 106.250 6339.56 6391.46 100.87 S 515.67 E 5974342.98 N 372230.00 E 1.299 524.61 6567.37 28.380 1 07.120 6423.51 6475.41 113.71 S 558.51 E 5974329.40 N 372272.61 E 0.816 569.30 6663.04 27.980 106.700 6507.84 6559.74 126.85 S 601.74 E 5974315.52 N 372315.61 E 0.467 614.43 6758.93 28.010 107.000 6592.51 6644.41 139.90 S 644.81 E 5974301.74 N 372358.46 E 0.150 659.39 6854.42 27.950 106.910 6676.84 6728.74 152.96 S 687.67 E 5974287.94 N 372401.08 E 0.077 704.15 6949.34 27.940 107.130 6760.69 6812.59 165.98 S 730.20 E 5974274.20 N 372443.38 E 0.109 748.58 7045.31 27.350 107.500 6845.70 6897.60 179.24 S 772.71 E 5974260.22 N 372485.66 E 0.640 793.04 7140.68 26.710 107.960 6930.65 6982.55 192.43 S 814.00 E 5974246.32 N 372526.71 E 0.706 836.31 7236.37 26.270 108.420 7016.30 7068.20 205.76 S 854.54 E 5974232.30 N 372567.03 E 0.507 878.89 7332.01 26.320 108.080 7102.04 7153.94 219.02 S 894.78 E 5974218.35 N 372607.03 E 0.166 921.16 7427.18 26.650 108.350 7187.22 7239.12 232.29 S 935.10 E 5974204.40 N 372647.12 E 0.369 963.50 7491.42 26.790 107.390 7244.60 7296.50 241.15 S 962.59 E 5974195.06 N 372674.45 E 0.706 992.33 7562.00 26.790 107.390 7307.61 7359.51 250.66 S 992.94 E 5974185.04 N 372704.64 E 0.000 1024.09 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. "-- Magnetic Declination at Surface is 25.155° (11-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 104.290° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7562.00ft., The Bottom Hole Displacement is 1024.09ft., in the Direction of 104.168° (True). .----_u_-.--- ------ - u- 11 January, 2002 - 13: 11 Page 4 of 5 Dri/lQuest 2.00.09.003 " Kuparuk River Unit Comments Measured Depth (ft) '- 270.00 7562.00 ""-" Sperry-Sun Drilling Services Survey Report for CD2-34PB1 Your Ref: 501032039370 Job No. AKMM11207, Surveyed: 22 December, 2001 . 2.46 N 250.66 S Survey tool program for CD2-34PB1 North Slope, Alaska Alpine CD-2 Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) 269.95 7359.51 Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 270.00 ~-~ 11 January, 2002 - 13: 11 0.00 269.95 To Measured Vertical Depth Depth (ft) (ft) 270.00 7562.00 269.95 7359.51 Comment 2.46 E 992.94 E Tie on point Projected Survey Survey Tool Description Tolerable Gyro (CD2-34PB1 Gyro) MWD Magnetic (CD2-34PB1) Page 5 of 5 DrillQuest 2.00.09.003 ( ( MIl cPrs 3/0 X. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1905' FNL, 1522' FEL, Sec. 2, T11 N, R4E, UM At top of productive interval 2554' FNL, 348' FEL, Sec. 2, T11 N, R4E, UM At effective depth At total depth 81' FSL, 1065' FWL, Sec. 1, T11 N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 8755 7210 8755 7210 measured true vertical Length 68' 2332' Casing Conductor Surface Size 16" 9-5/8" Production 7765' 7" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth Operational shutdown - Plugging - Pull tubing 5. Type of Well: Development _X Exploratory - Stratigraphic - Service ----- Per APD ----- Per APD feet feet feet feet Plugs (measured) Junk (measured) Cemented 580 Sx AS1 333 SxAS III L & 242 Sx 15.8 class G 158 Sx 15.8 class G Packers & SSSV (type & measured depth) 3.5" 9.3#, L-80 eue @7640' MD Re-enter suspended well - Time extension - Stimulate - Variance Perforate - 6. Datum elevation (DF or KB feet) R KB 52 feet 7. Unit or Property name Other _X Annular Disposal Colville River Unit 8. Well number CD2-34 9. Permit number / approval number 201-191 10. API number 50-103-20393-00 11. Field I Pool Colville River Field I Alpine Oil Pool Measured Depth 105' 2369' True vertical Depth 105' 2364' 7802' 7203' RECEIVED FEe .1 9 2002 Alaska Oil & Gas Coos. Commission Anchorage 13. Attachments 7" Baker SAB3 Permanent Packer @ 7328' MD, Camco TRM4E @ 1988' MD Description summary of proposal - Detailed operations program - BOP sketch - Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic 14. Estimated date for commencing operation 15. Status of well classification as: March 15, 2002 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. Signed )I ~- ~ /'\ ~ ~ Chin Alvord ~ ~ - 1.- ("IC..{ " FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I ApprovAl1o" A /- f'~ Plug integrity - BOP Test - Location clearance - (\ ~ """-- B - Ur¡ V\ Mechanical Integrity Test- . . .. SUbSeqUentformreqUired10-~C'~ G"'\'\.J\<::.)..y.êJ\~>b~~<::\t. \ Onglnal Signed By 1 Cammy Oechsli Approved by order of the Commission Form 10-403 Rev 06/15/88 . Title: Alpine Drilling Team Leader ...-, f~\ II, I. ~,..- ,/ ~ ¡ ! x Gas- Suspended - Questions? Call Vern Johnson 265-6081 Date l (f ð I ~ L Commissioner Date ~ !õ\ ~ ~~.. l i¡ ~:\~.. Æ \ .. \--- I\ì ¡I.~~!\ i \ - . ,- SUBMIT IN TRIPLICATE (' {' Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-34 b. The depth to the base of freshwater aquifers There are no USDW aquifers in the Colville and permafrost, if present. River Unit. Base of Permafrost = 1652' TVD (RKB) c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. d. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. Types of fluids can be mud, diesel, cement, and water. Maximum volume to be pumped is 35,000 bbls. f. An estimate of maximum anticipated Maximum anticipated pressure at casing shoe pressure at the outer casing shoe during during disposal operations is 1905 psi. See annular disposal operation and calculations attached calculation page. showing how this value was determined. g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. See attached cementing reports, LOT/FIT reports, and casing reports. h. Details that show the inner and outer casing See attached casing summary sheet and strings have sufficient strength in collapse calculation page. and burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission to confirm containment of drilling wastes. NA f " ,( CD2-34 Pressure Calculations for Annular Disposal .... .... Q) "0 Q) co "0 Q) co L: Q) L: (f) ëñ a. a. 0 0 C) 0 0 0 C N 0 (f) N co + + () ~ ~ = co (f) (f) --- a. a. L() I T- T- O) 0 0 (f) (f) co co <.9 <.9 ç9-5/8" 36 Ib/ft, J-55 BTC casing @ 2369 ft MD (2364 ft TVD) Pburst = 3520 psi, @ 85010: Pburst85% = 2992 psi """"" .... .... .... ..tö'ë Estimated Top of Cement @ 7040 ft MD (6882 ft TVD) (7" csg x 8-1/2" Open hole annulus) C) c :ë :J l- N C) --- c "7 ëñ C") co () ç3-1/2" 9.3 Ib/ft L-80 tubing to 7640 ft MD r:... ç7" 26 Ib/ft, L-80, BTC casing @ 7802 ft MD (7203 ft TVD) Pcollapse = 5410 psi, @ 85%: Pcollapse85% = 4598 psi ASSUMPTIONS: . Maximum injection pressure, P Applied = 1500 psi . Maximum density of injection fluid is 12.0 ppg. . Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft . Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULA TIONS: Maximum pressure at 9-5/8" shoe: Pmax = PHydrostatic + P Applied - PFormation Pmax = 12.0 (0.052) (2364)+1500 - 0.4525 (2364) Pmax = 1905 psi Maximum fluid density to burst 9-5/8" casinq: Pburst85% = PHydrostatic + P Applied - PFormation 2992 = MWmax (0.052) (2364) + 1500 - 0.4525 (2364) MWmax = 20.8 ppg Maximum Fluid Densitv to Collapse 7" Casinq: P collapse85% = PHydrostatic + P Applied - PGasGradient - PHeader 4598 = MWmax (0.052) (6882) + 1500 - (0.1) (6882) - 2000 MWmax = 16.2 ppg f { (fIPHILLIPS Alaska, Inc. Casing Detail 9518" Surface Casing Well: CD2~34 Date: 12/19/2001 A Subsidiary of PHilLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LOS 36.60 FMC Gen V Hanger 2.20 36.60 Jts 3 to 55 53 Jts 9-5/8" 36# J-55 BTC Csg 2243.37 38.80 Davis Lynch Float Collar 1.55 2282.17 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 83.33 2283.72 Davis Lynch Float Shoe 1.76 2367.05 9- 5/8" shoe @ 2368.81 TO 12 1/4" Surface Hole 2375.00 RUN TOTAL 32 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52 Last 13 joints stay out # 56 thru # 68. Use Best-Q-Life 2000 pipe dope Remarks: Up Wt -152k On Wt - 148k Block Wt - 75 Supervisor: David Burley ~ ...... ~'PHILLlPsl m ~ ( l ..~ PHILLIPS ALASKA INC. Cementing Report Page 1 of 3 Legal Well Name: CD2-34PH Common Well Name: CD2-34PH Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/13/2001 1 Report Date: 12/19/2001 12/11/2001 End: -----------------.---- -----.-----.---------- Cement Job Type: Primary -.--.--- ---_!:!.~.æ§.!Y.__._-_._- -----...--.-.-..-.- -..--..---.-§g -y~ e ~~_QQ~DJ:!Q!~- .---- --.--- ---.-- --_._-_._-§.g.y~-~~~-ç a slD.9_.__...- --- --. - -----------.- ..--..._._PJ.Y9____..-.--- -... Hole Size: 12.250 (in) Hole Size: Hole Size: Hole Size: TMD Set: 2,369 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 12/19/2001 sa Date: Date Set: BTM set: (ft) Csg Type: Surface Casing sa Type: Csg Type: Plug Date: Csg Size: 9.875 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start: Time End: Time End: Cmtd. Csg: Pipe Movement Pipe Movement: No movement Cementer: Jim Thompson RPM: SPM: Init Torque: . (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Max Torque: (ft-Ibf) Drag Down: (Ibs) - .--"---.....-....,,-.,,-.,,--...,,,-----,,-.-,- ,--_._--"._--"-".._,,--,,. -,--".- ,"".---------,-----,--------..-...-.-.-.-.-..,----..-,,-.- ,---"".. ".... -".".----...---.-..-.."..-,--"..--'-.-..--.--...-- ..-,,--.-,----,.-..-----.,-.-,..-.-..-.,----,----,-..-------.,-.,--."----,..-....-,."--,,--.,,..-,,-.,,,..- -".. -.... Type: Cement Casing Volume Excess %: 130.00 Meas. From: Time Circ Prior To Cementing: 1.25 Mud Circ Rate: 336 (gpm) Mud Circ Press: 320 (psi) Stage No: 1 of1 Start Mix Cmt: 11 :54 Start Slurry Displ: 11 :56 Start Displ: 12:42 End Pumping: 13:08 End Pump Date: 12/19/2001 Top Plug: Y Bottom Plug: Y 8.00 (bbl/min) 10.00 (bbl/min) Y 440 (psi) 900 (psi) 2 (min) Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: Mud Data Returns: Full Total Mud Lost: (bbl) Cmt Vol to Surf: 97.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: densomitor - Type: Spud Mud Density: 9.6 (ppg) Visc: 40 (s/qt) Bottom Hole Circulating Temperature: ("F) Displacement Fluid Type: Mud PVIYP: 13 (cp)/14 (lb/100ft2) Gels 10 sec: 6 (lb/100ft2) Gels 10 min: 7 (lb/100ft2) Bottom Hole Static Temperature: 50 ("F) Density: 9.6 (ppg) Volume: 178.00 (bbl) Stage No: 1 Slurry No:1 of4 --."-...--,,------..-.---,,..-.-------.---.------..-.----,.."",._-" -" --.,,-...... ,-".-."-...,, -. --..,,- ",,-.-...-....-----. ---."u,- .......-----..--,----,,--"-,,--..-..---......--------u..---..---.""..-..-,,--.--.,,- """--.-".'."--."..""....""""""-."'---. -"."-"----..-....-,,..--.,,....---.....-.-.---- - -- - Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) To: (ft) Description: 40 bbl gel w/ marker Cmt Vol: (bbl) Density: 8.40 (ppg) Slurry Vol: (sk) Water Vol: 40.0 (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Temperature: ("F) Temperature: ("F) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 12/27/2001 10:55:33 AM ( ~ ....... ~'PHILLlPS~" mJ ~ Legal Well Name: CD2-34PH Common Well Name: CD2-34PH Event Name: ROT - DRILLING ( PHILLIPS ALASKA INC. Cementing Report Page 2 of 3 Report #: Start: Spud Date: 12/13/2001 1 Report Date: 12/19/2001 12/11/2001 End: Stage No: 1 Slurry No: 2 of 4 _.._.._--_.._-------------_.._-------_._------_..~..._-..-.--...-..----.....-.-.---...---.-----.---.--.-.-----....-.......-..-.-...----..'--.-'--'--'---"'---'-'--""'--'-"------ "--.-....-.-.-"'" .---------. Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: ARCO Cmt Vol: (bbl) Slurry Vol: (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: CF) Temperature: (OF) Temperature: CF) (OF) Class: Density: 10.50 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) CF) Stage No: 1 Slurry No: 3 of 4 Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) _-----0._-.'.--------'..--'--------.'-'---."'--'-..'.'..--.---,,- ......._..._-.._.-.-...-.- ----'-.--"--"'-'-'--'-" -"'-"..'--.' -"""--"""-'--.--'---'---'--..--.--.-'---'.'--'--' ..-........"'."".'.-'---..--'--...-..----..--.-'--'--'---.----.-.---....-...-......-...-.---.-'.-'---'-.'----'-"'---'.""-----..-'--' -- -..-.-- -. ..- Slurry Data Fluid Type: LEAD Slurry Interval: 1,869.00 (ft)To: 36.00 (ft) Water Source: Description: AS Lite Cmt Vol: 260.0 (bbl) Slurry Vol:333 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: CF) Temperature: CF) Temperature: (OF) CF) Class: Density: 10.70 (ppg) Yield: 4.40 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp CF) CF) Stage No: 1 SlurryN6:4 of4 c Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 2,369.00 (ft)To: 1,869.00 (ft) Cmt Vol: 50.0 (bbl) Water Source: Slurry Vol:242 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: CF) CF) Class: G Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: PRIMARY Mix Water: (gal) Foam Job: N Pressure (psi) (psi) - Purpose: TAIL Mix Water: (gal) Foam Job: N Pressure (psi) (psi) - -----.-'.'-'-.---'---------'."'--'-------------------.'-..-.--.--..--- ---.-.....-""""-'.n' . Printed: 12/27/2001 10:55:33 AM ( (' PHILLIPS ALASKA INC. Cementing Report Page 3 of 3 Legal Well Name: CD2-34PH Common Well Name: CD2-34PH Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/13/2001 1 Report Date: 12/19/2001 12/11/2001 End: Casing Test Shoe Test Liner Top Test ------------------- ------.---.---.'----------".'-'---'.-.----.------- .-..-...-..----.-----.---.-.---.----.----.--..--.-----------"'-----------------------'.-'-""-------'-"----'-- -.. Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 15.50 (ppge) Tool: N Open Hole: 26 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) N - --------- --.- ----. '.-'.. .- .-. __un. .------ ---------.-.-...---.----.--..- - --..-----.-.--.--...-..- ---.--- -- - ---.--.-.-.------.--.-.------ ----.- .---.- ---------.----------------------- .-."-"- .----------. -- --- -- -..--..-.----...-.-.- - '---. --' . .. . Remarks - . . -.--.-.----------------------.-..---------.-.----------...-.------..---.--...-------------.-.-..--.-...----....---------.---...-------.-..-.--.-------------..--...--.-.---.------------.---..-.--.---.-.-----..---..--.---.------- __..h._'___. ..-- ...-- .-. Reciprocated casing while conditioning mud, intermitant overpull 5-10k (metal to met al) with hanger two feet above landing ring. Discontinued reciprocation at start of ce menting operations after several attemps when 25k overpull encountered at same spo t. Displaced cement at 8 bpm untill tail at shoe, increased rate to 10 bpm first 30 bbl s of tail around shoe, staged rate down to final of 4 bpm. Circulated 97 bbls of 10.7 ppg cement returns to surface, full returns throughout. Annulus stood static at flowli ne after plugs bumped. Printed: 12/27/2001 10:55:33 AM (' ,.c- ,~ ~ ..... " "- ~ fJHILLIPS 1 ~ lj,~) -.,- Page 1 of 2 Phillips Alaska, Inc. Daily Drilling Report : JOB NUMBER: EVENT CODE i 24 HRS PROG TMD ITVD I DFS ! REPT NO. , DATE CD2-34 : ODR I 2.375.0 2.370.0 I 3.00 I 4 ;12/19/2001 SUPERV~~~e Burleï____HtIG N~;. ~~~~'@PPÇ9_'~9_Œ!_~_~I_~L._D.TNAME ~O.IP~~:O' ------- ~-~~~,~-_._LY.TA~Goo -¡c. _L.~'_T~... N;.Q.Q__- - CURRE~_T STATUS ------ . I ACCID_~NTS LAST 24 HRS.? -- DAILY (NT W~~q~:______I:UM.~~T_~~~~~~D_-- ~~:~~~E~~~l #~'_1~~LC~_9:...<:!@.2. U. t -~[!11.J~_EJI-,-gdll?_::JŒJ:' ho Ie_.. ---_J:T~~~ï~A.~~ ;;~;~~~~=~:. . . DAIL Y~~_;~L?-,-}_~. --- .'.~-~~:~~. ;.--~~~- '-. "'.- LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE AUTH. 998010 3,476,695 ~S~l~~~;;;- DA ~~ 2!~~~.~~ ---~-- --;:~Q---~~=~~~--"~l~~~9~~S~~=;~-__1 ~:~~ŒLJ~;~;;;~~~~~----~.~00~9__l~1~_- L~:_~OP ~R~S~~~~~~-~ . ~~- . -cENsrrv-¡ppg) 9.60 Tpp-r---------- Ec[)l--TïVïUD -DÄiAFDAIL~¡COSTr-o.OO------r- CU-M-COST-r.--O~OO----'- FV PVIYP GELS WLlHTHP FC/T.SOL OILIWA T %Sand/MBT Ph/pM Pf/Mf CI Ca H2S LIME ES 40 13/14 6/7 12.8/ 2/ / /22.5 9.0/ / WELL NAME BHA NO. I 1 ¡ BHA WT. BELOW JARS STRINGWT. UP BHA I HOLE CONDITIONS i BIT NO. I 1 STRING WT. DN STRING WT. ROT TORQUE 'UNITS BHA LENGTH I ft-Ibf 993.77 NO JTS LENGTH O.D. I.D. CONN SIZE CONN TYPE I I ITEM DESCRIPTION ._-_no_- ----______n .. -.___--__n_____..... n __n__..___------ ..-. Bit 1 1.00 12.250 Navidril Mach 1 C 1 28.82 8.000 -----------__.___n______-----------------------'------"--.._-- -.------..-.....-..-..-.---- ---.-..--- -----. -...-----.---.-- --.--.---.- -- --..... XO 1 1.30 8.000 3.000 ----.---.---....---------.---.-.-.---.-.--...--..--------- -..-----.-----.- ____unO' ---.-.--..--- --.. Drill Collar-Short NM 1 9.92 8.125 3.000 ---------.-------.-..------ - ----- H'____"-.-.-"'" . .... Stabilizer - No~~~1l._-------------_._-_._------------------_..___1 5. 75____8.06~- ___~~~5 -- ---------- --.---------- MWD 1 30.37 8.063 1.920 --.-----------"---"'---."---.'-----'--'--------'" ....-----------.-- -----..-------- -----.------- -.--..-.-.----.-.------ ------------.-.--- ---.--..-.......-----..-..- - - UBHO 1 3.27 8.065 3.000 --------- ----.---- --------- ---.----- ---.--.-----' -----. ---.-.-.---..--.-.--.-- ----..-..------..... - _n Drill Collar - NonMag 1 30.62 8.065 2.875 --- .---- _un' -- ---------.......----. .. Drill Collar - NonM~~___--_._._--------------------_._._..._...._---._---- ---_._-_.~-_... 30.53 8.065 --- 2.8~~___- --------.---------------..--..------ Stabilize~_~~onMag _._-------------------------_...._-_._-~---_._---_?6..~-_. ------ 8.065______-_.--~.:.~~§-----------_.._-------._----_._-_. Drill Collar - NonMag 1 31.07 8.065 2.875 Crossover1 3.65 6.500 3.000 Drill Pipe - Heavy Wgt 3 88.34 5.000 3.000 Jars - Up/Down Jars 1 33.40 6.125 2.250 Drill Pipe - Heavy Wgt 23 690.10 5.000 3.000 ...------....-------------'-'-'----'o- -'o- . BITS SERIAL NO, i -:- JETSORTFA P67 JF I 12/12/18/1 all DEPTH IN DATE INI.O.D.L-B.G,O.R 104.0 12/17/2001 3-3-RG-A-E-I-BU- TO . BIT I RUN' : SIZE !MANUF. TYPE 1 I 1 I 12.250 I HUGHES-CHR MX-C1 ------------------'-----"--'-----'------------------'----"-------"'-----'----"---------.-------'------ ..-"'.' -- ..... -. . . .. . . .. .. .. .BITOPERATIONS. . . .--.-.-...-.-------.-,.....--....------.....,.......-.....-.....-.-.....,.-...-........-.....-............ "-.'.-'."--""".'----"-'-""----'-'------.-'-.j'-"".-.'-""".-""---.--- '-".'--'----"-'-.'r-----""'.--""-.'-"".""-".I."'--'--'--"---'-.1""'."-"'..."'-"'.-"""'--'[.'--'-""-"---'-"-"."-',-'-"-.-."'-"" . ...." BIT I RUN ". WOBRPMGPM I PRESS P BIT HRS . !24HrDIST '.' 24Hr ROP . CUM HRS CUM DEPTH: CUM ROP ----1T--..--11".---'¡.O/3C¡-"--:¡'63-/ 223 -.-'--588---.' --'-2~ 100 -- ---1-:O25---I~--J'-_.--'-'¡~69~4ã-----~13.40 .----'-2-;271-:Õ~-----1-69'.-4¡3.--' _._---------~_.L L___.-- ------ - - L 1_._____L______--..--.. '-"'-.--' - - ----.--..------------'--.'-----'--'---'--'-"'--------'------_......----- . . ----".-"--...-..----'-----" ---..........._-- On' OPERATIONS SUMMARY.'.." . . IR~~:=~O- -'H~~~~.__. ~~~ ~.~-~~~~]~~..?~Bi.~_-"-'..~~!_-. '-- :~~ -" p.B~_~:~~::==~~~:-~ .~~:~:::-'=----=~..:-~~:~=:::~'::=~~~!~~I~i~~:.-- ~:=-::=::~~==~:.~.':.-..'.-:::.:- --_.'.-:.:..--.: .-- -' 00:00 01 :00 1.00 DRILL P TRIP SURFAC P 0 H, s tan d b a C k H W 0 Pan d 8" coil a r S ----- 01 :00 02:30 1.50 DRILL P PULD SURFAC L 0 M W 0, X 0 ' S, S tab, bit and mot 0 r .. . -- --- -.----.- ------- ....-- 02:30 04:00 1.50 CASE P RURD SURFAC Rig ups lip s, e I e vat 0 r s, ton g S, C h a n g e 0 u t t 0 Ion g bails to run 9-5/8" casing SFTY SURFAC H e I d pre job sa f e t y and 0 per at ion s me e tin 9 RUNC SURFAC Ran 55 j 0 i n t S 0 f 9 - 5/ 8 ", 3 6 # , J - 5 5, B T C M U h a n g er and landing joint, landed casing with shoe @ 2369', FC @ 2282' PULD SURFAC L 0 fill u P too I , M U C em e nth e a d ------------- 04:00 04:30 04:30 09:30 0.50 5.00 CASE P CASE P 09:30 10:20 0.83 CEMENT F Printed: 12/27/2001 10:52:25 AM ( (' ... .... -""" ,. " ~ flHILLlP:S 1 t ",",, '~ ) Page 2 of 2 Phillips Alaska, Inc. Daily Drilling Report WELL NAME : JOB NUMBER I EVENT CODE i 24 HRS PROG ITMD ITVD DFS i REPT NO. DATE CD2-34 I ODR 2,375.0 2,370.0 3.00 I 4 !12/19/2001 OPERATIONS SUMMARY FROM TO I HOURS CODE TROUBLE SUB I PHASE I DESCRIPTION I I ' 10:20 11:45 1.42 CEMENT F CIRC SURFAC Staged pumps up to 8 bp m, 340 psi C i r c and con d mud , reciprocated casing 25', full returns throu ------ ------ --.-._---..--- --..--------- ------------ . ------- g h ~_.~.!..'_£~ S M ~-------_._--------------- ---..---.---.--.--..- u.- 11 :45 12:45 1.00 CEMENT F PUMP SURFAC Pumped 40 b b I s of Biozan spacer wi t h nutplug ma r k e r, test cement Ii n e s to 2500 psi Pumped 50 b bls of 1 0 .5 ppg ARCO Spacer, 260 b b I s of 1 0.7 P ----- --------- ------------- -----w---- .- -- -------..- ..--- ----.- --.----- ""_H_'_'__- -'" p_-~-_!~~~_._~--~~--~-~__~_~L~__~_L--~_:_~._.P2JJ.--!_~!_~-£~-~~..n- t. u- 12:45 13:30 0.75 CEMENT F DISP SURFAC Dispalced cement wit h 20 b b I s FW and 1 58 b b Is 0 f mud at 8 - 1 0 b pm. Bumped pi u g s , floats he I d , an nul us static, full returns d u r in g job wi t h 97 b b I s of 1 0.7 ppg cement returns to surface. CIP @ 1 3 08 hrs, ETOC @ 2255' 13:30 14:30 1.00 CASE P RURD SURFAC Flu s h surface equipment, LD cement head and la n din g joint and running too Is. 14:30 20:30 6.00 CASE P NUND SURFAC N 0 Divertor system , N U wellhead and t est mlm s e a I to 1 000 psi N U BOP Stack. 20:30 20:45 0.25 WELCTL P SFTY SURFAC PJ S M 20:45 00:00 3.25 WELCTL P BOPE SURFAC RU and t est BOPE , 250/5000 psi , annular prevent ------'---'-"--' ..----.- .--.---..--- ---- ---------.--- _._-_._-_.__....._-~~""?'.?_QL~~q_g.__e_~J_.'_._.._._---_.._.-----...---.------------...--.----. ...---. ". .... --..-.---. -"'.---"-----------------.'--"'-'----"'- --..----. .-..- .-.--...-..-.....-....-....- .....----..-----.,,-.- --.-- '-."----------.--"'--.'-'-----------'----."---"-----'--"--.----- - -..----. "-'-" - ~4 ti.~ S U M.~~Rr:__~.Q_':I_~-~~.~--~~~--~~~~_~L su!~ce 9~-~~1h..~~-~~_.@_~~6~~:_N q_Qivert°E~~_l¿_well~_~~<! a~_~__§.~~-§..~~~:_!~st B2~E. --------.-...-- "--'-"-"-"- ------'-------'.----. . --. .-..-..-----.-......--.-.."-."'----""----.'---'---------.---.-...-------- -....--.-..-.....--,,-----..-.--............-. PERSONNEL DATA . "-"--'---.-.""'--'-----'----'.""'------"."""--'. "-"-"-.--"'.""" --""-"--'.,."'---'.'-.. --....-------....-¡--."..-.......--. ..--..-.. -----,,"'--'.'..'-'--.. ------...'.'-".-"-."-'---.----.-"----"."'-""-"--".- -----...--.-----------'.....-..----..-;-- .---"'-"---"-""0"-'."'----'-'."'.-"'-""'-'-"""'-..""'.. .'.. ,. COMPANY SERVICE: NO. HOURS¡ . COMPANY SERVICE. ' NO. HOURS ....-.----.-.----........-....--......-.-".-.....-"'.'. '-'..'-'-'.'.'---""'--.""'--"-.'-.'---"'.--'..----.'-'........ ..-..........-...,,-- .-...,,--...'-.---"'-'.'" ---.----.-..-.'----..-....-.-.-------'-.--.---.. .-...--.." ._"_...,,........_,. .."."-,,..----..----.--.. .----.-------". ,,' ...-."""'.""" -"--"- _~_hillip~_____._------- 2 Sperry Sun 3 -------._- ---------"---- -....--....----- __n-__- .---------..-. ..--- ..-. .--- .---------.-".-. Doyon 26 DSR 4 - -..--- .--------.-- -------------..-- -- -----. ----..-.-- """'-""'------"-'-' _Baker InteL__.___--.--,,-- 2 Catering 5 -- --- --,,_.,,--_._- ..--." --,,--..-. ------_._----,,------ ,,---- --.--.-.-----.. Dowell 2 FMC 2 MI Drilling Fluids 5 . . . MATERIALS ¡CONSUMPTION ITEM UNITS USAGE ON HAND I ITEM UNITS USAGE ON HAND Fuel gals 2,628 I -7,088 Water, Potable bbls 120 -325 Water, Drilling bbls 394 I -1,308 . SUPPORT CRAFT . . TYPE NO; REMARKS TYPE NO.. . REMARKS CD2-4 7 L 1,858 CD2-34 ._-_.._..J ---_._-,,----- .---".-----...--,,- ---,,--,.---------,--,-,,-'--"-"""'.-"'- -. Printed: 12/27/2001 10:52:25 AM CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-34 Date: 12/20/2001 Supervisor: D. Burley Reason(s) for test: 0 Initial Casing Shoe Test D Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8",36#, J-55, BTC CSG Casing Setting Depth: 2,369' TMD 2,364' TVD Hole Depth: 2,395' TMD 2,390' TVD Mud Weight: 9.5 ppg 26' Length of Open Hole Section: EMW= Leak-off Press. + Mud Weight 0.052 x TVD 740 psi 0.052 x 2,364' + 9.5 ppg = EMW for open hole section ::: i 5.5 ppg Used cement unit Ria pump used NO #2 Pump output = 0.0997 bps Fluid Pumped = 0.9 bhls Fluid Bled Back = 0.7 bbls 3,000 psi 2,900 psi 2,BOO psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi W 1,BOOpsi I 0::: 1,700 psi I ::J 1,600 psi ~ 1,500 psi W 1,400 psi 0::: 1,300 psi a. 1,200 psi 1,100 psi 1,000 psi 900 psi BOO psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 ! ; ¡ I I - . I~-~-" 1 .-A.-A.' I I J I I I j .. ........ ¡¡~! ! ! III ¡ ¡ ¡ II -# .-+~-~~~A.-t; -......; TIME LINE ONEMINUTETICKS F 'A.' -+- LEAK-OFF TEST ~CASING TEST "'" LOT SHUT IN TIME -.-CASING TEST SHUT IN TIME '"""'f- TIM E LI N E I J T I T 40 50 10 20 30 STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above MnrlifiArl hv Sr.ntt RAvnnlrls FOR FOR lOT STROKES PRESSURE CSG TEST STROKES PRESSURE r-- -----------T---- - --Õ- ---- - -r----õ--p-si - --- 1 r-- - - ---- - - ---- T ---Õ--Š tkš-- - r -- --õ--p-šT ---1 ~-------------- +------ - ------ - -}- ---------------.{ ~----- ----- - ----+ ------ ----- ---+- - ---------- - --- ~ I I 1.0 I 70 psi' ; ; 2 stks ; 150 psi I .---------------+---------------.- ------------.-~-t;- qr----- - --- - -- --+ --------- -- - --+- - -------- - --;----1 L--------_____L__--~ :~___---L_~_~_~-p"~_I_~ Q¡--- --- --- - -- - _l---~-~ !~~- --1. --~-~QJ?_~ ~___l ! ! 3.0 ! 240 psi; : ! 6 stks ! 625 psi ¡ r--------- -----r---4~Õ--- ---r---3Š-õJ)st>1 \ \ ~------ - --- --- --r--ã-stkš- --r- -ã-6()p š 1--"1 r----------- ----..,.------ - ----- --- r- --------- ---~-r r------ - - ----- -- ..,..--------- ---- -..,. -------- -- - --- --~ : : 5.0 : 460 psi ;\ '0 : 10 stks ; 1,030 psi: .--------------- +------ - ---- - --- .-------------.--~ ~-------- - ---- -- +------ - -- ---- - +--- ----- ---- - -.---1 : : 6.0 : 560 pSI ,100 I 12 stks ; 1,190 pSI I t---------- -----i"------- ----- --- t----------- --.-- ~ l "---- ---- - ------ 1'"------ - ------ -1'" --- --------- --.-- t : ; 7.0 : 670 pSI I \ P : 14 stks ; 1,370 pSI: r-------------- -T----------- - --- r --------- ----.--~ t---- - --- - - - ---- T------ - -------T- - ---------- - -.--1 ; ; 8.0 ; 760 pSI, o.¡o : 16 stks ; 1,570 pSI I r--------------r----9~Õ------ r ---ã"2-õ- psf-Y: ~ 0--- - --- -- - ---- rTã- stï< š -- r -.¡ Jã-Õ-psT 1 .-------------- -+----- -- ---- ----. -------- - --- - --- of .---- - --- - - - ---- + ------ - ------ - +--- --------- --.---1 ; ; ; : ; ; 20 stks ; 2,020 pSI: L_------------ --..1------ ---- ------"--------- --- - ---.. L--_- - --- -- -----..&. ------ ----- - - _..&.-- ----------- --- 4 ! ! ! ! ! ! 22 stks ! 2,280 psi ¡ t------- - ------....--- - ---- ------t---------- ------.. t------ - ---- -- - -of- ------ ------ - - of-- -- ---------- ---. ! ! ! ! ! ! 24 stks ! 2,500 psi! r-----__n- ----- ..,.----- ------- - -r---------- ---- - --r r------ ------- - -..,.. --------- -- - --..,..- - - ------- -- - --- ~ I I I , , I , I I I , , , , , I .---------- - ---- +------ - ----- ---t- --------- - --- - -of ~- ------------ - - +--------- - - - --+ - - --------- ------1 I I I , I , , , I , , , I I , , L------ --- -----..1------------- ---"----------- --- - -.. "-------- - -- - - - - ..&.------ -- - - -- --..&. - - -------- - --- --4 I I I , I , , , I I , , I , , , I I I , I I I , t---------- -----....------ ----- - ---t----------- --- - -.. t----- - --- ---- - - of---------- -----of- --- - ---- -- - -----. I I I I I I , , , I I I I , I , I I I I , , I , r---------------""----- - --------r-------------- - --r r------ -- - ----- -..,.------ --- - -- ---.- ----------- --- --~ I I I , , I I , I I I I I I I , .-_n_- ---------+------- ---- - --- .-------- ------- -of ~---- - --- - ------+------ - --- --- -+ --- ----- -- --- - ---I I , I I , , I I , , I I I , , I L---------------..I---------------- "-------- - ---- ---.. L----- --- -------..&. ------ - --- --- - ..&.--- ----- - --- -- --4 , , I , I , , I , , I , , , , I , , I , , , , I t--- - --- -------....---- - ---- ---- --t ----------- ----.. , , I , I I I , , I I , r-------- -------..,.---- ------ -----r -----------------r I I I , I I I , .---------------+--------- - ---- -.---------- ------of I I I , I I , , L------_--_n--_.................................4................................1 I I , , I I , , I I , , LEAK-OFF DATA MINUTES I ~ ! SHUT IN TIME! SHUT IN PRESSURE r---------------""---------- -- ----- ------------- ---, : 0.0 mÎn : i 820 psi! .---------,----+------- ---- - ---.--------- ----.--- of : 1.0 mm : : 710 pSI: L---------------..I----- --- ---- ----" -------- ----- ---.. i 2.0 mÎn ! ! 675 psi! t--------------....---------------t------------ - ---.. ! 3.0 mÎn ! ! 660 psi! r-------- -------..,.---- ----- ----- -r------- ----------r : 4.0 miD : ; 650 psi; ~----------.---- +-------- - --- - -.------- --- - --.- --of : 5.0 mm I ; 640 pSI I L------------ --- ..1----------------"- ------ ---- --- - -.. ! 6.0 min ! ! 630 psi! t----------- - ---....-------- -------t- ------------- - -.. ! 7.0 mÎn ! ! 620 psi! r--- --------- -- -..,.------- ----- ---r- ------- - --- -----r : 8.0 min ; : 610 psi; ,------------- - -+-------- --- - ---. -------- ---- - --- of ! 9.0 miD : : 600 psi; C}~9~2~~J~ ~I~~~~~~~ ~~~ ~~~~ [~~~~Q~~~ e~C] r- 60 ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROlEUIv1 Cav1PANY CASING TEST DATA MINUTES ..- ! SHUT IN TIME! SHUT IN PRESSURE r------ - ------ - -..,..----------- - ---,-- - ------- ---- -:-- ~ ; 0.0 miD ; ; 2,500 pSI I ~------ - - ---:-- - -+------ ----- - -- +- - - ------ ---- -.---1 ; 1.0 mm ; ; 2,490 pSI: ¡---2-.Õ -ñiìñ - - r-------- - - - -1- 2~4ãõ- psT 1 t---- - --- - ------ of----- ----- - -- --of-- --------- ---- --. ! 3.0 mín i ! 2,470 psi! r---- - --- -------..,..- ------ -- - --- -..,.. --- ----- - -- - -- --~ ; 4.0 mín ; ; 2,470 psi I ~---- - ------: ----+ ------- --- --- - + --- ------ --- --.---1 ; 5.0 mm : ; 2,470 pSI I L------ - ---- ----..&. ------- ---- --- ..&.--- ------ --- - --- 4 ! 6.0 min ! ! 2,470 psi! t------ - ------ - -of- ------- ----- - -of---- ------- -- - ---. ! 7,0 miD ! ! 2,460 psi! r-_n-- - - -- --- - -..,..------ ----- - -- ..,..-- -------- ------ ~ : 8.0 min : ; 2,460 psi; ~----- --- - --:- --- +---- ----- -- - --+ -- ---- -- -- - ---.---1 : 9.0 mm : I 2,460 pSI: L---- - --- ---- --- ..&.---- ----- - - - - -..&. --- ----- -- - --- --4 ! 10.0 miD ! ! 2,460 psi! t----- ------ - ---of- ------- - - - --- - of---- ----- - --- -- --. ! 15.0 miD ! ! 2,460 psi! r---- - ------ - ---..,.. ------- --- --- - ..,..--- ------ --- - - --~ ; 20.0 min : ; 2,450 psi I ,------ - ---- -- - --'- ------ - - -- -- - - +- - - ---------- ----I ! 25.0 min ! ; 2,450 psi I t--~-O-- _0---- ~ - --1'" ------- --- -- - - 1'"- _2- _4--5--0--- - --.-- t L-::,-- ~- --~1] ~ ~-l---------- --- - 1. --- 2____- -P.. ~L 1 ~., NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY , , (' . Casing Detail 7" Intermediate Casinq Well: CD2-34 Date: 12/26/2001 Phillips Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 35.20 FMC 11" X 7" Hanger 2.32 35.20 Jts 3 to 190 188 Jts 7" 26# L-80 BTCM Csg 7676.62 37.52 7" Davis Lynch Float Collar 1.42 7714.14 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 84.48 7715.56 7" Davis Lynch Float Shoe 1.73 7800.04 7801.77 8-1/2" TD 7812.00 1 straight blade centralizer per jt # 1 thru 20, then every other jt. from ]t8. # 134 to # 188. 48 total centralizers Use Best-a-Life 2000 pipe dope Remarks: Up Wt ::: 270 On Wt: 190 Block Wt: 75K Supervisor: David P. Burley ( ( PHILLIPS ALASKA INC. Cementing Report Page 1 of 2 Legal Well Name: CD2-34PH Common Well Name: CD2-34PH Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/13/2001 2 Report Date: 12/29/2001 12/11/2001 End: 1/1/2002 Cement Job Type: Primary ----.. -----_.~_.... -..------.----------..'___--_0_------'.- --------------.-.-- -----------------------.. ----- ---... --_._----_.___.P.~Lf!1.~_~...__._..._-_......_._._---- ._--------_o_§9!1.~~~~-QPI?r:!_tl2L~_._._.._.__._.... __~ueeze Casing_____-- ------_..J:~_!L_..._._._,-_....__.... Hole Size: 8.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 7,802 (ft) SO TMD: (ft) TMD Set: Top Set: (ft) Date Set: 12/27/2001 SO Date: Date Set: BTM set: (ft) Csg Type: Intermediate Casing/Li SO Type: Csg Type: Plug Date: Csg Size: 7.000 (in.) SO TMD: Plug Type: SO Date: Drilled Out: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Cmtd. Csg: Pipe Movement Pipe Movement: Reciprocating Cementer: Jerry Culpeper Rot Time Start: : Rec Time Start: 09:45 Time End: : Time End: 11 :22 RPM: SPM: 40 Init Torque: (ft-Ibf) Stroke Length: 40.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 275 (Ibs) Stage No: 1 of 1 Max Torque: (ft-Ibf) Drag Down: 200 (Ibs) _"__0'0".""'.-'""'."""-.--""."_.'--_0__""_"-.'-'.'.......,._- -,---.. ..,- ."._"..0...._."-,,--,,---,--,,,,".'-' .--......---... .-...--..-...................... ....0 .."n....--_....-... "-"-'.-'-"-"-.'.- "'-"""-"'.""-."'.---."""'__.0_0____'_-----.."" ._. 0 .-'. ""'-"---------."----'.'."'0"""""""""". ."".-"--'.".--"'.'" .. .0... ..... ... Type: Cement Casing Volume Excess %: 40.00 Meas. From: Time Circ Prior To Cementing: 1.50 Mud Circ Rate: 168 (gpm) Mud Circ Press: 450 (psi) Start Mix Cmt: 09:57 Start Slurry Displ: 09:59 Start Displ: 10:08 End Pumping: 11 :20 End Pump Date: 12/27/2001 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.00 (bbllmin) 7.00 (bbl/min) Y 640 (psi) 1,250 (psi) 2 (min) Y Mud Data Returns: Total Mud Lost: 270.00 (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: densometer Type: Non-Disp. LS Density: 9.9 (ppg) Visc: 39 (s/qt) Bottom Hole Circulating Temperature: 110 (OF) Displacement Fluid Type: Mud PVIYP: 6 (cp)/17 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 7 (lb/1 DOfF) Bottom Hole Static Temperature: 158 CF) Density: 9.9 (ppg) Volume: 295.10 (bbl) Stage No: 1 Slurry No: 1of 3 -._0_.....__0"_"'-_'0...-----..--.."..--..--...._..._...0.......'"_... ...---------- .-.---.. ...-.........."...... -.."..."."-'" .0'__._....--.----..---..-'-"-'" --"-------"-'--------""-"'---"'--'_'_--_0__"__.--'-'---_0_____"-.'-"'-------"-"----"."-""""- ,."""',, Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) To: (ft) Description: ARC a Wash Cmt Vol: (bbl) Density: 8.40 (ppg) Slurry Vol: (sk) Water Vol: 20.0 (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Temperature: CF) Temperature: CF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) CF) Pressure (psi) (psi) Printed: 2/4/2002 8:57:13 PM ( .f \ PHILLIPS ALASKA INC. Cementing Report Page 2 of 2 Legal Well Name: CD2-34PH Common Well Name: CD2-34PH Event Name: ROT - DRILLING Report #: Start: Spud Date: 12/13/2001 2 Report Date: 12/29/2001 12/11/2001 End: 1/1/2002 Stage No: 1 Slurry No: 2 of 3 --------------'-------------'---------------"----------.----.--..--------..---.--.-..--."-.-.--"'----.----------------..-----..--..---------.-----...--..-...----...---.------__m____._-'--"""'.""-----"-'----" _..- . --... Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: ARCO Spacer Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: eF) Temperature: (OF) Temperature: eF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) eF) Pressure (psi) (psi) (OF) Stage~No:1SiurryNö:3of3 . . . ...---..---------------.....---.--.--..--.-- ,,"----'.'-'----".-'------------'--'--.--------'-"--" .-... -"----_". -- '-------."--'-.-'---'--"'.--'-"""'--'---..".-'-"- ------------"'.'---"-.--".'."-'-----"'---------'-.'--'----.." ..--.------.-----------..-.----.--.--.------- ---.--.--.----.---- .. ."...' Slurry Data Fluid Type: TAIL Description: Slurry Interval: 7,802.00 (ft)To: 7,040.00 (ft) Cmt Vol: 32.5 (bbl) Water Source: Slurry Vol:158 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRI MARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: eF) Temperature: eF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp eF) (OF) Pressure (psi) (psi) eF) Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 12.40 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) N Remarks Pipe ran well until! 7147', lost returns from hole. Reciprocated pipe throughout. Printed: 2/4/2002 8:57:13 PM ( ( Page 1 of 2 Phillips Alaska, Inc. Daily Drilling Report i JOB NUMBER I EVENT CODE 124 HRS PROG TMD TVD DFS I REPT NO'1 DATE CD2-34 I. ODR 7,812.0 7,199.0 11.00 I 12 112/27/2001 SUPERVISOR RIG NAME & NO. i FIELD NAME I OCS NO. AUTH MD DAILY TANG i CUM. TANG ---_.____Q?Vid BU!l~Y___~-__Q.Qy'()nl@PJ:>co.com 19 ._~----- AI ine __1Q.Z69.L- 0.OQ--_.---.L_~.:90 ---.- CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD CUM INTANG WI MUD MU BHA #4. J^~E 0.00 0.00 ----.-----.--------...------ -.--- - ---------------.---- --'--""'---------'--'-' .--. 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD ÙTHOLcj~-YE.ha,BIH,~st ""9,,, d.rill.£r~~s.d~JL;-.:*~c.hE<?~.~AHRS SINCE INS-:].-' Y~~~~~Ol______---- AFE-.---1. 9. 5,613. ---. .-- -AUTH.-__1..~51'_~1_?___-. L 15.46 998D10 3,476,695 -LAST SuRVEY: -OA TE.-iMC--------------INC. ------ --. --AZIM-----.- --Fj-ST CASING -- ----lNEXT CASING--------'--------- LAST BoP-PRES TEST--- - - __J..?L25/2Q01___._____.?:J57 ~--__§_~J30 ---_1_~~.2~.Q___L9.625_@t@_~.369.0 illLLZ:9_9.Q_@L@__7,768.0 @ 12/27/2001 WELL NAME DENSITY(ppg) FV PV/YP 39 7117 10.20 PP GELS WLlHTHP 7/8 4.8/10.2 FC/T.SOL 1/ ----.----- -.--- - ------------- --......- H2S 0.00 LIME ES /12.5 FROM TO ¡ HOURS, CODE 00:00 02:45 2.75 CASE P 02:45 03:30 0.75 CASE P OPERATIONS SUMMARY TROUBLE SUB I PHASE RUNC INTRM1 CIRC INTRM1 DESCRIPTION Run casing to 5727'. Staged pumps up to 6.0 bpm initial pressure 680 psi. Reciprocate pipe PUW 200k SOW 183k, circ ---.-- .9------------------------------------_._------------~-~-- con d _m l!. d, f i ~i--.£--~~ s s uL~__..?_z..9~.~------------------ -Q~~~Q__.Q5..:.30~.9..Q.._~_~?"§'..P_m_____._------ _~UN~_.___~NTR~.!.__~u n____~_~ sin g t 0_71 8 -~-~~--~~_!..~J~..r:..':!..~_!~~-_t......?_j 0 i n_~~_.:__._--- 05:30 06:00 0.50 CASE T EQIP CIRC INTRM1 R e C i pro cat e pip e P U W 2 7 5 - 3 0 0 k SOW 1 7 5 - 2 0 0 k, P ump at 1.5-3 bpm attempting to regain returns, n 0 returns, lost 48 bbls of mud. ------------.-.---------.------.--...-------.--.-....-.....-.. -.--. RUNC INTRM1 Con tin u e tor u n cas i n g, M U L J and h a n g e r, I and casing with FS @ 7802', FC @ 7714'. LD fill-up t 001 and MU cement head. --.--.... ..------- -.----.-------. ------- -----.-----------..---- ---------- 07:45 09:45 2.00 CEMENT CIRC INTRM1 R e C i pro cat e cas i n g 5 0' P U W 27 5 k, SOW 2 00 k, P u mp with 2-4 .bpm maximum pressure 420 psi. rum ped 40 bbls with 12.5 ppb LCM and continue to r egain returns. Pumped second 40 bbls pill with12 .5 ppb LCM, no returns established. PUMP INTRM1 Line up to cementers and test lines to 3200 psi. Pumped 20 bbls of preflush, 50 bbls of 12.5 ppg spacer and 32 bbls of 15.8 tail cement. INTRM1 Displaced cement with 20 bbls of FW from cemen ters, and 274 bbls of mud with rig pumps at 5-6 b pm, had partial returns last 50 bbls of displacem ent, reciprocated pipe until I last 10 bbls. Bumpe ------_._--------_....__._-------_.._--~-_pJ....u g ~~_!!'_@--~.~J_o a t ~-~~.9_.:_---_._-------_._-_.. 11:30 12:00 0.50 CEMENT PULD INTRM1 Blow down lines and RD cement head. ..-.- .---.-----.-----.-....-...----------------.-..------ -- -.------..-.___..__m__._.....-.. 12:00 13:00 1.00 CASE P RURD INTRM1 L D I and i n g j nt, rem 0 vel 0 n g b a i Is. c I ear run n i n g t - 0 0 I s f r _9_!!1_...!:JJL.!..~~:..._-----_._------_.__.._---_._------ - .. NUND INTRM1 Install and test packoff to 5000 psi. Changed top pipe rams to 3 1/2" X 6". ------ --.-- -.---.-- .----- --.-.----.-- ...---------.--.------- ....--.------ --------..---.-..---------.....------- -' --- BOPE INTRM1 T est pip e and b I i n d ram s, c h 0 k e, kill and man if 0 I d valves, IBOP and floor safety valves to 250/50 00 psi. Test annular preventor 250/3500 psi. Pull test plug and install wear bushing, blow down Ii nes. Upper IBOP valve (auto) leaked. AOGCC ( C huck Sheve) waived witnessing test. -' .-...-. --- .--..----.-------- .--------"'--. ..----- ..-.---.- 06:00 07:45 CASE P 1.75 .-'--' ---..----.-- 09:45 10:20 0.58 CEMENT DISP 10:20 11:30 CEMENT 1.17 -- --- --- 13:00 15:00 2.00 CASE P 15:00 21 :30 6.50 WELCTL P Printed: 2/4/2002 8:55:41 PM ( ( ~ ..... 1'. '- ~ ¡lHILLIPS l' ~ ',~~ I ) ~ Page 2 of 2 CD2-34 Phillips Alaska, Inc. Daily Drilling Report I JOB NUMBER; EVENT CODE! 24 HRS PROG ITMD ITVD ! ; ODR ! 7,812.0 7.199.0 DFS i REPT NO. : DATE 11.00 I 12 ¡12/27/2001 WELL NAME OPERATIONS SUMMARY FROM TO I HOURS I CODE TROUBLE SUB i PHASE i DESCRIPTION 21 :30 00:00 I 2.50 I RIGMNT T RGRP IINTRM1 I C h a n g e 0 uti BOP val ve ._.---,------- ------ --------------.-----.---.- .-..-----.-----,--------------------.-- -.-------..-,-----.____..n_- - - -- 24 H~~lL~.!VIA~~ Ru~ 7" --~_a.~i!:~-,_co~!T1u_<!~ cm~ casinLIf1~!a.I~ a.f1_~ test packoff, RU and test BOP_~__--------------------------_.._.. -- - --.-----.-.--- ----..-. ---.-- ,.......-.--.. -----..- ,. -..-- - -- - -..--------.---.--..- .---,.-..-,.--------.---..----.-.--------.-..-.--.---..- - '--------'--"---'-----------------"--. PERSONNEL DATA ---------- COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS ..--.---.-.--.---.-..--......---..------....,--..'--- .-....--.------,--.----..-..--........--.--.-......-..-......- ------"---...--"-- --.-.-.--.. .-.....-.-.---.-.-------...--....-_..__..m. ------._u'.-----.-"-."'..-----'-.---' -.-..----..-.--" .-.,.....-........, ..,., .. -. Phillips 2 Sperry Sun 2 ---------.-..-...-----.-- --------------- -----'----- ---- ------..._----------- --------_....------------------ ---.- ------..-..- --- Q~Y~~----- -- --_.---- --- -- --.. -----______n___'_.-- ------~~- ------ p_S R ---------------- ---------------- ------- ---- -_:4_- .n. --. . -- . ~ker Inteq_.__. 3 Catering ._~--~--~ Dowell 2 Epoch 2 -.----.------.------------ -.----.-..----- _-___n..__.--_-,---- -- --.---- ---'-- -.--.--.-- -,---.-.----.------ ____n -------- .. MI Drilling Fluids 4 Fuel Water, Drilling UNITS gals bbls MATERIALS I CONSUMPTION USAGE ON HAND I ITEM 2,010 -24,122 Water, Potable 252 -4,285 . ITEM UNITS bbls USAGE 110 ON HAND ___un' ...-. . .. I I -1,120 TYPE CD2-47 NO.! 425 I CD2-34 SUPPORT CRAFT REMARKS TYPE . . NO. REMARKS Printed: 2/4/2002 8:55:41 PM Well Name: CASING TEST and FORMATION INTEGRITY TEST Date: CD2-34 12/27/2001 Supervisor: D. Burley Used cement unit Rio pump used w c::: ::J rn 400 psi rn w c::: a.. Reason(s) for test: D Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC X 7" 26# L-80 BTMC Casing Setting Depth: Toe 7,040' TMD 6,882' TVD Hole Depth: 2,369' TMD 2,364' TVD Mud Weight: 9.6 ppg 4,67" Length of Open Hole Section: EMW= Leak-off Press. 0.052 x TVD = 530 psi 0.052 x 2,364' + 9.6 ppg + Mud Weight EMW for open hole section:::: 13.9 ppg yes #2 Pump output = bbls pumped Fluid Pumped = 9.5 bb!s Fluid Bled Back = 0.0 bbls 800 psi 700 psi 600 psi TIME LINE ONE MINUTE TICKS 500 psi 300 psi 200 psi ~ LEAK-OFF TEST ~CASING TEST LOT SHUT IN TIME -.- CASING TEST SHUT IN TIME -+- TIME LINE 100 psi 0 psi f--' 0 22 24 26 6 8 10 12 14 16 BARRELS 18 20 2 4 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Mnrlifiprl hv ~r.ntt Rpvnnlrls 28 LEAK-OFF DATA MINUTES FOR lOT BBlS PRESSURE r---------- ---- T-------Õ----- --r----Õ--p- sr---l' I I I I r---- ------------r----- --- - --- - -- r------- - --- - ----., I I 0.5 I 5 psi I }---- -----------+------------- --~------------: ----{ I I 1.0 I 20 pSI : "--- - ------ -----....------------ - --~------------ ----... I I 1 5 I 56 . I I------__m _m 1------:---- - --L--------P-~~-7t : I 2.0 : 142 psi: rm----m -----t-----~E!r- - --t---2"Š-f psr'* ì-_m_____m_-t-----3~Õ--- ---r---3"š-f psT --t t--------------- "t---------------t------------ -.---) I : 3.5 I 464 pSI I r-_m--_m__-:--_-- 4~Õ--_mr--S2Õ-pSr-~ r--- - ___mm_-t-----4~ š-__m tmsËffpsT-} t--- ------------+-------- ---- --- ~-------- --- - -.---} I : 5.0 : 596 pSI. "--- ------ ------....----- --- - ------ ~------------ ----... ! ! 5.5 ! 606 psi! --------- ----- - ....--------------- ~--------- -- - - - --... ! ! 6.0 ! 611 psi! f--- ------ -- --- --r----- ------- - --r---------- --- ---., : : 6.5 : 626 psi: t--------- -- ----+----- ---- ------~----------- -- .----{ I : 7.0 : 596 pSI: "---------------....----- ---- ----- -~------------ ----... ! ! 7.5 ! 591 psi! t-------------- - ....----- ------- --- ~----------------... ¡ ! 8.0 ! 570 psi ¡ f----------------r------------ ---r--------- ---- - --., I I 8.5 I 550 psi: }-------------- -+----- ---- --- --- ~------------- .----{ I : 9.0 : 550 pSI: ¡---- ----- -------r-----9~ S------ r---SS-Š--p-sr-î I I I I t--- ------------ ....---------------~------------- ---... I I I I I I I I I I I I r-------------- - -r--------------- r---------- ------., . I I I I I I I }----------- ---- +-------- -------~------------- - --{ I I I I I I I I "---------------.......,........................... ,.........................."... , . I I I . I I I . I I I ! SHUT IN TIME! SHUT IN PRESSURE r----------------r------------ - ------------- --- - ---, : 0.0 mìn : ¡ 555 psi ¡ }-----------.----+------------ - --~--------- ----.---{ I 1.0 mln I I 460 pSI I "--------------- ....----- --- ----- --~--------- - --- - --... ! 2.0 min ! ! 404 psi! t--------------------------- --~--------- ---- - --... ! 3.0 min ! ! 379 psi! r---------------r---------------r----------------" : 4.0 min : : 359 psi I t-----------.----+------------- --~---------- ---.--- { : 5.0 mm : : 343 pSI I "---------------....--------- --- ---~---------- ------... ¡ 6.0 min ! ! 338 psi! t---------------""---------------~----------------'" ! 7.0 min ! ! 328 psi! f----------------r---------- ---- -r------- - --- -----., I 8.0 min : ; 318 psi: t--------- --.----+------------- - - ~- ---------- --.----1 : 9.0 mm : I 313 pSI: "---------------....---------- -----~------- ----- ----... L_!_9.:Q-~jr!j__m___- - ---.L --~~-~ J!~L-1 30 ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE f---- ----- -- - -- - r--Õ-st ks--- r ----Õ--p-sr---1 I I I I r----- - -- - ----- - .,..-------- - - ----.,.. - -------- - - --- -- ~ I I I I I I I I }--------- -- --- - +-------- - ----- + ------ -- - - - - ---- t I I I . I I I I >---- ------ - - -- -...------ -- - -----... - ------- - - - -----~ I I I I ~--- - ---- - t-------- - -- --- t--------- -- - ----1 ~--- - - --- -t------- - - --- - - t-------- --- ----- i I I I I I\O~- ---- - -- - t ------ - -- - -- - - t--- ------ -- - - - --1 I I I I t'tt-t----- - ---- "t------- - ---- -- "t--- ----- --- - - ---t " I I . r~-ti-- - - - ----t-------- - --- --t-------- --- - - --- t I I I I I I I I r~U-- - -- --- - T-------- - ----- T - ------- - -- - ----1 I,";-C¿;-- - - - --- - t-------- ------ t- ------- --- - - ---1 I I I I >-------- - -- --- - ...-------- - -- ---...- ------- - - - - ---- ~ I I I . I I I . I I I I t ---- ----- - - --- - ..,...---- ---- - ----- ..,...-------- --- - ---- ~ I I I . I I I I I I . I r---- ----- - - --- - .,..-------- - ----- .,..-------- --- - ----~ I I I . ~----- --- - -- --- - +-------- ------ +- ---------- - ----t I I I I I I I I "---- ---- - -- --- - ...--------- - - ---...- ---------- - ---- ~ I I I I I I I I I I I I t---- ----- - - ---- ..,...--------- -----..,... - ------- --- ----- ~ I I I I I I I I I I . I r-------- - -- --- - .,..----------- ---.,.. - ------- --- - ---- ~ I I I I I I I . }----- --- - - - --- - +---- ---- - ----- +-------- --- - --- - t I I I I I I , I "--------- - - --- -...----- --- - --- --...--- ----- ----- ---~ I I I I I I I I I I , I --~. ! SHUT IN TIME! SHUT IN PRESSURE r---- ------ - ---- .,..-------- - ----- -,--------- ---, - - ---~ I O.Omin I : OpSI : }---- ------ ~ --- -+------ -- ---- -- +-------- -- - - ---- t I 1.0 mln : I : "---- --- -- - - ---- ...------ - - - -----...--- ----- -- - - - ---~ ! 2.0 min ! ! ¡ t- --- ------ -- ---..,... ----- - - --- -- - - ..,...--------- ---- - --~ ! 3.0 min ! ! ! r---- -- ---- - ----.,.. ------- - - --- - -.,..--- ------ ---- - --~ I 4.0 mill: : : }-- -- ------ ~- ---+ ----- - - ----- - -+--- - --- -- - --- - --t I 5.0 mill I I : "---- -- ---- - ----...------- -- --- - -...--- ------- --- - --~ ! 6.0 min ! ! ! t---------- - --- -..,... ---- -- -- - - -- - -..,...--- ------ ---- - --~ ! 7.0 min ! ! ¡ r------ ---- -- - --.,.. ------- --- -- - -.,..- - - ------ - --- - --~ I 8.0 mill : I : ~------ ---- - - - --+ ------ - ----- - - .J.._-- ------ - --- - -- t ! 9.0 mill: ! : "------ ------ - --... ----- - - --- - - - -...- -------- - ---- --~ ¡ 10.0 min ¡ ! ! t------ ----- - - --..,... ------ - ---- - -- ..,...--------- - --- - --~ ! 15.0 mill ! ! ! r-------- - -- - - --.,.. ------- --- -- --.,..- -- ------ - - -----~ : 20.0 min I : : }---- ---- - --~ - - - +---------- - --- +- ------- --- - ---- t : 25,0 mill : I : "----- ---- -- --- -....---------- ----...- ----- -- --- ----- ~ ! 30.0 mill ! ! ! >-------- - --- - -- - ------ - -- - - --- -- ------- --- -----. -. NOTE: TO CLEAR DATA. HIGHLIGHT AND PRESS THE DELETE KEY C"o,",' by b~"hc., rO<: V ,;0"'>'00 00:0 ,'°,"," , 30".00-2002 "0: Rc'c,,"ce :, \<We <ElCI 87"">. C"":nc:,, e'c '0 ',c: ,,'c-cnce "e: ,J", :,,"c Vc-::'" Doplh, O'C ","COC" [";~C:ce '«3. . i::;;;",'i::i ~~" ;"¡¡'! 4400 <000 3000 "00 'BOO ¡n S rn" - :,'00 .1 ",on 0 0 " g ,"0O QJ ë ~ "00 <000 3GOO " 3100 'Ron 2100 2000 1600 - QJ:¡, , """""""", "." """" """...".", 1200 - 800 " 400 " --- - Q) 2 '-' £ 400 ::J a (I) I 800 V 1200" ( I) l'lill i J~ s (' l-\lasl{a, III c. Structure: CO#2 Field: Alpine Field Soalc 1 inc!> - 400 I: "00 ,noo IGOO I2CO BOO <00 '00 IB, , , , , , "'" , , , , , , , , , --\~ "'\, \ ""~,~,,',I/~ "00"0 ",1J,ì 'i:"!'/'\.,e:::"~~:':..:::"-,:,~,,,,/" """, '"I' """'"11 Well: 34 Location: North Slope, Alaska East (feet) -> 800 1200 1GOO 2000 2<00 2800 "°0 3GOO <000 """". ".....-."'..""."., 8\ , , , , , , , , , , , , , , \ , , , , , " \, ...-" """" \, "".... \ '" , "\\ \' \\ " " " , \ \\ ., \ \'\ , .. " , "".,',.,...." " \, "" "...,.,..,.",,\:\,\.. " ""'" \ ""~1J~ì,' \ "",',' \ ~ '\ '-'-'-" \, \, '\ -"', ŒEJ \ '\ "'" "",,\\ \. .\ \ \ , \', \\\~, 7 e"."" '\"" ". "'" \\ ,..-".".... ..,"- ,...,..,.:>:,;;,:... "..., "",.""';);';,::",, ..",/ ,/ / /' /' 1600 - Ci'Y"" lOOO " ,,' / ' . = /:::..::: /(/ h>;"'/ ')]iJ tl!// 1400 >800 ,"DO ~ ~'~ 7 """"" \', \""'\ , , '\\ ~ ,1000 " 4000 4400 4800 - 8200 " 5600 6000 -- 6400 4400 4000 3000 3200 Scale 1 inch -= 400 Il 2800 2400 2000 1600 1200 800 <00 400 '\ , \. , \. \ \ \8 ~~ 7 e"""11 \ , , , , , \\ \, \, \ ~ 800 1200 1600 >000 2400 >BOO 3000 ,1000 4000 East (feet) -> .:'~ ~ PHilliPS ?' ! _::-:-:-:::-::--'::::-,-,.-:-:::"",::: ! !:'--'" - - .. .::'\ i ;,,-:':i,: ";;,,,' _:.:;,;;:,; ~ 4400 5200 <BOO "c..'Ot"" "---""-'" ."'. , , " tm .."'... \\\ \\ \.,\, '[3 " '" 4400 <ROO 5>00 5&00 &000 0400 I::: ,. '800 3' g. '400 ~ 0 0 ;:: 4000 '"00 "00 '800 ",DO >000 1000 " 1200 800 400 U1 a 5- :r 400 -:;- CD ~ '-" ROO I V . 1200 1600 2000 >400 ,"00 "°0 3600 ,000 4400 ~\,,41/' [I"", Dr;:] " 4AOO . 0200 56011 " 600<> 5600 6400 6400 6000 , , , , , , , , ~ ."""""""""",~/"'I' '001°' .)¡ "I' '001°' .,."......"..,"" , '",~~~""'ì;'-¿::;::' ,.."" "." h "I,coolo, ,/' "",.\'.oII~.,';"'o, """',,,,':1"'-"I'COOIO' """""""'::';"'~ "I'I ,,,'o, """"".," """"" """"'" ,!!:', 'I' "",~""""" ""\c'"""".j' "'1M ,;"'O, 1'03/ V T~"!;y, "",,",' ""." ",!,li~!~"\\\11.., "-."" (' C""tod by b~ '"001 Dolc p'o""" "-'."-,,,", Pic! '{dc'cn" " "WJ <"'°1 - "7,""> Phillips Coo.d",'c' 0<0 'n ',cI 'dc'cnc, ,10' 1,1', 7"" V,,:"ol D'Plh, 0." '"';,:,:C" "":"'°"° 'K8" "",;;¡;'-- -. Structure: CD#2 Field: Alpine Field 'Nn'~ Scale 1 inch - 100 It \JOO "00 \100 1000 'co 800 100 ,.00 <00 JOO '°0 100 bOO ,- ",00 ~ ~- 0 0 :<00 .<: u ,~ lOaD - ~----- / ~ õ ,~~ 1200 I 1 00 ' Cò, ,..... "18 COO," '" 1000 cø 000 AOO - Q:; 700 Q> CiD""'" "\'~ ",III ""'O, "00 """""""...""., "" "'" ""'" """'" """" "" 600 - """"""""~"',~/' '00"" """""" £:::. "I' Cool" 400 JOO "-þ:,.IIY~"C"'~:'~, 200 ....... Q; () .... '-" 100 " .!: "5 0 1/1 I V 100 1 3 2cf'/f r"" "", " ,..".",,"'¡f "1M Coo"~" .." ( Alaska, ][ ~:l C ,~, ~ PHllUPS ~ . . ; . ; ~ . . t:':: 'OC'" w """:,,..;2 ~',"::':{;'.J Well: 34 Location: North Slope, Alaska East (feet) -> 100 '00 \JOO :<00 I, ",co I UI ~ 1i' ,co JOO '00 >00 600 800 90O 1000 \100 '200 ~ I!) l"r 0 '1M 'oo¡'o :<CO 5' " ~ UCO , '200 0 0 ;:: ~~ ? C,'",' , , , , , "00 400 JOO 200 1110 1/1 0 S- o :r ....... .... '" laD !l '-" I '00 V ,,'00 400 000 000 700 "°0 <§) \100 ~ II ',IA Coo"'11 1000 &5 000 " , 800 700 ~ """""""" "-.." , "-"""-.., ""'" ,/' ';!::;"li"~;!^I\" .../ ¿.," ,/.~ "I't;'h~"', .""""""",~,<::':~'<:',',;;r " "'~ '<':::','::::;:"'" , "',, ,,' , , """'-"'::'-"" "I' ":'~~:« ""1' C,,'o, .... \, . , ""'"" JÎ"¡;~ - / \ 'ij;~:":::,, ,..:,~~".,."/,,,/.//'/'" "",/ \> ~.~: ..:\\" -" " :-"( -::, 0 01' ç,"~":",, ", , ,""',,'.~>'" / \~ 0 'I' Coo"" cØ!fl/ ~o>~,..çoo"o / ~ & ! 1000 - .c9 1100 " 700 ."," " ,/ ""."...., 300 400 000 '00 '/00 "00 1200 . & """'"'1 "'00 --.-- * Too,.' - "'°,,00 ¡'Ii, :;00 . ~, "'I'I """',~¡ , "",". 1500 " :GOO & '" . @ :;, IJOO 1200 1100 1000 900 800 700 '00 '00 <00 JOO 200 100 Scole 1 inch ~ 100 It .4l 9 'I' Coo"o \, , , \, \. ~ /\\ y"'.", --'----------- \ " ""w " 1<7,47 W "\" ì;~ "'III C"""'II \ "- \ \, \, % 1000 1100 4ò- 1200 UOO :;00 ~ 1500 1600 IJOO :;00 \.>- 0 'III """"'0 ~ 100 200 JOO 400 '00 600 700 800 900 1000 1100 1200 East (feet) -> SURFACE CASING SHOE SEPARATION FROM CD2-34 Surface Casing Shoe ASP 4 Coordinates: 371803.06 5974439.79 Distance Surface Surface csg. Cement Casing No. of Ann. Vol. from Object csg. Shoe X Shoe Y Wells Permit # Permit Date Report Tally LOT Source well **** Start Date End Date well* Coord. Coord. CD2-35** ----- ---- x x 1 ---- ---- ---- 661 372312.31 5974017.68 CD2-24, CD2-33, CD2-42 301-140 6/1/2001 x x 2 CD2-33A, CD2-15 33992 6/1/2001 10/10/2001 835 371098.46 5973992.48 CD2-33 (+A&B), CD2- CD2-24 301-186 7/13/2001 x x 2 39, CD2-14, CD2-15 33999 7/16/2001 1 0/9/2001 1206 370630.11 5974721.81 CD2-33 B*** ----- ---- x x 4 ----- ----- ---- 1738 370155.64 5973886.23 CD2-39 301-281 10/9/2001 x x 2 CD2-15, CD2-47 27879 10/10/2001 11/12/2001 975 372350.61 5973633.17 CD2-14 301-288 10/9/2001 x x 2 CD2-45, CD2-47 14835 11/13/2001 12í17/2001 657 372202.47 5974960.87 CD2-15 301-308 11/6/2001 x x 2 NA 1113 370832.00 5974984.02 CD2-47 301-322 12/3/2001 x x 2 CD2-34, CD2-26 27349 12í17í2001 1 í20í2002 1280 371231.72 5973294.19 CD2-45 301-345 12/13/2001 x x 2 CD2-49 18721 1/20/2002 2/12/2002 1127 372765.13 5973853.74 CD2-34 x x 2 NA 0 371803.06 5974439.79 CD2-26 x x 2 NA 115 371798.52 5974554.55 CD2-49 x x 2 NA 666 371252.38 5974065.93 CD2-34 x y -I ~~ J ~ ../ * Distance in feet, between surface casing shoes, in the X- Y plane ** CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annuluar disposal. ***CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' ND), shoe depth shown indicates window depth. It has not been permitted for annular disposal. **** As of 12-Feb-02 ~x-. ,f' ~ \ II~ (\ ~1r~1rŒ (ill~ ~~~~~~ ALAS KA 0 IL AND GAS CONSERVAnONCO~SSION l / .I , / / TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alford Drilling Team Leader Phillips Alaska, Inc. PO Box 1003 Anchorage AK 99510-0360 Re: Colville River Unit CD2-34 Phillips Alaska, Inc. Permit No: 201-191 Sur Loo: 1905' FNL, 1522' FEL, Sec. 2, TIIN, R4E, UM Btmhole Loc. 81' FSL, 1065' FWL, Sec. 1, TIIN, R4E, UM Dear Mr. Alford: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (CD2-34 PH) and API number (50-103-20393-70) from records, data and logs acquired for well Colville River Unit CD2-34. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD2 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pennit , to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. ( f ~ Colville River Unit CD2-34 Permit No: 201-191 Page 2 of 2 Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (~(ktv): ~ ¿ammy cQchsli Taylor. Chair BY ORDER OF THE COMMISSION DATED this 3rd day of October, 2001 jj c/Enc1osures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ¿ \ , l Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 20, 2001 RECEIVED SEP 21 2001 Alaska Oil and Gas Conservation Commission 333 West yth Avenue, Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. GomffilSslon AnchoraIJ9 Re: Application for Permit to Drill CD2-34 (& CD2-34 PH) Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD2 drilling pad. The intended spud date for this well is October 4, 2001. It is intended that Doyon Rig 19 be used to drill the well. The CD2-34 pilot hole will be drilled through to the base of the Alpine Sand at +/-28° inclination. This will allow evaluation of the reservoir interval. It will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting completion of well work and facilities work that will allow the well to be put on production. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed pilot hole schematic. 6. Proposed completion diagram. 7. Proposed completion diagram with open hole isolation options. 8. Pressure information as required by 20 ACC 25.035 (d)(2). 9. CD2-34 Pilot Hole Cementing Requirements. 10. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. ORIGINAL ( ( If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~~7-. Vern Johnson Drilling Engineer Attachments cc: CD2-34 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy lambert lanston Chin e-mail: ATO 1530 A TO 868 A TO 848 A TO 844 Anadarko - Houston Kuukpik Corporation Tommy- Thompson@anadarko.com i' ( ( STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 .~\\ .r~û\ t ,o\b ./cO /., ç to ( \ d --b-Vc:: /' 1a. Type of Work Drill X Redrill 1b Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (OF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 52' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P, 0, Box 100360, AnchoraQe, AK 99510-0360 ADL 380075 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1905' FNL, 1522' FEL, Sec.2, T11 N, R4E, UM Colville River Unit Statewide At target (=7" casing point) 8. Well number Number 2554' FNL, 348 FEL, See, 2, T11 N, R4E, UM '-'SDI_ri"~';:':" #59-52-180 ":)', .., ',,1' "'" ~~j}",;" At total depth 9. Approximate spud date Amount 81' FSL, 1065' FWL, Sec. 1, T11N, R4E, UM 1 0I.a4J20Q1'~: $200,000 12. Distance to nearest 13. Distance to nearest well 14. Nùmber of acres in property 15. Proposed depth (MD and TVD) Property line CD2-33 10769 MD 81' FSL T11 N feet 10.2'at313 Feet 2560 7227 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth feet Maximum hole angle 89.9° Maximum surface ,~." psig At total depth (TVD) 3247 at psig 5000 ,I 7175' TVD .SS 18. Casing program Settinq Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Lenqth MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2366' 37' 37' 2403' 2400' 337 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 7732' 37' 37' 7769' 7220' 128 Sx Class G N/A 4.5" 12.6# L-80 8rd mod 7410' 32' 32' 7442' 7143' TubinQ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production Liner Perforation depth: measured SEP 21 2001 true vertical n' . ..... . . .. .... l"~.~ I' 20. Attachments Filing fee Property plat BOP Sketch Diverte, ~'w.v,' VII - I.m mg program X X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report ~~9~50 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ilA)_¿ {)f.~ Title Drillinq Team Leader Date '9(2.1 "" ./' .... Commission Use Only Permit Number/ ~ I API ~b3 20 =?~~~OO I Approval date (0' 19:> \ IC) \ See cover letter for .2CJ/ - /' 50- e::; - Other requirements Conditions of approval Samples required Yes ~ Mudlogrequi ed Yes rNo~ (;) - Hydrogen sulfide measures Yes . Directional survey required c9 No Required working pressure for BOPE 2M 3M cV 10M 15M "SS~'C) ~\ \S~\>-\<t ~ ~\.,,\ ""~ ~ Other: by order of ({') /3/0 I Approved by """ Commissioner the commission Date Form 10-401 Rev. 7-24-89 -, 'tI".g. ~rDned B Su'bmit rn triplicate y Cammy Dechsli ORIGINAL '" ,,' (' l " CD2-34 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of thes~~~s21 2001 12-1/4" Hole /9-5/8" Casin Interval Event Risk Level Conductor Broach Low Well Collision i.\fó~ähJm Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVD Lost Circulation Low Low 8-1/2" Hole / 7" Casin Event Abnormal Pressure in Surface Formations >2000' TVD Lost circulation Interval Risk Level low Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low RECEIVED , .. ' ns. t..;OHnHlSSIOI Ancho De Miti ation Strate Monitor cellar continuous! durin interval. <Jyrb~sir"\gleshóts., CO2- 35 10' at 100', CO2-33 102' 312'. Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Oiverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries M iti ation Strate BOPE drills, Keep mud weight above 10.4 ppg. Check for flow during connections and if needed, increase mud wei ht. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheolo ,lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted swee s. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. HzS drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low M iti ation Strate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheolo ,lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. BOPE drills, Keep mud weight above 9.3 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. HzS drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL ~~. ", Alpine: CD2-34PH (Pilot Hole) & CD2-34 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Procedure Install diverter. Move on Doyon 19. Function test diverter. Drill 12-%" hole to the surface casing point as per the directional plan. fF!un.aQÖ'&~JJl~,Ol_~:p/~J~_s~~ac~ b~~'i nQ. Install and test BOPE to 5000 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. !Perform leak offtest.~ Drill 8- 'Y2" hole to a point +/- 100' TVD below the base of the Alpine Sand. Set a 500' cement plug #1 from TO to +/- 7062'. Set a 400' cement plug #2 from +/- 6662' to +/- 7062'. RIH with drilling assembly. Dress off plug #2. Kick off at +/- 6978' and drill sidetrack to intermediate casing point in the Alpine Reservoir. Run and cement 7" casing as per program. :iii'e1p"J~øfjré'-emerïtc~¡'*,-;::ré'€rø:"féel';"/rEfâtfð\ÎèAlpinë':'Ì"e$e~oir. ,G.arr~._QuL,,: 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 5000 psi. Run drilling asserryþlY.Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 -""', "~I-"~ "L", ".'", , ppg EMW. MlrtimÜm'acceptàbTê:leäk"off,for:drHlingäheää:,is1rj,.¡),~'PP9'::f?'MW¡.:,i Drill 6-1/8" horizontal section to well TO. 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. ".'"'¡I,il":i',::,¡.":è:.':';';',C"""""",:,,,, Run 4-'Y2, 12.6#, L-80 tubing with $'SS\l'nip:þlé;" gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus. Set BPV and secure well. Move rig off. OHlullVAL { '- t Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. I,GD2-33 will be the closest well to CD2:"34 , 10.2' at 313" MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 7.7' at 350' MD. DrillinQ Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Incidental fluid~- developed from drilling operations on well CD2-34 wiU'h:é it1jéctedihtoa P~Imi~ted annulus ',' "'1""'"' "",",' " ,I ',", , ' ' on CO2 pad or'tAeiél~ssi;2å:¡s-pos~:Ü well on CD1 pad. . . The CD2-34 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVO. 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. ;¡Wi&:;~;;"F~'~Uie§t,',t~at"".,ÇDZ~94,'Þe~"lpeum j'tt~'ctl':fpr1!,I'a,Anl:Jlar",\;pårri/þ.ihg,~,6f<1',fhJids:.',ribcutr,ihg','.:åà.",'â:" :',rèso It',.'öf ".' d ri II i ng operations, perregUlãtion 20 MC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USOW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set below the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi = 1,086 psi Pore Pressure 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 aD (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 ORIGINAL {" If CD2-34 & CD2-34 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 ~" Section - 6 1 18" point - 12 1f4" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 1 0 - 25 10-15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4-8 10-15 10 minute gels <18 12 - 20 API Filtrate NC - 10 cc I 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 -10.0 9.0 - 9.5 KCL 6% Surface Hole: A standard high viscosity fresh water I gel spud mud is recommended for the surface interval. Keep flowline viscosity at :t 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 I 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 low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with aM-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with :t 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL " { ,( Colville River Field CD2-34PH Pilot Hole - Prior to Sidetracking Updated 08/20/2001 RKB - GL = 37' ~ Wellhead 16" Conductor to 114' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2403' MD / 2400' TVD cemented to surface 9.8 ppg drilling mud in hole Plug #2 : 400' (6662' MDt 17 ppg to cover the HRZ when in place (HRZ top at +/-6953) Cement Plug Top of cement plug dressed off to 6978' MO / 6817' TVO (+/- 28° inc.) . .. . . . .. ....... . . . .. . ... . .. . .PIQg:#2: . Top Alpine Reservoir at 7381' MO / 7173' TVO Top of Cement Plug #1 at +1- 7062' 500 ft Pilot Hole TO at 7562' MD / 7332' TVO (+/- 28° inc.) OHI(jNAL /' (' Colville River Field CD2-34 Production Well Completion Plan 16" Conductor to 114' Updated 09/20/01 4-1/2" Cameo BAL-O SSSV Nipple (3.812" 10) at 2000' TVD=2003' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" 00) run in profile Dual 1/4" x 0.049" sls control lines 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2403' MD I 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. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco RP Shear Valve Pinned for casing side shear @ +1- 2000 psi set 2 joints above the X landing nipple WRDP-2 SSSV (2.125"10) wi DB-6 No-Go Lock (3.812" 00) - to be installed later Packer Fluid mix: 9.6 ppq KCI Brine with 2000' TVD diesel cap Tubinq Supended with diesel to lowest GLM Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Cameo BAL-O SSSV Nipple 2003' 2000" End thermal centralizers 2403' 2400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Cameo KBG-2 GLM (3.909" 10) 3403' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. 4503' 4500' (1 per joint) Cameo KBG-2 GLM (3.909" 10) 5719' 5700' 4-1/2", 12.6#/ft, IBT-Mod Tubing Cameo KBG-2 GLM (3.909" 10) 7193' 6992' 4-1/2" tubing joints (2) HES "x" (3.813" 10) 7288' 7058' 4-1/2" tubing joint (1) Baker S3 Packer 7338' 7088' 4-1/2" tubing joints (2) HES "XN" (3.725" 10)-61.6° inc 7430' 7137' 4-1/2"10' pup joint WEG 7442' 7143' Baker S3 Packer at +1- 7338' <200' from top of Alpine TOC @ +1- 7038' MD (500' MD above top Alpine) -"'----. '. ""':"<'<""-""'<"'..__mm.mnnm.n.._.... Top Alpine at 7538' MD 1 7181' TVD --.-- - - --,--- ---.-- - ---,--- ---,--- ---,--- ---,--- - --.-- - ---.-- - - --.-,-- ---,--- - --.-- - ---.--- -, Well TD at i 1l~~.~t~~~:. ...J . "',." ;:~7;2i2'1<~..T\Rj:':.,', ,".. "', ::'. ' ." . , I - ---.-- - - --,--- --_._- - ---,-- - - --.-- - ---,--- ---,-- - ---.--- ---,--- ---,--- - -_._- - ---,-- ---- 7" 26 ppf L-80 BTC Mod Production Casing @ 7769' MD 1 7220' TVD @ 89.86° ORIGINAL t ( Colville River Field CD2-34 Production Well Completion Plan Formation Isolation Contingency Options Updated 09/20/01 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" 10), WRDP-2 SSSV (2.25" 10) and DB-6 No-Go Lock (3.812" 00) with dual 1/4" x 0.049" sls control line @ 2000' TVD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2403' MD 1 2400' TVD cemented to surface _(A) Bonzai ECP Assemblv - Baker ZXP Packer (4.75" 10) - 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 Cameo 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. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD (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 1 Entry Guide Camco KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch J.Ç) Open Hole Bridç¡e P'uç¡ Assemblv - Baker Payzone ECP (cement inflated) -XC -Float Collar - 4-1/2" Float Shoe Camco KBG-2 GLM (3.909" ID) & 1" Camco RP Shear Valve Pinned for casing side shear @ 2000 psi set 2 joints above the X landing nipple '. Baker S3 Packer set at +1- 7338' M D . """""""'T--'-'----'--'~' Well TD at 10769' MD 1 7227' TVD TOC @ +1- 7038' MD (500' MD above top Alpine) -." -... -- "-. -"- ' -"-'-'-' -" "'~.-.;,..,._. - L______----,-c_-.c_-.- -~_.._~-~'_._~--_._~~--_._-'-_.&. ".' -.-.-~.. . : @ @ : -~_._~--_._~-_._~--_._--_. '."',.. -~-.-~-""""",: 7" 26 ppf L-80 BTC Mod Production Casing @ 7768' MD 17220' TVD @ 89.86° ORIGINAL 1il ( CD2-34 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well : Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (Ibs. I (psi) (psi) MD/TVD(ft) Qal) 16 114/114 10.9 52 53 9518 2403 I 2400 14.5 1086 1569 7" 7769 I 7220 16.0 3267 2545 N/A 10769 I 7227 16.0 3270 N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]0 Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft 0 = 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 1. 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 = [(FG x 0.052) - 0.1] 0 = [(14.5 x 0.052) - 0.1] x 2400 = 1569 psi OR ASP = FPP - (0.1 x D) = 3267 - (0.1 x 7220') = 2545 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3270 - (0.1 x 7227') = 2547 psi ORIGINAL ~' " ( ß!Pine, CD2-34PH Cementing Requirements CD2-34PH Cement Plug #1 : 7562' MD to 7062' MD = 500'. Slurry: Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. 500' X 0.3941 fe/ft X 1.15 (15% excess) = 226.6 fe => 196 Sx @ 1.16 ft3/sk CD2-34PH Cement Plug #2 : 7062' MD to 6662' MD = 400'. Slurry: Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. 400' X 0.3941 fe/ft X 1.15 (15% excess) = 181.3 fe => 182 Sx @ 1.00 fe/sk ß!Pine, CD2-34 Well Cementinq Requirements 9 5/8" Surface Casing run to 2403 MD / 2400' TVD. Cement from 2403' MD to 1903' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1903' to surface with Arctic Set Lite 3. Assume 200% excess annular volume in permafrost and 50% excess below the permafrost (1655' MD). Lead slurry: System: Tail slurry: System: (1903'-1655') X 0.3132 fe/ft X 1.5 (50% excess) = 116.5 fe below permafrost 1655' X 0.3132 fe/ft X 3 (200% excess) = 1555.0 fe above permafrost Total volume = 116.5 + 1555.0 = 1671.5 fe => 377 Sx @ 4.44 fe/sk 377 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fe/sk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% SO01 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 fe/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 fe/ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fe/sk 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % SO01 accelerator @ 15.8 PPG yielding 1.17 fe/sk 7" Intermediate Casing run to 9122 MD 1 7232' TVD Cement from 7769' MO to +/- 7038' MO (minimum 500' MO above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (7769' - 7038'} X 0.1268 fe/ft X 1.4 (40% excess) = 139.8 fe annular volume 80' X 0.2148 fe/ft = 17.2 fe shoe joint volume Total volume = 129.8 + 17.2 = 147.0 fe => 128 Sx @ 1.15 fe/sk 128 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk ORIGINAL 1 By Weight Of mix Water, all other additives are BWOCement a ::x::' ..............c- ~. --""c c. ~ ~. ~ ~-_. Date plaited: f8-Sea-20m D I ~ 11 < Al! ~ 1: In 1 CliilllOS laSKa, :IJLC. Created by bmichael For: V Johnson Plot Reference is CD2-34P81 Version#9. Coordinates ore in feet reference slot #3'c- Vertical Depths ere reference Estimated ~;i~:: Y;'f"'<) Structure: CO#2 Well: 34PB1 Field: Alpine Field Location: North Slope. Alaska ~~~~ P,' . D n ,~,~ ¡ ~ I \ V; ----- Point ----- KOP in" LU,--, Begin Drop West Sak EOC Base Permafrost C-40 C-30 9 5/8 Casing C-20 K-3 K-2 KOP bian-97 EOC bian-96 HRZ K-l LCU Miluveach A . n pine LJ pine C B Alpine C/Alpine A Base Alpine A Kinaak F , J TO MD 250.00 500.00 1000.00 1069.42 1250.00 1654.54 2224.54 2401.54 2402.54 2734.54 3850.54 4070.54 5000.00 5596.17 5932.56 6129.13 6953.46 7158.41 7260.32 7338.45 7359.97 7381.48 7438.10 7451.68 7463.01 7561.52 ". mmmu u u -. UU __mm ._mum_m_. u. Inc 0.00 5.00 5.00 3.61 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 17.89 27.98 27.98 27.98 27.98 27.98 27.98 27.98 27.98 27.98 27.98 27.98 27.98 COMMrNI Dir 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 105.1 4 105.14 105.1 4 105.14 105.14 105.14 105.14 105.14 105.14 105.14 105.14 105.14 105.14 TVD 250.00 499.68 997.78 1067.00 1247.46 1 652.00 2222.00 2399.00 2400.00 2732.00 3848.00 4068.00 4997.46 5584.00 5893.40 6067.00 6795.00 6976.00 7066.00 7135.00 7154.00 7173.00 7223.00 7235.00 7245.00 7332.00 _m.'mmm_mm u. ._um........ ;\,,; A~,~, A u ¡ North 0.00 -0.95 -4.75 -5.20 -5.70 -5.70 -5.70 -5.70 -5.70 -5.70 -5.70 -5.70 -5.70 -29.80 -63.99 -88.07 -189.07 - 214.18 -226.67 -236.24 -238.88 -241.51 -248.45 -250.11 -251.50 -263.57 ~~~~ 10.86 54.27 59.46 65.13 65.13 65.13 65. '¡ 3 65.13 65.13 65. í 3 65. í 3 65. Î 3 154.22 280.58 369.59 742.87 835.68 881 .83 917.21 926.95 936.69 962.33 968.49 973.6 í 018.22 East 0.00 V. Sect 0.00 10.76 53.76 58.91 64.52 64.52 64.52 6/~.52 6~c.52 6/~.52 64.52 6/;-.52 64.52 156.81 287.69 379.89 766.56 862.69 910.1;-9 947.14 957.23 967.32 993.88 '1000.26 1005.57 '1051.78 Dog/100 0.00 ~roo .~- 0.00 /.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~~ a ::x:s -- C':) - - <: ~ r--- Created by bmichaei For: V Johnson Date platted: 1 9-Sep-20Dl Plat Reference is CD2-3? Version#9- Coordinates cre in feet reference slat #34- Vertical Depths are referenae Estimcled ;<'j"-~ r;".E(' D 1 ~ 11 1 ~ 1) All - l' ~ JL llllll¡pS lLaSK:a; A- Ii I".' C i JL' . Structure: CD#2 Field: Alpine Field Well: 34 Location: North Slope, Alaska ==== ----- Point ----- . KOP - Sidetrack pt K-1 LCU . Miluveach A . Alaine 0 , i . Alaine . ¡ . Torget-EOC-Csg pt 'TO - Cosin pt = 'I ~ .I'! . ~ ¡ 'i!i ! ~ID ",L-.AK" 0' i' ¡Ir ill IL L I " u. c L- Û ~ rn M' ~,á ¡¡=' NN~T \\ nU'Ui"M' ,.;1 ¡: V 11M., Iii!! :i,: Ii II ~ Ü ~ ~ J L t u n.n' A"" A [I i U ~ ~ MO o¡( No (t h TVO inc 6978.43 27.98 6817.05 -192.13 754-. í 8 105. í 4 7184.54 126.55 6986.00 -246.38 857.25 42.10 .... - . ~~, , PHilLIPS I."~""y^~"-""'-""-'--"'-""'" tf:ti ,==~-~ Eost V. See t """" "()r"../ ~ 00 LJ ":1 ; 0.00 9.00 7318.95 52.62 1 34.71 7077.00 -311.03 931.68 713.67 9.00 ~ 7446.73 63.02 140.55 7145.00 -390.98 1004. í 8 818.36 9.00 7486.45 142.13 7162.00 -419.01 1026.60 66.29 7538. í 6 144.07 7181.00 -457.46 1055.45 70.58 7768.58 151 .86 7220.00 1174.86 -649.13 89.86 10768.91 15 í .86 7227.00 -3294.8 í 2589.90 89.87 525.11 62 í .56 853.65 90 '! . Î 7 1126.50 Ai 26.82 9.00 9.00 9.00 0.00 l ,r-" ". .,' ", . ,J/--\l""""Y"",S ' , I ... .. ~. .. .. .'. .. ,,-..I Cree:c" Dy bm;co,ce: For V .Johnson De:e p'o::ce : IB -Sco'2001 Strucfure : COI/2 Field: Alpine Field "'°: ",,!ere"ee " CD2-'\<"B' Vecs.o"#9, Coord;"e:cs ere ;0 !ee! rclercnce "O! ,#3'., 'Treo Vcrllccl 0001"' ara relM""CC !."':mel,,e !~,G, co -;;;- 0) ~oo - 600 - 800 . 1000 - 1200.. 1400 - ,---.,. +- (J) (J) 'I- 1600- '---/ .£ +- :J 1800- 0 (/) I 2000 V 2200 - 2400 - 2600 - 2800 3000 - :5200 3~00 -- ..,..,,-;¡; \\~,~ '" ".~. 0 ¡--Ü;TIM,^Tm"'šui<FACi:-l I_OCA1ION: J I '9OS' eN!.. ~sn: ILL L_~:...~_I2~I\I,_i<~E- g ~ ~ 0, ,C:: ¡;¡ 0 (J *, ^' 0) 1 c:: ,0 :iJ '{- :----'~;,~m--~ïO-Li~ _m-l l TARCEì LOCATION: I ~{~t_~~ ~~~,6~~~~J " Q; .C::- ~ ,Q , ,,{' " f; ('¡.. Q; 0 Q (J ,f;' I".:::., :>Q; Q; Q; . ,,8J ,Q "- Ú .;).c::- ," -\:- -...¡ :;;:: ,Q ;f;;,Q e, t """,,'<'¿~o, K - 1 * ,:",,~ QJ };:c::- Q I,CUk ,:~,P~~I.I " A': ", " ..... T ,,\ -- .. G S ~(\.. G. 9 Well: 34PB1 Location: North Slape, Alaska [--PILO'rHõL:E-T.í), ,---.J LOCATION: 2168' FNL, 504' FEI- S[C.2,T11N,I~'1E ------------ Targcl--EOC'--Csg PI ~ -? .(5) ~ ~ TO L.oCATION: 81' FSL, 1065' FWI- SEC. 1, T11 N, R4E ,-------..------- 3600 ------T'-'---'r---¡-'-"--r---T--'-r----¡------ r'---- --¡----"-'-'-T--T----T--T-r~-'¡--r--"--'--I 200 0 1 05.14 AZ <:0 0) I c::- .0 jj * " (J '. 9! 8 ' :J:: l-mL KOI) -- Sidetrack F)l *, MiIIJVCAOC.h A ~.'~' nlpme. U * Alpine ¡,;,\. [--'----------] TAI~GET I_OCATION: . 25~4' I,-.:NL, :$48' IC~.~L SEC. 2, T11 N, 1~41- -------------- 200 1200 East (feet) -> 400 600 800 1000 1'1,00 1600 1800 (, -;f .. y' r" ~'.. .l ",'. \../ . .~~-'",- .", ""'- <::: Q~ ;1" i" 1'1'" ,¡;- '":, :. n:L t";;;; ¡ ~ .1 . 1- ;¡ r, ~ ~ ~,.'r --..."..."';"'--:'" 1 04.29 AZIMUTH 1052' (TO PILOT 'rD) ***Plone 01 i.:Jroposol*** TO - Casing PL r--r--T-¡---r--r----¡ 2000 2200 2~.00 th h ŒD 1 ~;;@ TRUE tm 2600 2800 ORIGINAL HRZ* K'-1 I_ClJ MiluveÇJch A AlPine Dc Alpine, [~ Alpine C/ Alpine A ' Base Alpine A :511'IJ1 Kingok 1° 7600 - ---¡-'--r-¡-------,- -"--"-,-----l--IQ¡--r------,------¡-- -----I-----r----r"--'-r---T---"'I---l-----'---¡-----¡ 400 a 400 800 1200 1600 2000 2.400 2800 3200 3600 a 400 800 1200 .. 1600 - 2000 2400 ,.--.... -f- Q) Q) 2800 .. L- '--" ....c -f- 3200 - Q.. Q) 0 0 3600, 0 -f- \... Q) 4000- > Q) :::i HOO- \... i- I V 4800 - 5200 - 5600 - 6000 - 6400 -- 6800 .. 7200 .. i { J? Jb i ~, ~~ i l) S -'. A'- 'l " 'J\ ~ , --" ". G... S _c\.. a , ], 'n r. . ..l J, \.j . Structure: CD/!2 Well: 34PB1 Field: Alpine Field Location: North Slope, Alaska ! I~N?ol.:lcvolion: S2' KOIO ~ t~~ . [OC Begin Drop ; 4,00Wes\ Sok * 2,00 . [DC *- 0,00 130se Permafrost ><- C-40 j,.l C..-30 9 5/8" Casing P\ >< C-"20 104.29 AZIMUTH 1052' (TO ][JILOT TD) ***I::Jlone of j:Jroposol*** >< K<5 K--2 TANGENT ANGLE "VEHTICAL" ,><- KO[:) * 3,00 * E),DO * 9,OD * 12,00 * 15,OD ¡. 18,00Albion--97 * 21,DO * 24-,00 '\<' 27,DOr::OC :*, Albion-96 \ DLS: :5.00 dcg per 100f\ TANGENT ANGLE 27.98 DEG ŒJ Vertical Section (feet) -> Azimuth 104.29 with reference 0.00 5, 0.00 E from slot 1/34 (;¡¡i~Ù;S) 1 ~ f ),", "---....,..-" C"nted by bmioheol For V .Johnson Dale pln!:e" ; 18-Sep-2001 l'lo! Holorcnoo i, CO2-j^Pgl VorsionN9- Coordinotos ore in foot reforonco olal 113;- 1 ruo vortioal DoolM oro reloronoo [,timotod HKß- !"'õ~ """..., h-.IOmJj INn.(~ ORIGINAL <::) :J::J - - ~ - - <: ~ r--- LCU" Miluveacn A" Alaine D\ 7200 -.! Alaine C ~IB Alpine C/AI.Dine A\ Bose Alaine A Kingak I liD 'i34PB1 :::: ] I I I I I I Created by bmichae! For: V Johnson Dcte plotted : 18-5ep-2001 Plat Reference is CD2-3? Version#9- Coordinates are ;n feet reference slat #34- Vertical Deaths cre reference Estimated ~-~ ,NTEO ~ -I- Q) Q) 'r- ~ l~ 6200 ~ ~ ~ 6400 J I ! 6600 i .J I HRZ.. " </" ,L ,Oc, ij- ~,C; / 0'1- ,L ~ ~<?:- ~':> ~- '1-"- 'l- <ò<Ò /" '?- '" ~. + ~Q ~ "::) <ò V Oe, / ~ c; -è!.e,-,~~e, G ~. ""V '~~~lq' <v° ". ,,~~ þ<'l- '?' ~ ~ -. ,," e, ~~ () k ,OJ '?j ",-0 ---L1 >---0 ~ "'" ,,OO qe,' òe,o, 00 ~. Cj- QV ....c -I- 0... Q) 0 6800 0 0 -I- L Q) > 7000 Q) ::¡ L l- I V 200 400 1000 1200 600 800 1400 D1 'l"Vc' Jt .iÎLl: IlIa s An a" SlT') ..<l ' ~V'l....d., I' ,I) ", 1..1L~ . Structure: CO#2 Field: Alpine Field Well: 34 Location: North Slope, Alaska 151.86 AZIMUTH 1127' (TO TARGET) ***Pione of Proposo!*** TARGET/FINAL ANGLE 89.87 DEG ~_.-~ <PHI~~~~( (l¡~ ~~ íD - Casing p~ WJ 1500 1800 2200 2800 3200 3600 3800 "200 2400 2600 3000 2000 VertiGo I Section (feet) -> Azimuth 151.86 with reference 0.00 S, 0.00 E from slot #34 3400 4000 -"" r-'- --,---,----;-' /.400 1,800 "600 East (feet) -> ~O 20 0 20 ~O 50 80 100 120 HO 160 180 200 220 - ._~-j--e._-__L_._I- - _...1- _.l____l__.-.L..-.__L._-._l_- ...1. -- - L_---L._...L--L..-- L-L-._L-.l_.__I._.l..____L_--.l___--.J__L-L- @ ~jOO lOOt 900~ 1100'~:)ggo :'J700 /00 8;-;'::00 * E%,300' , -'" ". ")c. 1 9 0 0 @ 30èJ~:'~w~PQ - "'gò:a. @ 300 * """ 1100 '" .* ~ :$00 '~~V~Q~O.OO /700 ""'. ...,~9q.§300* 1100 "<:,"'" ..r'íôé; * 500 300 ""'~'" ..A @ "". 900 ~'). ,.......,/ * 700 @ 300* 700 "<~>" ~ " .'I-~* 900 "<~-2300 @300 1100 . * 700*, 1300 '<';::: ,* 1 ~)oo *@ 300 '~' * 500 * 1700". * 11 DO 1'$00 @ :309 .,1; 00 * ' -*, 700 * 900' "', * 150'0700 @:$OO * 900',"", 44 ~~~~3°L í~L,~ ~~~,ï~~ ~'O 20 0 20 4D 50 80 1 DO 120 140 150 180 2DO 220 East (feet) -> 'I' ¡ ( Cree:ed by b",:cheo' For V .Iohnson Dc:e o'o::ed : ;9-5co. 200~ I'io: l¡c(clCcco " c:J/-J~ vcI,:o"i/9. ". ': ._.J() " ;', " '.'~, S.... .. "' ~. "' "' "' :, I~ " \" " .' ,. -....' ," L- ..~ ~ S .K.: C'~ 5 , 'r' rì "~. .~ '--' . Well: 34 Structure: CD!!Z Field: Alpine Field COO'C:"c:c, ele In :cC: ,clcrcnee ",,: #.\<. Location: North Slope. Alaska Vcr:lee. JC?:"' cre .dcrer.ce ;.,::"'e:e" '<Kg. ruoi~,,".è "".""""'" :;.rr.'f¡ 160 . _1.8J E3,300 SOO 1100 @- * @300 1700 * @ 1 :SOO * 1500 HO 2Ql 120 ~E> - -<v 1 500 ~ 300* 700 * * gß!6.500 @300 /00 ,"~~~~OO @300 * 500 @JOO @300 It.. 500 @ :SOu @300 @300 @300 * 900 * 1100 5300 * 5500 .* 100 * 1300 * gOO * 1100 *,900 ,* 1300 80 - * 700 * 1100 ^ I 60 - r--. -+- Q) Q) '-I- '---" 40 - :;0 1100 * ..c 4- I..... 0 Z 31 20 @300 * 1 300@ 300 700 ../ ,A"" @':;:Ð_G::~':::',-',J,O(~, - '..~,' - ,"", r--. -+- Q) Q) '-I- '---" 0 -'Œ gqg" dB"""" "::.", ~:",,'i)'~~o.,.'ì': ':-,- t, ::; :i!:'§59~)::' ':, - - """ 20 ..c +- :J 0 tf) I V 40 - * 1300 50 ,. * 100 80 & *, 1300 100 - 120 - '-e§> HO 150 5700 *, * 1500 "'~:?7.00.. - 40 -""",.,~,"'Œ15. r--~~~. ..:- -I.'I~-"" "" '¡;:i!'" ~,~ ~..'! I!,.~~" ,\! f1I. ~~ ~ ~;:- j ~ š .~ ~ G 'ií-.. if """----~.....-~' ~g 26 -- 120 _0 150 HO ._0 100 80 _0 60 ^ I z 0 ") -+ :::J - ~O -- 20 r--. -¡., CD CD -+ '---" 0 - 20 If) 0 C -+ :::J r--. -¡., CD CD -+ '---" 60 I V . 80 - 100 - 120 - 140 160 ORIGINAL ( t '~) '~"\ ,~ J: J" ,~ '0 S-. A A ...~ . L .~' ~---"""'" " nUl" 'liPS ~ t.,rr1ll.-,."..(" ". " " , ~"",,-,;,.:r L\ ~', aç , S 'k aç L -. - , ! :["\, C A_" . C'ca'c" "Y """cI'oci For V .J ohnson Dc:o alp;:o" : :9-öOP"200' Structure: CDf/2 Well: 34 ?IO: Rolo'ence ;3 C~2..Y. Ve>5'an#9. Caelc:na:o" PIC In 'ec' ",Ic'cnce "O, NY', Field: Alpine Field Location: North Slope, Alaska "co VeiLcal Dca'"' aIC Icr",eneo E","',,:ea RW. ~.!E"!> '-006i1lW 1'"'1'" East (feet) -> ------ -+- Q) Q) ....... "---" ;1~)O 500 7~)0 Î 000 1 ;150 1 é>00 17é>O ;1000 2;150 2500 ?'I 50 .5000 3250 -. ~:~~:._I__..-L-...:.____L_I_L _.J_..J_._L -- ~-L_,_L.__-L__L.._-~_.-. L-_~L ~-;..L_L_~L___l__..- L-.,-_L 0 . ~ . '"(,:1" '" 6.0.0.0 \ - 4' I;¡I,,~ml!~~~~!~'&~î~!:\ilJi); " , , '. 250 . </.5 ,,',I'¿b "" '~¡¡~Jl',",'-,,?,".o,_.o r------J \'o $6'",;2O'QO~i" I3~Pßl , $, * ~" ,~.5 "'~ 30, 00 2aoQ~'.'.'I~ -, --,.. " <;- I ~, "Il'l'~' ' §"" """,2aaQ"I,~I\'",','" ' <5',::\*,2.0.00",,*- ""¡'!~~\"'" \ v.." ,1, '~"'I' , lr ~.., 2.0.0.0'2-0.0.0, '\¡"',':~,I,,.;;,', " , * 3.0.0.0 \ ó' u1\ * . "" ,','!,:;~;', \ .J.. 'I." ,'.~,:$?22a \1<; 4.0.0.0 750 - ~ \~ 2QOO'",'~;;~:;', \ \::J "'~I\,),:" *, :;000 \ \ ,,'¡\;~'\ ' 4 *. 2000 * 2QQQ\:t'iIii':.,4.0QQ \ *. 44- 1'5, 3:0:000 \\, '3000 \'í:~,:,~;:"",., \,~ .. IOOC "\ ~(:',:",:'II ".*4.0.0.0 1250.. ," 1250 \ <;i1j\~'>~. '., .. -' \. \!~;,~ .* 3000' '11<, ?QOQ ~ $;~:,;,\ 'fJ " \I::,~~I", ",*, 3.0.00 ~ - 1500 '\ "'~;ti."~" "" ',,' ,,'~!~":' " \II:,!\' '" """""" , \"{1~11\:~\ '\ \1,:': "", """ '1\ 4.000 '"I,:"" '" \, 300,0*' ' !\, "'" .. "\¡\ '\ ,\""jl')' .. ","l"" 3.00.0 '\ \\i:\~(1:I;\' , ~~:\~I,I"\ \, ~:,;,j,::, \, ~*\¡ ,~:~\ "'ilt~I¡i>', \ ¡"II""" '\\ '\~~\::;'\ \ 'ìAjl,l\ .. i:I",,',,~ \ \"~I:l:~, \, .. \, 60.0.0 \ .. \. \ \. \, .. \, \. \, \. \ .. \ .. \ '>t 7.0.0.0 7000 \ , " '~ 1 1 500 1000 1500 .. 1750 - * 4000 "* 6.0.0.0 "'" -- 2000 "'" ~ "Qb ,., 2250 ....c -+- :J 0 (í) I V 2000 - % * 4..000 2250.. * 3.000 2500 *. 4.000 * :1000 2750 - * 5.0.00 3000 - 3250 '1.4.0.00 * 5.0.0.0 *.4.00.0 3500 - * 600.0 * 4..0.00 3750 .,. 4000 .. -~-'-'-I"'----¡'-----r----¡' ~----¡-¡~~ I -----,:B.¡----¡--,--,-,--¡-- 250 500 750 1000 1250 1500 1750 2000 2250 ~ I I 2750 2500 3000 East (feet) -> ~ "<J .2750 ~- -,-- - 3250 0 250 500 - 750 _0 lltSO (/) 0 C -+ :J ------ -+, CD CD -+ "---" I V 2500 .- 3000 3250 - 3500 .. 3750 .. 4000 ORIGINAL ",I' '~\- ~¡ Crea'ea by bm;ehael For V ,Johnson '~~ '~) ," ~' 'l' ," ,y) S "'- A -"~"'" "' è-, k A A ]" " " ,," ..... 'T" -'-';,. - c... S ~:h... {"1 , ]r ,"(' , ~ ~- ,- (...- " ;~.......-~ ¿' P"I", "liP"'" 1. . n iLL , ;:;. { ~ ~ ¥ l ~ ,t, ~ ~ '---v ~ Jole "'allee , ~9-Sep-~aa' Structure: CDI12 Field: Alpine Field Well: 34 '"'a: Raler""ee ;, CW-,y. VN:;;a',~9, Coa:e;"":e, e:e '", Ice: re'era"aa ':01 "J', Location: North Slope, Alaska ,',,;a Vcrl'ea, aep:o, ere rclcreoec L:.I;"'OICO !~K;J, ~'/1! '-;;-a.., "¡TE', em @j ¡'¡:\ U l=, NO 1\11-1 Q -'2'-, <>,',1- 4J L":'@ 1____] ~ * 6o0~)50 * 300 0 340 @ *600 10 1200 20 @j 3:50 * 600 30 -Z20 ~) -,. 40 310 50 300 Q"Ql Qu 290 60 70 2,80 80 270 60 70 90 260 1 00 250 1 1 0 240 120 2Ï'0 .". ~) 1 ~)O 220 140 210 *1'5Q?*.~ 1 00 -"" ,,300 ""'<'- 1 7 0 "Qb '~,~ 200 1 50 1 60'" ~ 200 "...,."....,.......1-90,*..601"'8'Ö"" @...."..... \S) ~ ", "';& '<6~ ~ Normal f:Jlane Travelling Cylinder - ¡=-eet All depths shown ore Meosured depths on Refer'ence Well ORIGINAL f " (" C'ca:ce by "m;cr,cel For V .Johnson ce:c ?:o::ec : ~ 9-5ep'-200' Pia: Re:e'cnec is CJ2-J'. VecsiarH9, 'r' " . '[ ,. . ,,- ~ l--) J': " ",.., S.... ,"' J -~ ,A -- -- ,J..... jt A', , "1 T ,.., :- -~ a s ~~ G , "(ì C -~ -l"~ ". ,.~~, .f ':'1~, MI'" ~ I,~'-~~"',:"'" ~"",N" '"'tIt" ~""~""'-.. ,r, ,~ Ii, Ii ~I ' , 'J . ~ \1' 'V '" ¥ "'~-.".-~ Cooed'nc:cs c'e Ir /ee: "IO'cree 5'0: 1/3<, Structure: COff2 Field: Alpine Field Well: 34 : ¡rue Ve.:;ecl Jeb:hs are re/e'ence [s:'me:ed IlK!!. Location: North Slope, Alaska ;J:f;:<ì\1~ M-n!' "'.R,W," T'rn:o ~ // (92 ::3"0/'/ ~,.,., çY' ,,' ,']; ~r¡, 220 ~1~00 Qõ 320 \i>., 1400 OJ C0 @ JSO j 40. 900 900. TRUE NORTH ~ L_X &0 @oo @ 10 \\Í.À ~ CJJJ 20 3:30 30 & * 1 ~OO 40 * 1900 ŒÐ ŒJ310 50 @ ,,@ 0 300(I[r"",~""""""", 60 290 (EJ 70 280 80 270 90 260 100 2' e- 0 -,) 1 1 0 240 120 & . 130fÐ ""1"40" ""'" @ 20 O. 900 1 60 . 90d 90 1 8 O. 900 1] 0 @14~ r? ~ ~~ "Q¿) * 1400 Gb 210 c§> ~ Normal Plane Trovelling Cylinder - Feet All depths shown ar,e Measured depths on Reference Well ORIGINAL { Phillips Alaska, Inc. CD#2 34PBl slot #34 Alpine Field North Slope, Alaska PRO P 0 S A L LISTING by Baker Hughes INTEQ Your ref: CD2-34PB1 Version#9 Our ref: prop4828 License: Date printed: l8-Sep-200l Date created: 17-Aug-2001 Last revised: 17-Aug-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 18.372,w151 2 27.401 Slot Grid coordinates are N 5974452.868, E 371716.367 Slot local coordinates are 1904.11 S 1520.99 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ~. ;t ORIGINAL \ {' Phillips Alaska, Inc. PROPO5AL LI5TING Page 1 CDff2,34PB1 Your ref : CD2-34PB1 Versionff9 Alpine Field,North 5lope, Alaska Last revised : 17-Aug-2001 Measured Inclin Azimuth True Vert R E C TAN G U LA R G R I D COO R D 5 G E 0 G RAP H I C Depth Degrees Degrees Depth COO R D I N ATE 5 Easting Northing COO R DIN ATE 5 0.00 0.00 0.00 0.00 0.005 O.OOE 371716.37 5974452.87 n70 20 18.37 w151 2 27.40 100.00 0.00 95.00 100.00 0.005 O.OOE 371716.37 5974452.87 n70 20 18.37 w151 2 27.40 200.00 0.00 95.00 200.00 0.005 O.OOE 371716.37 5974452.87 n70 20 18.37 w151 2 27.40 250.00 0.00 95.00 250.00 0.005 O.OOE 371716.37 5974452.87 n70 20 18.37 w151 2 27.40 350.00 2.00 95.00 349.98 0.155 1.74E 371718.10 5974452.69 n70 20 18.37 w151 2 27.35 450.00 4.00 95.00 449.84 0.615 6.95E 371723.31 5974452.14 n70 20 18.37 w151 2 27.20 500.00 5.00 95.00 499.68 0.955 10.86E 371727.21 5974451.73 n70 20 18.36 w151 2 27.08 1000.00 5.00 95.00 997.78 4.755 54.27E 371770.55 5974447.20 n70 20 18.33 w151 2 25.82 1050.00 4.00 95.00 1047.63 5.095 58.18E 371774.45 5974446.80 n70 20 18.32 w151 2 25.70 1150.00 2.00 95.00 1147.48 5.555 63.39E 371779.65 5974446.25 n70 20 18.32 w151 2 25.55 1250.00 0.00 95.00 1247.46 5.705 65. DE 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 1500.00 0.00 95.00 1497.46 5.705 65. DE 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2000.00 0.00 95.00 1997.46 5.705 65.DE 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2500.00 0.00 95.00 2497.46 5.705 65. DE 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 3000.00 0.00 95.00 2997.46 5.705 65. DE 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 3500.00 0.00 95.00 3497.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 4000.00 0.00 95.00 3997.46 5.705 65. DE 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 4500.00 0.00 95.00 4497.46 5.705 65.DE 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 5000.00 0.00 95.00 4997.46 5.705 65.DE 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 5100.00 3.00 105.14 5097.42 6.385 67.66E 371783.90 5974445.34 n70 20 18.31 w151 2 25.42 5200.00 6.00 105.14 5197.10 8.435 75.23E 371791.44 5974443.17 n70 20 18.29 w151 2 25.20 5300.00 9.00 105.14 5296.23 11.845 87.83E 371803.98 5974439.55 n70 20 18.26 w151 2 24.84 5400.00 12.00 105.14 5394.55 16.605 105.42E 371821.48 5974434.49 n70 20 18.21 w151 2 24.32 5500.00 15.00 105.14 5491.77 22.695 127.95E 371843.91 5974428.02 n70 20 18.15 w151 2 23.66 5600.00 18.00 105.14 5587.64 30.115 155.36E 371871.19 5974420.14 n70 20 18.08 w151 2 22.86 5700.00 21.00 105.14 5681.90 38.835 187.58E 371903.25 5974410.88 n70 20 17.99 w151 2 21. 92 5800.00 24.00 105.14 5774.27 48.825 224.52E 371940.01 5974400.26 n70 20 17.89 w151 2 20.84 5900.00 27.00 105.14 5864.52 60.065 266.07E 371981.36 5974388.32 n70 20 17.78 w151 2 19.63 5932.56 27.98 105.14 5893.40 63.995 280.58E 371995.80 5974384.15 n70 20 17.74 w151 2 19.21 6000.00 27.98 105.14 5952.96 72.255 311 .12E 372026.19 5974375.37 n70 20 17.66 w151 2 18.31 6500.00 27.98 105.14 6394.53 133.515 537.53E 372251.52 5974310.30 n70 20 17.06 w151 2 11.70 6978.43 27.98 105.14 6817.05 192.135 754.18E 372467.13 5974248.03 n70 20 16.48 w151 2 05.37 7000.00 27.98 105.14 6836.10 194.775 763.95E 372476.85 5974245.22 n70 20 16.46 w151 2 05.09 7389.41 27.98 105.14 7180.00 242.485 940.28E 372652.34 5974194.54 n70 20 15.99 w151 1 59.94 7500.00 27.98 105.14 7277.67 256.035 990.36E 372702.18 5974180.15 n70 20 15.86 w151 1 58.47 7561.52 27.98 105.14 7332.00 263.575 1018.22E 372729.91 5974172.14 n70 20 15.78 w151 1 57.66 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #34 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 1051.78 on azimuth 104.51 degrees from wellhead. Total Dogleg for wellpath is 37.98 degrees. Vertical section is from wellhead on azimuth 104.29 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL ( Phillips Alaska, Inc. CD#2,34PBl Alpine Field,North Slope, Alaska Top MD TOp TVD Rectangular Coords. t PROPOSAL LISTING Page 2 Your ref: CD2-34PBl Version#9 Last revised: l7-Aug-200l Bot MD Casing positions in string 'A' Rectangular Coords. O.OOE 2402.54 ------------------------------ ------------------------------ 5.705 Bot TVD Casing 0.00 0.00 0.005 ----------------------------------------------------------------------------------------------------------- 2400.00 NO Targets associated with this wellpath 65.13E 9 5/8" Casing ORIGINAL ( Phillips Alaska, Inc. CD#2 34 slot #34 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref: CD2-34 Version#9 Our ref: prop43ll License: Date printed: l8-Sep-200l Date created: l-Dec-2000 Last revised: 17-Aug-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w151 1 42.976 Slot location is n70 20 18.372,w151 2 27.401 Slot Grid coordinates are N 5974452.868, E 371716.367 Slot local coordinates are 1904.11 S 1520.99 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( ORIGINAL { ( Phillips Alaska, Inc. PROPOSAL LISTING Page 1 CD#2,34 Your ref : CD2-34 Version#9 .'\lpine Field,North Slope, Alaska Last revised : 17-Aug-2001 Measured Inclin Azimuth True Vert R E C TAN G U LA R G R I D COORDS G E 0 GRAPH I C Depth Degrees Degrees Depth COO RDIN.1\ T E S Easting Northing COO R DIN ATE 5 0.00 0.00 0.00 0.00 O.OOS O.OOE 371716.37 5974452.87 n70 20 18.37 w151 2 27.40 250.00 0.00 0.00 250.00 O.OON O.OOE 371716.37 5974452.87 n70 20 18.37 w151 2 27.40 300.00 1. 00 95.00 300.00 0.04S O. 43E 371716.80 5974452.82 n70 20 18.37 w151 2 27.39 400.00 3.00 95.00 399.93 0.34S 3.91E 371720.27 5974452.46 n70 20 18.37 w151 2 27.29 500.00 5.00 95.00 499.68 0.95S 10.86E 371727.21 5974451.73 n70 20 18.36 w151 2 27.08 1000.00 5.00 95.00 997.78 4.75S 54.27E 371770.55 5974447.20 n70 20 18.33 w151 2 25.82 1050.00 4.00 95.00 1047.63 5.09S 58.18E 371774.45 5974446.80 n70 20 18.32 w151 2 25.70 1150.00 2.00 95.00 1147.48 5.55S 63.39E 371779.65 5974446.25 n70 20 18.32 w151 2 25.55 1250.00 0.00 95.00 1247.46 5. 70S 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 1300.00 0.00 105.14 1297.46 5.70S 65. 13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 1400.00 0.00 105.14 1397.46 5.705 65. 13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 1500.00 0.00 105.14 1497.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 1600.00 0.00 105.14 1597.46 5.70S 65. 13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 1700.00 0.00 105.14 1697.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 1800.00 0.00 105.14 1797.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 1900.00 0.00 105.14 1897.46 5.705 65. 13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2000.00 0.00 105.14 1997.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2100.00 0.00 105.14 2097.46 5.705 65. 13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2200.00 0.00 105.14 2197.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2300.00 0.00 105.14 2297.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2400.00 0.00 105.14 2397.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2500.00 0.00 105.14 2497.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2600.00 0.00 105.14 2597.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2700.00 0.00 105.14 2697.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2800.00 0.00 105.14 2797.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 2900.00 0.00 105.14 2897.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 3000.00 0.00 105.14 2997.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 3100.00 0.00 105.14 3097.46 5.705 65.13E 371781. 39 5974446.07 n70 20 18.32 w151 2 25.50 3200.00 0.00 105.14 3197.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 3300.00 0.00 105.14 3297.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 3400.00 0.00 105.14 3397.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 3500.00 0.00 105.14 3497.46 5.705 65.13E 371781. 39 5974446.07 n70 20 18.32 w151 2 25.50 3600.00 0.00 105.14 3597.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 3700.00 0.00 105.14 3697.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 3800.00 0.00 105.14 3797.46 5.705 65. 13E 371781. 39 5974446.07 n70 20 18.32 w151 2 25.50 3900.00 0.00 105.14 3897.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 4000.00 0.00 105.14 3997.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 4100.00 0.00 105.14 4097.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 4200.00 0.00 105.14 4197.46 5.70S 65.13E 371781. 39 5974446.07 n70 20 18.32 w151 2 25.50 4300.00 0.00 105.14 4297.46 5.705 65. 13E 371781. 39 5974446.07 n70 20 18.32 w151 2 25.50 4400.00 0.00 105.14 4397.46 5.705 65. 13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 4500.00 0.00 105.14 4497.46 5.705 65. 13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 4600.00 0.00 105.14 4597.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 4700.00 0.00 105.14 4697.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 4800.00 0.00 105.14 4797.46 5.705 65.13E 371781. 39 5974446.07 n70 20 18.32 w151 2 25.50 4900.00 0.00 105.14 4897.46 5.705 65.13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 500'0.00 0.00 105.14 4997.46 5.705 65. 13E 371781.39 5974446.07 n70 20 18.32 w151 2 25.50 5100.00 3.00 105.14 5097.42 6.385 67. 66E 371783.90 5974445.34 n70 20 18.31 w151 2 25.42 5200.00 6.00 105.14 5197.10 8.435 75.23E 371791.44 5974443.17 n70 20 18.29 w151 2 25.20 5300.00 9.00 105.14 5296.23 11.845 87.83E 371803.98 5974439.55 n70 20 18.26 w151 2 24.84 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #34 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 4190.89 on azimuth 141.83 degrees from wellhead. Total Dogleg for wellpath is 109.09 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 151.86 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL ( ( Phillips Alaska, Inc. PROPO5AL LI5TING Page 2 CD#2,34 Your ref : CD2-34 Version#9 Alpine Field,North 51ope, Alaska Last revised : 17-Aug-2001 Measured Inclin .r..zimuth True Vert R£CTAN G U L .r.. R G RID COO R D 5 G £ 0 G RAP H I C Depth Degrees Degrees Depth COO R D I N .r.. T £ 5 £asting Northing COO R DIN A T £ 5 5400.00 12.00 105.14 5394.55 16.605 105.42£ 371821. 48 5974434.49 n70 20 18.21 w151 2 24.32 5500.00 15.00 105.14 5491.77 22.695 127.95£ 371843.91 5974428.02 n70 20 18.15 w151 2 23.66 5600.00 18.00 105.14 5587.64 30.115 155.36£ 371871.19 5974420.14 n70 20 18.08 w151 2 22.86 5700.00 21.00 105.14 5681.90 38.835 187.58E 371903.25 5974410.88 n70 20 17.99 w151 2 21. 92 5800.00 24.00 105.14 5774.27 48.825 224.52E 371940.01 5974400.26 n70 20 17.89 w151 2 20.84 5900.00 27.00 105.14 5864.52 60.065 266.07E 371981.36 5974388.32 n70 20 17.78 w151 2 19.63 5932.56 27.98 105.14 5893.40 63.995 280.58E 371995.80 5974384.15 n70 20 17.74 w151 2 19.21 6000.00 27.98 105.14 5952.96 72.255 311.12E 372026.19 5974375.37 n70 20 17.66 w151 2 18.31 6500.00 27.98 105.14 6394.53 133.515 537.53£ 372251.52 5974310.30 n70 20 17.06 w151 2 11.70 6978.43 27.98 105.14 6817.05 192.135 754.18E 372467.13 5974248.03 n70 20 16.48 w151 2 05.37 7000.00 29.25 108.20 6835.99 195.095 764. 07E 372476.97 5974244.90 n70 20 16.45 w151 2 05.08 7100.00 35.88 119.57 6920.30 217.235 812.87E 372525.39 5974221.95 n70 20 16.24 w151 2 03.66 7200.00 43.28 127.64 6997.37 252.705 865.61E 372577.52 5974185.59 n70 20 15.89 w151 2 02.12 7300.00 51.11 133.72 7065.30 300.635 921. OOE 372632.08 5974136.73 n70 20 15.42 w151 2 00.50 7400.00 59.19 138.56 7122.42 359.845 977.66E 372687.72 5974076.58 n70 20 14.83 w151 1 58.84 7500.00 67.42 142.65 7167.33 428.885 1034.20E 372743.09 5974006.60 n70 20 14.16 w151 1 57.19 7600.00 75.74 146.27 7198.91 506.035 1089.24E 372796.80 5973928.54 n70 20 13.40 w151 1 55.59 7700.00 84.11 149.62 7216.40 589.415 1141.41E 372847.55 5973844.29 n70 20 12.58 w151 1 54.06 7768.60 89.87 151. 86 7220.00 649.155 1174.87E 372880.00 5973784.00 n70 20 11. 99 w151 1 53.08 8000.00 89.87 151. 86 7220.54 853.205 1284.00E 372985.66 5973578.16 n70 20 09.98 w151 1 49.90 8500.00 89.87 151.86 7221.71 1294.105 1519.82E 373213.97 5973133.37 n70 20 05.65 w151 1 43.01 9000.00 89.87 151.86 7222.87 1734.995 1755.63E 373442.28 5972688.59 n70 20 01.31 w151 1 36.12 9500.00 89.87 151.86 7224.04 2175.895 1991. 45E 373670.58 5972243.80 n70 19 56.97 w151 1 29.24 10000.00 89.87 151.86 7225.21 2616.795 2227.26E 373898.89 5971799.02 n70 19 52.64 w151 1 22.35 10500.00 89.87 151.86 7226.37 3057.685 2463.07E 374127.20 5971354.23 n70 19 48.30 w151 1 15.47 10768.93 89.87 151.86 7227.00 3294.835 2589.91E 374250.00 5971115.00 n70 19 45.97 w151 1 11.77 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #34 and TVD from Estimated RKB (52.00 Ft above mean sea level). Bottom hole distance is 4190.89 on azimuth 141.83 degrees from wellhead. Total Dogleg for wellpath is 109.09 degrees. Vertical section is from 5 0.00 E 0.00 on azimuth 151.86 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INT£Q ORIGINAL Phillips Alaska, Inc. CDff2,34 Alpine Field,North Slope, Alaska ND Rectangular Coords. TVD (I 'If PROPOSAL LISTING Page 3 Your ref: CD2-34 Versionff9 Last revised: 17-Aug-2001 Comment Comments in we1lpath -------------------- -------------------- 7768.60 10768.93 649.15S 3294.83S ----------------------------------------------------------------------------------------------------------- 7220.00 7227.00 1174.87E 2589.91E CD2-34 Heel Rvsd 15-Aug-01 CD2-34 Toe Rvsd 15-Aug-01 Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- CD2-34 Heel Rvsd 15- 372880.000,5973784.000,0.0000 CD2-34 Toe Rvsd 15-A 374250.000,5971115.000,0.0000 7220.00 7227.00 649.15S 3294.83S 1174.87E 2589.91E 17-Aug-2001 17-Aug-2001 ORIGINAL ,¡: ( ,,:í '( American Express@ DATE ¥~k ¿~2txJ/ro..,.'m' ~~~:~~:E æ-H /l&Ç.þ- /~(C I slleo.a> I -' ~ cit~ ~ jot:> DOLLARS . Cash Advance Draft 165 Issued by Integrated Payment System. Inc. Englewood. Colorado Payable at Norwest Bank of Grand junction - Downtown. NA Grand junction. Colorado PERIOD ENDING I: ~ 0 2 ~ DOt. 0 0 I: j 5 ... 0 ~ ? 5 00 0 5 :U; III 0 ~ b 5 " I "" CHECK 1 STANDARD LETTER DEVELOPMENT v DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL RED RILL ~ ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSNUTTAL LETTER WELL N~~4 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ,vi ANNULAR DISPOSAL <-)NO ANNULAR DISPOSAL <-) YES ANNULAR DISPOSAL THIS WELL , CIJ:2 '-. "-? 71 "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . . Production should continue to be reported as a fun.ction of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and. logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 ~70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS /" ~ YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved 'subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ' WELL PERMIT CHECKLIST COMPANY WELL NAMECO 2. - .1 L/ PROGRAM: exp - dev FIELD & POOL /2... 0/6_) INIT CLASS ~ /"'0,1/ GEOLAREA?9 ß ADMINISTRATION 1. Permittee attached. . . . . , . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . , . . . . . . . . . . , . . Y N 4. Well located in a defined pool., , . , . . . , . . . , , . , . , Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . , . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . , . . . . , . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12, Permit can be issued without administrative approval., . . . , Y N 13, Can permit be approved before 15-day wait.. . . . , . , , , . Y, N 14. Conductor string provided, . . , . . . . . . , . . . , . . . . 'fj) N 15. Surface casing protects all known USDWs. . . . . . . . . . . (!) N 16. CMT vol adequate to circulate on conductor & surf csg. . . , . (ÿ) N, ~ ~~: g~i~~,', ~~~~::~~~o~~i~:~~~~~;~~~:~:Scsg: : : .. : : : : ~ CID ~Q;-:'~"'>~-:-~~¡~;~~"",::'ì 19, Casing designs adequate for C, T, B & permafrost. . . . . . . é)9} ~ ~ 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . Q N ~"\.~~'t'< "",~ I "-Ò ~s.~~c~~ 21. If a re-drill, has a 10-403 for abandonment been approved, . . ~ r~ ~ ":J ~ ~ L ('- ~ . ~ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . ,N C-~j~o. ~'N'c:¡... '\(-~~'\tècJ~~,,~\::~('.("('U 23, If diverter required, does it meet regulations. . . . . . . . . , N ~ ,-.--.:::n ~ 24. Drilling fluid program schematic & equip list adequate. , . , . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . , , Y N , , 26. BOPE press rating appropriate; test to 3~b psig. N ~~" (~~ d~~". ~~\\ \,,~ "N\.) ~ ~ ~~~ '~St)t:'~~:x. 27, Choke manifold complies w/API RP-53 (May 84). . , . . . . , N r ~ ~~: ~~~~~~~~~~rH~~h;~~ ~~~~:~~; ~~u~d~~n: : .' : : : " .' ~ .' .' Y ,~ 30, Permit can be issued w/o hydrogen sulfide measures. . . . , 31. Data presented on potential overpressure zones. . . . , . , 32. Seismic analysis of shallow gas zones. . . . . , . . , . . . . AP.. R ~) 33, Seabed condition survey (if off-shore), . . . . . . . . . . . . 2 Q;{ 34. Contact name/phone for weekly progress reports [exploratory 0 , ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . , . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~þ~ WM to (. redrll serv wellbore seg _ann. disposal para req - UNIT# CJ50St'Cd ON/OFF SHORE ðv R DA, TE ~ c 0 Z ( 0 -I :E ;tJ - -I m - z -I J: - tA » .( :;0 m » AP. R ~/ ENGINEERING GEOLOGY N M /l\ Y N 1 Y N ~ ?h.~~\ ,,~~ c-"'~~~,,~s:~~~) ~'t\~\~":> ~". "-\~~~ íL~\.\ Y N Y N APPR DATE Comments/Instructions: 8~s JMH } c;\"J-r/C) c:\msoffice\wordian\diana\checklist (rev. 11/011100) I~ !~ ( Well History File APPENDIX , Information of detailed nature that is not particularly germane to the Well Permitting Process. but is part of the history file. , To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically , . organize this category of information. I" , .~ ¿}D/-/Cj I IIdY5 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 02 13:30:48 2002 Reel Header Service name............ .LISTPE Date.....................02/05/02 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.....................02/05/02 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-34 501032039300 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 02-MAY-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 AK-MM-11207 M. HANIK D. BURLEY MWDRUN 3 AK-MM-11207 C.A. DEMOSKI D. BURLEY MWDRUN 4 AK-MM-11207 R. KRELL D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 11N 4E 1905 1522 MSL 0) 51.90 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2369.0 6.125 7.000 7802.0 ~ ( 3RD STRING PRODUCTION STRING # REMARKS: 1. CD2-34 KICKED OFF A CEMENT PLUG IN CD2-34 PBl AT 6700'MD. 2. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 3. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 4. MWD RUN 1 (CD2-34 PBl) WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUN 2 (CD2-34 PBl) COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS), ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) , COMPENSATED NEUTRON POROSITY (CNP) , AND STABILIZED LITHO-DENSITY (SLD). 6. MWD RUNS 3 AND 4 COMPRISED DIRECTIONAL, DGR, AND EWR4. 7. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 8. MWD RUNS 2 (PART) , 3, AND 4 REPRESENT WELL CD2-34 WITH API# 50-103- 20393-00. THIS WELL REACHED A TOTAL DEPTH OF 8755'MD/7210'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW- COUNT BIN) SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: 8.511 9.5 - 9.8 PPG (, :1 I, MUD SALINITY: 550 - 750 PPM CHLORIDES FORMATION WATER SALINITY: 25,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/02 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE NPHI FCNT PEF NCNT GR RPX RPS RPM RPD FET DRHO RHOB ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2300.0 2300.0 2300.0 2300.0 2337.0 2350.5 2350.5 2350.5 2350.5 2350.5 2374.0 2374.0 2375.5 STOP DEPTH 6700.0 6700.0 6700.0 6700.0 8712.5 8719.0 8719.0 8719.0 8719.0 8719.0 6700.0 6700.0 8755.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 2 3 4 MERGED MAIN PASS. $ MERGE TOP 2300.0 6700.5 7811.5 MERGE BASE 6700.0 7811.5 8755.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 { { Depth Uni ts. . . . . . . . . . . . . . . . . . . . . .. Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2300 8755 5527.5 12911 2300 8755 ROP MWD FT/H 0.26 450.25 151.702 12760 2375.5 8755 GR MWD API 37.71 412.26 103.02 12752 2337 8712.5 RPX MWD OHMM 0.25 2000 6.3414 12738 2350.5 8719 RPS MWD OHMM 0.32 2000 6.58311 12738 2350.5 8719 RPM MWD OHMM 0.46 2000 11.5964 12738 2350.5 8719 RPD MWD OHMM 0.3 2000 19.1307 12738 2350.5 8719 FET MWD HOUR 0.18 76.71 1.25536 12738 2350.5 8719 NPHI MWD PU-S 18.06 73.57 41.3473 8801 2300 6700 FCNT MWD CNTS 404 919 597.672 8801 2300 6700 NCNT MWD CNTS 2088 3720 2712.56 8801 2300 6700 RHOB MWD G/CM 1.88 2.82 2.39353 8653 2374 6700 DRHO MWD G/CM -0.08 0.52 0.0806194 8653 2374 6700 PEF MWD BARN 2.13 12.76 3.21482 8801 2300 6700 First Reading For Entire File......... .2300 Last Reading For Entire File.......... .8755 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE PEF NCNT FCNT NPHI GR RPD RPM RPS RPX FET DRHO RHOB ROP $ ( 2 I ,( header data for each bit run in separate files. 2 .5000 START DEPTH 2300.0 2300.0 2300.0 2300.0 2337.0 2350.5 2350.5 2350.5 2350.5 2350.5 2374.0 2374.0 2375.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ # STOP DEPTH 6700.0 6700.0 6700.0 6700.0 6700.0 6700.0 6700.0 6700.0 6700.0 6700.0 6700.0 6700.0 6700.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 22-DEC-01 Insite 66.16 Memory 6701.0 2300.0 6701.0 .2 28.4 TOOL NUMBER PB02201HWRGV6 PB022 0 1 HWRGV6 PB022 0 1 HWRGV6 PB02201HWRGV6 8.500 2369.0 LSND 9.60 43.0 9.3 550 4.6 1.400 .810 1.050 2.200 75.0 134.6 75.0 75.0 It i ;,( MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2300 6700 4500 8801 2300 6700 ROP MWD020 FT/H 2.67 450.25 190.501 8650 2375.5 6700 GR MWD020 API 46.07 189.61 106.173 8727 2337 6700 RPX MWD020 OHMM 0.35 2000 4.95681 8700 2350.5 6700 RPS MWD020 OHMM 0.4 2000 4.97294 8700 2350.5 6700 RPM MWD020 OHMM 0.46 2000 5.94107 8700 2350.5 6700 RPD MWD020 OHMM 0.3 2000 14.5125 8700 2350.5 6700 FET MWD020 HOUR 0.18 48.03 0.774172 8700 2350.5 6700 NPHI MWD020 PU-S 18.06 73.57 41.3473 8801 2300 6700 FCNT MWD020 CNTS 404 919 597.672 8801 2300 6700 NCNT MWD020 CNTS 2088 3720 2712.56 8801 2300 6700 RHOB MWD020 G/CM 1.88 2.82 2.39353 8653 2374 6700 DRHO MWD020 G/CM -0.08 0.52 0.0806194 8653 2374 6700 PEF MWD020 BARN 2.13 12.76 3.21482 8801 2300 6700 First Reading For Entire File......... .2300 Last Reading For Entire File.......... .6700 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... { Version Number.......... .1.0.0 Date of Generation...... .02/05/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD ROP GR RPX RPM FET RPS $ 3 j: '\ header data for each bit run in separate files. 3 .5000 START DEPTH 6700.5 6700.5 6700.5 6700.5 6700.5 6700.5 6700.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 7778.5 7811.5 7786.5 7778.5 7778.5 7778.5 7778.5 25-DEC-01 Insite 66.16 Memory 7812.0 6701.0 7812.0 27.9 88.7 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB022 0 1 HWRGV6 PB022 0 1 HWRGV6 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 8.500 LSND 9.80 It :{ MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 40.0 9.6 450 4.0 1.000 .753 .800 1.850 100.0 135.0 100.0 100.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6700.5 7811.5 7256 2223 6700.5 7811.5 ROP MWD030 FT/H 0.26 298.29 65.9624 2223 6700.5 7811.5 GR MWD030 API 46.31 412.26 122.243 2173 6700.5 7786.5 RPX MWD030 OHMM 1.41 25.31 6.74512 2157 6700.5 7778.5 RPS MWD030 OHMM 1.41 25.51 6.92828 2157 6700.5 7778.5 RPM MWD030 OHMM 1.39 24.44 7.02425 2157 6700.5 7778.5 RPD MWD030 OHMM 1.47 24.49 7.2032 2157 6700.5 7778.5 FET MWD030 HOUR 0.3615 48.2936 0.861791 2157 6700.5 7778.5 First Reading For Entire File......... .6700.5 Last Reading For Entire File.......... .7811.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 I. '~ Date of Generation...... .02/05/02 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 ~. header data for each bit run in separate files. 4 .5000 START DEPTH 7779.0 7779.0 7779.0 7779.0 7779.0 7787.0 7812.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 8719.0 8719.0 8719.0 8719.0 8719.0 8712.5 8755.0 30-DEC-01 Insite 66.37 Memory 8755.0 7812.0 8755.0 87.8 92.4 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PBO2355HAGR4 PBO2355HAGR4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 6.125 7802.0 Flo Pro 9.20 51.0 ,I; ~ { MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 9.0 29000 3.2 .130 .063 .140 .160 69.0 149.0 69.0 69.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7779 8755 8267 1953 7779 8755 ROP MWD040 FT/H 1.28 302.86 74.857 1887 7812 8755 GR MWD040 API 37.71 82.13 65.6092 1852 7787 8712.5 RPX MWD040 OHMM 0.25 2000 12.2824 1881 7779 8719 RPS MWD040 OHMM 0.32 1622.36 13.6347 1881 7779 8719 RPM MWD040 OHMM 6.62 2000 42.9967 1881 7779 8719 RPD MWD040 OHMM 7.15 2000 54.1685 1881 7779 8719 FET MWD040 HOUR 0.33 76.71 3.93228 1881 7779 8719 First Reading For Entire File......... .7779 Last Reading For Entire File.......... .8755 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/02 ~. Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................02/05/02 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Reel Trailer Service name............ .LISTPE Date.....................02/05/02 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File ,,, ~ '- Scientific Technical Services Scientific Technical Services I ~ ( do/--~/ 9/ I ) dc.¡~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed May 01 13:30:43 2002 Reel Header Service name............ .LISTPE Date.....................02/05/01 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.....................02/05/01 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-34 PB1 501032039370 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 01-MAY-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 AK-MM-11207 M. HANIK D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 11N 4E 1905 1522 MSL 0) 51.90 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2369.0 1 , ( 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS), ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 6. MWD RUN 2 REPRESENTS WELL CD2-34 PB1 WITH API# 50-103-20393-70. THIS WELL REACHED A TOTAL DEPTH OF 7562'MD/7360'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW- COUNT BIN) SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.5" MUD WEIGHT: 9.5 - 9.8 PPG MUD SALINITY: 550 - 750 PPM CHLORIDES FORMATION WATER SALINITY: 25,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 ~ { Date of Generation...... .02/05/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE NCNT FCNT NPHI GR FET RPD RPM RPS RPX PEF DRHO RHOB ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2300.0 2300.0 2300.0 2337.0 2350.5 2350.5 2350.5 2350.5 2350.5 2357.0 2374.0 2374.0 2375.5 STOP DEPTH 7457.5 7457.5 7457.5 7521.0 7513.5 7513.5 7513.5 7513.5 7513.5 7467.0 7467.0 7467.0 7561.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ---- BASELINE DEPTH $ # MERGED PBU MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 2 MERGED MAIN PASS. $ MERGE TOP 2300.0 MERGE BASE 7561.5 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 i¡ v \~ FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2300 7561.5 4930.75 10524 2300 7561.5 ROP MWD FT/H 2.67 450.25 182.136 10373 2375.5 7561.5 GR MWD API 45.62 411.02 109.722 10369 2337 7521 RPX MWD OHMM 0.35 2000 4.96209 10327 2350.5 7513.5 RPS MWD OHMM 0.4 2000 4.98101 10327 2350.5 7513.5 RPM MWD OHMM 0.46 2000 5.78434 10327 2350.5 7513.5 RPD MWD OHMM 0.3 2000 13.0232 10327 2350.5 7513.5 FET MWD HOUR 0.18 48.03 0.737039 10327 2350.5 7513.5 NPHI MWD PU-S 18.06 80.09 41.3671 10316 2300 7457.5 FCNT MWD CNTS 404 1115 603.909 10316 2300 7457.5 NCNT MWD CNTS 2088 3720 2715.36 10316 2300 7457.5 RHOB MWD G/CM 1.88 2.88 2.40347 10187 2374 7467 DRHO MWD G/CM -0.08 0.52 0.0771365 10187 2374 7467 PEF MWD BARN 1.83 11.42 3.08106 10221 2357 7467 First Reading For Entire File......... .2300 Last Reading For Entire File.......... .7561.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/01 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI 2 header data for each bit run in separate files. 2 .5000 START DEPTH 2300.0 2300.0 2300.0 STOP DEPTH 7457.5 7457.5 7457.5 i( GR FET RPD RPM RPS RPX PEF DRHO RHOB ROP $ 2337.0 2350.5 2350.5 2350.5 2350.5 2350.5 2357.0 2374.0 2374.0 2375.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ 7521.0 7513.5 7513.5 7513.5 7513.5 7513.5 7467.0 7467.0 7467.0 7561.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O l 22-DEC-01 Insite 66.16 Memory 7562.0 2337.0 7562.0 .2 28.4 TOOL NUMBER PB022 0 1 HWRGV6 PB022 0 1 HWRGV6 PB02201HWRGV6 PB02201HWRGV6 8.500 2369.0 LSND 9.60 43.0 9.3 550 4.6 1.400 .810 1.050 2.200 75.0 134.6 75.0 75.0 ( t Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size Nsam 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 Rep Code 68 68 68 68 68 68 68 68 68 68 68 68 68 68 Offset 0 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2300 7561.5 4930.75 10524 2300 7561.5 ROP MWD020 FT/H 2.67 450.25 182.136 10373 2375.5 7561.5 GR MWD020 API 45.62 411.02 109.722 10369 2337 7521 RPX MWD020 OHMM 0.35 2000 4.96209 10327 2350.5 7513.5 RPS MWD020 OHMM 0.4 2000 4.98101 10327 2350.5 7513.5 RPM MWD020 OHMM 0.46 2000 5.78434 10327 2350.5 7513.5 RPD MWD020 OHMM 0.3 2000 13.0232 10327 2350.5 7513.5 FET MWD020 HOUR 0.18 48.03 0.737039 10327 2350.5 7513.5 NPHI MWD020 PU-S 18.06 80.09 41.3671 10316 2300 7457.5 FCNT MWD020 CNTS 404 1115 603.909 10316 2300 7457.5 NCNT MWD020 CNTS 2088 3720 2715.36 10316 2300 7457.5 RHOB MWD020 G/CM 1.88 2.88 2.40347 10187 2374 7467 DRHO MWD020 G/CM -0.08 0.52 0.0771365 10187 2374 7467 PEF MWD020 BARN 1.83 11.42 3.08106 10221 2357 7467 First Reading For Entire File......... .2300 Last Reading For Entire File.......... .7561.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/05/01 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.003 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................02/05/01 I - ilt Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Reel Trailer Service name............ .LISTPE Date.....................02/05/01 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Writing Library. ,~ Scientific Technical Services Scientific Technical Services