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Home My WebLink About204-122 • • a o r 'w -C U O ,n N > 0 r O O w O r O N 3 Jim U >O ` t Q�u Y N L O a"' 7 - Q V 7 Op +J f0 >. c0 tP ° z 0 CO Q U [V 0 C N U 4 0 E a) O _( O .= O_ C C C y,, �! G (0 0 'C Y Y C 'O O. — O Li co O N > 3 Q 0 S2 ° '_-, C O- 6 Co 0 •- r r ti n r N _c a 0 v-i 0 E L D r r ++ O Nr• M T r r CO CO N o0 V1 O -, Z Q O Z ° v > EUv cc cc u O F O O O O O O O O O O O O OCO ` N 0 ` .W J J J J J J J J J J J J C C `+- U �O y W W W W W W W W W W W W v.) a) C O F- LL IL LL LL LL LL LL LL LL LL LL LL _, > L a) 0 Q J J J J J J J J J J J J C w U) F Q < < < < < < Q < < < < u VI a) p 'C Q Q Z Z Z Z Z Z Z Z Z Z Z Z a) o a) �, aJ ° LL LL LL LL LL LL LL LL LL LL LL LL CC -0 C > +4 cu co C a) ''' d O U CU 0 t z c ( CV ) 0 C O w ra % O ` vL O Ov a. _ > u 4-,Z te ° a< a) a C V O LL d a C 0 J p_ 0 J J p_ J d E ° � 3m `o =la a -) 6aoo •6o CO t!) 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OD C N )(1 N to io u� )n )n to to N u) a. u C =a E alb' « aB W a) 3 CL 9 ~ a N O o O co ca O r N co co O ,+�'' E aJ F E c� E co s- a '_ ? LLJ (� (� C7 2 00 m Z �a d Q W r N r N N M N N C fLA 0 N Z �� C ^ 3 c0 .0 CD cD O C� � Q � ~ a a Q AKE OF ALASKA ALWA OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r. Plug Perforations r Fracture Stimulate [—, Pull Tubing .... Operations Shutdown Performed: Suspend 7 Perforate P Other Stimulate P Alter Casing i Change Approved Program II Plug for Redrill 1.... Perforate New Pool __ Repair Well Re-enter Susp Well . Other:Crystal Seal Treatment Ci 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development k Exploratory _ 204-122 3.Address: 6.API Number: Stratigraphic P Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-23215-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651,25660 KRU 1E-126 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 12612' feet Plugs(measured) None true vertical 3573' feet Junk(measured) 7131, 7860 Effective Depth measured 12573' feet Packer(measured) 0 true vertical 3572' feet (true vertical) 0 Casing Length Size MD ND Burst Collapse Conductor 82 20 108 108 0 0 Surface 3765 13.375 37915 2306 0 0 Intermediate 8061 9.625 8088 36-5 0 0 A-Sand Liner 5194 5.5 12607 3572 0 0 Perforation depth: Measured depth: 8056-8148, 8271-8333, 8799-8984, 93369918, 10087-10761, 11144-12122 True Vertical Depth: 3600-3614, 3627-3631, 3622-3612, 3594-3582, 3592-3581, 3558-3554 RECEIVED FEB 17 2016 Tubing(size,grade,MD,and TVD) 4 1/2, L-80, 7062 MD, 3406 TVD AOGCC C Packers&SSSV(type,MD,and TVD) PACKER-ZXP LINER TOP PACKER @ 7245 MD and 3452 tvd SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: SCANNEL 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 501 - 435 - 210 Subsequent to operation shut-in - - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: �`- Daily Report of Well Operations( Exploratory Ex lorato P Development ✓ ServiceIII Stratigraphic Copies of Logs and Surveys Run I— 16.Well Status after work: Oil Ri Gas 1— WDSPL Printed and Electronic Fracture Stimulation Data P GSTOR F WINJ P WAG z GINJ P 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: 315-363 Contact John Peirce (D 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature Phone:265-6471 Date v'T i--- ,u✓`/77 Form 10-404 Revised 5/2015 3//�//I RBDMS Lk' FEB 1 8 2016 Submit Original Only KUP POD 1E-126 ConocoPhif ips & Well Attribut Max Angle TD , Alaskainc, T. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Otto(ftKB) GonocoHhnhps 500292321500 WEST SAK PROD 94.07 11,058.79 12,611.0 ... Comment 025(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-126,2/11/20163:47.34 PM SSSV:NIPPLE 80 8/24/2012 Last WO: 5/3/2007 33.71 8/31/2004 Veronal sohematc(actual) Annotation Depth(ftKI3) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW osborl 10/23/2013 HANGER,25.1 11110411114 ' lg , 1161 Ca:::Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread . CONDUCTOR 20 19.124 26.0 108.0 108.0 94.00 K-55 WELDED *�' AllI`u'Casing DescriptionOD(in) ID(in) Top(ttKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -",--/,CONDUCTOR;28.0-109.0- ‘1"1°'Pill SURFACE 133/8 12.415 29.6 3,795.0 2,304.3 68.00 L-80 BTC NIPPLE,518.9 s Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 95/8 8.835 27.0 8,088.0 3,605.3 40.00 L-80 BTC-M Heat Trace;2,970.0 Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D-Sand Window 9 5/8 8.697 7,105.0 7,124.0 3,422.0 40.00 L-80 BTC-M ! Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread B-Sand Window 9 5/8 8.697 7,305.0 7,321.0 3,469.2 40.00 L-80 BTC-M SURFACE;29.6-3,795.0- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WVLen(I...Grade Top Thread A-SAND LINER 51/2 4.950 7,412.8 12,607.0 3,572.4 15.50 L-80 DWC fin GAS LIFT;4,1019 )E Liner Details 111111 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,412.8 3,487.2 79.64 PACKER HRD ZXP LINER TOP PACKER 7.000 GAS LIFT;5,280.9 7,431.4 3,490.5 79.91 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.875 MIL NIPPLE;6,9721 7,434.3 3,491.0 79.92 HANGER FLEXLOCK LINER HANGER 4.853 III 7,445.8 3,493.0 79.93 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 Mr GAUGE;8,988.7 7,465.1 3,496.4 79.94 XO BUSHING CROSSOVER BUSHING 3.930 III Casing Description I OD(in) IID(in) I Top(ftKB) I Set Depth(ftKB) I Set Depth(ND)...1Wt/Len(I ...I Grade Top Thread D-SAND LINER LEM 4 1/2 3.9581 7,029.8 7,286.2 3,461.7 12.601L-80 IBT II I Liner Details Nominal ID I I Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,029.8 3,397.4 74.96 SLEEVE 'HR'LINER SETTING SLEEVE 7.500 LOCATOR;7,039.1 7,038.1 3,399.5 74.87 XO BUSHING 4.880 SEAL ASSY;7,040.2 7,044.1 3,401.1 74.81 SBE 4.760 7,062.4 3,405.9 74.73 XO BUSHING 3.960 7,076.7 3,409.7 74.78 PACKER LEM PRODUCTION PACKER 3.870 7,093.4 3,414.1 74.85 HANGER LEM HH ABOVE 3.950 7,105.5 3,417.2 74.89 HANGER LME HH BELOW 3.680 1 f1 OSAND LINER;7,1037,283.0 3,461.0 77.07 SEAL ASSY NON-LOCATING SEAL ASSEMBLY 3.890 12,435.0.0 ' '1 Casing Description ) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1 Len ...Grade Top Thread D-Sand Window;7,105.0 ) B-SAND LINER LEM 1OD(in)41/21 3.9581 7,245.21 7,457.51 3,495.01 12.601 L-80 IBT 7,124.0 L. Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) FISH;7,131.0 7,245.2 3,452.3 76.32 PACKER ZXP LINER TOP PACKER 6.278 7,263.8 3,456.6 76.69 XO BUSHING CROSSOVER BUSHING 7"x5.5" 4.760 1 7,265.6 3,457.0 76.72 SBE SEAL BORE EXTENSION 4.750 7,284.8 3,461.4 77.10 XO BUSHING CROSSOVER BUSHING 5.5"x4.5" 3.910 • 7,292.6 3,463.1 77.26 HANGER LEM ABOVE HOOK HANGER 4.020 7. 7 7,302.5 3,465.3 77.46 HANGER LEM INSIDE HOOK HANGER 4.020 7,327.3 3,470.6 77.95 NIPPLE CAMCO'DB'NIPPLE 3.562 D-SAND LINER LEM;7,029.9- _ - 7.454.3 3.494.5 79.93 SEAL ASSY BAKER SEAL ASSEMBLY 3.875 7,286.2 11 It( Tubing Strings B-SAND LINER;7,302.6- '�14 il Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection 12,455.0 'ill Ili TUBING WO !String 41/21 3.8301 25.11 7,062.41 3,405.91 12.601L-80 14.51BT 0-Sand Window;i305.u !I Completion Details €€ Nominal ID El Top(ftKB) Top(ND)(ftKB) Top Incl Cl Item Des Com (in) 25.1 25.1 0.00 HANGER TUBING HANGER 3.900 516.9 515.4 10.66 NIPPLE CAMCO 3.875"DS Nipple @ 500' 3.875 • _.�:'r_ 6,972.1 3,382.7 75.56 NIPPLE CAMCO 3.813""DB"Nipple 3.813 I:.:_r,;i 6,987.3 3,386.5 75.40 XO 3.830 11 1 6,988.7 3,386.9 75.38 GAUGE A-well Gauge Mandrel(Weatherford)4 1/2"8rd BxP 3.950 7,039.1 3,399.8 74.86 LOCATOR LOCATOR SUB 3.890 B-SAND LINER LEM;7245.2- 7,040.2 3,400.1 74.85 SEAL ASSY Baker GBH-22 Seal Assembly 3.890 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) FISH;7,960.0 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 2,970.0 2,005.8 69.23 Heat Trace HEAT TRACE 2970'-3063' 5/3/2007 0.000 7,131.0 3,423.8 74.99 FISH TYPE 1 ISO SLEEVE STUCK IN D LEM 6/15/2010 0.000 INTERMEDIATE;2704058n, 7,860.0 3,565.7 79.90 FISH Toolstring including coil connector tagged 4/18/08 2/8/2008 0.000 IPERF;8,056.08,148.0 Perforations&Slots Shot Dens IPERF;9.271.08,333.0 Top(ND) Btm(ND) (shots) - Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,056.0 8,148.0 3,600.1 3,614.2 WS A3,WS 8/15/2004 40.0 IPERF Alternating w/blank pipe, --- A2,1E-126 slots 2.5"x.125",4 IPERF;8,799.0-8,984.0 circumferential rows/ft- Applies to all Perfs 8,271.0 8,333.0 3,627.4 3,630.7 WS A2,1E- 8/15/2004 40.0 IPERF IPERF;9,336.0-9,918.0 126 8,799.0 8,984.0 3,622.3 3,611.8 WS A2,1E- 8/15/2004 40.0 IPERF .- - 126 IPERF;18,007.0-10,761.0 _ _ 9,336.0 9,918.0 3,593.7 3,582.0 WS A2,1E- 8/15/2004 40.0 IPERF _ _ 126 IPERF;11,144.0-12,122.0 - 10.08/.0 10,761.0 3,591.7 3,581.0 WS A2,1E- 8/15/2004 40.0 IPERF - 126 IPERF;12,376.012,574.0 I A-SAND LINER;127,412.8-.0 ,607t KUP POD 1E-126 Cono &Phillips M a''" • Alaska.Inc. Canocof'h®lips ••• ...1E-128,2/11/20183:47.34 PM L Vort I a 8060896(achwp HANGER;25.1 .i--"I.a Perforations&Sloe ' t �� 1�4 Shot Dens u111. Top(ND) Btm(ND( (shots/ -"-ti CONDUCTOR,26.0-108.0' '~•IA^ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 11,144.0 12,122.0 3,558.4 3,553.8 WS A2,1E- 8/15/2004 40.0 (PERF NIPPLE,516.9 ii 126 Heat Trace;2,970.0 12,378.0 12,574.0 3,566.1 3,571.8 WS A2,1E- 8/15/2004 40.0 IPERF 126 I Mandrel Inserts SURFACE;29.6-3,795.0 . St ati Top(TVD( Valve Latch Port Size TRO Run GAS LIFT,4,101.9 R Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 4,101.9 2,409.8 CAMCO KBG-2- 1 GAS LIFT OV BK 0.250 0.0 7/10/2012 1R 4.11 GAS LIFT;5,280.9 2 5,280.9 2,825.5 CAMCO KBG-2- 1 GAS LIFT OV BK 0.250 0.0 5/22/2012 1R Notes:General&Safety NIPPLE,6,972.1 End Date Annotation taw 9/8/2004 NOTE:TRI-LATERAL WELL:1E-126(A-SAND),1E-126L1(B/C-SAND),1E-126L2(D-SAND) GAUGE;6,988.7 4/18/2008 NOTE:ESTIMATE TOP OF FISH @ 7860'CTMD WM MIR 2/23/2009 NOTE:View Schematic w/Alaska Schematic9.0 1 - LOCATOR.7,039.1 VOL SEAL ASSY;7,040.2 -. ME 4' D-SAND LINER,7,103.4- 1- 12,435.0\ k D-Sand Window;7,105.0- 7,124 0 - 7,124.0 FISH;7,131.0 D-SAND LINER LEM;7029.8- 7,286.2 1 )19 B-SAND LINER;7,302.6- ;1 12,4558\ B-Sand Window,7,305.0- p 7,321.0 I it Ili i B-SAND LINER LEM;7,245.2- 7,457.5 it FISH;7860.0 INTERMEDIATE;27.0-8,088.0, IPERF;8,0560-8148.0 IPERF;8,271.05,333.0 IPERF;8,799.0-8 984.0 IPERF;9,336.0-9,918.0 IPERF;10,087.0-10,761.0 IPERF.11,144.0-12,122.0 IPERF,12,378 812.574 0 _ A-SAND LINER,7,4128- 12607.0 \\\\ 01E-105 Crystal Seal Treatment 40 DATE SUMMARY 5/24/2015 PULLED 5/16" CHOKE ON DB LOCK @ 503' RKB. BRUSHED AND FLUSHED TBG TO 7164' RKB. SET 1/4"CHOKE ON 3.81" DB LOCK @ 7164'RKB. COMPLETE. 7/13/2015 GAUGED TBG TO 3.86"TO 503' RKB; 3.79"TO CMU @ 7164' RKB. PULLED CHOKE @ 7164' RKB. READY FOR CTU. 7/14/2015 Pumped 25 bbls diesel down Tbg. Job complete. 7/21/2015 B&C CTU#1: RETREIVE TYPE 1 ISO-SLEEVE FROM B LEM AT 7524'WITH BAKER G- FORCE JARS. WHILE GOING TO WELL FOR SECOND RUN, UNABLE TO COME UP ON TROLLEY WINCH. MECHANIC CALLED OUT, WILL RESTART IN THE MORNING. 7/24/2015 B&C CTU#1: SETA SAND ISOLATION PLUG & PRONG IN DB NIPPLE AT 7578'WITH BAKER SI-DI HIPP TRIPPER, TWO RUNS. SET TYPE 1 DIVERTER IN B LEM AT 7524'. WILL RETURN IN THE MORNING TO SET A TYPE 2 ISO SLEEVE ACROSS D LEM. 7/25/2015 B&C CTU#1: SET A TYPE 2 ISO SLEEVE ACROSS D LEM AT 7258' WITH BAKER SI-DI HIPP TRIPPER. READY FOR ELINE TRACTOR PERF. 8/7/2015 UNABLE TO TRACTOR PAST 8225'. MADE MULTIPLE ATTEMPS AND TRIED TO USE A PUMP ASSIST BUT WERE UNABLE. DECISION MADE TO RDMO AND GO TO NEXT JOB 8/13/2015 B&C CTU#1: PERFORM DEPTH DETERMINATION LOGIN B LATERAL WITH PDS MEMORY UTILIZING A PUMP THROUGH TOOL CARRIER. DRY TAG AT 11226'CTMD(PERF DEPTH FROM 8945'-8950'). LOG PERF INTERVAL AND PAINT TIE IN FLAGS AT 8900'AND 9000' CTMD. WILL RETURN THE MORNING TO PERFORATE. 8/20/2015 B&C CTU#1: PERFORATE MBE INTERVAL IN B LATERAL FROM 8945'- 8950' RKB WITH SLB 2-IN POWERFLOW HSD GUNS (2006FP 6SPF, EHD 0.45",4.5"PEN). DEPTH CORRECTED TO TAG FROM LAST MEMORY LOG, REFERENCED TO IPROF DATED 6-MAR- 06. WELL LEFT FREEZE PROTECTED AND SHUT IN. READY FOR CRYSTAL SEAL. 9/22/2015 INJECTIVITY TEST. PUMPED 2OBBLS DIESEL @ 1 BPM DOWN THE TUBING @ 200PSI. JOB COMPLETE. 9/23/2015 Perform MBE treatment with 2,805 lbs (51 sacks) of 4 millimeter CrystalSeal per design. Well freeze protected and to be left shut-in. ***Job in Progress with more steps in Procedure to follow.*** 9/27/2015 Injectivity test,pump 20 bbls dsl down tbg at lbbl/min @ 625 psi,job complete •TE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate E Pull Tubing E Operations Shutdown Performed: Suspend T Perforate Other Stimulate IT Alter Casing Change Approved Program Plug for Redrill IT Perforate New Pool I Repair Well r Re-enter Susp Well IT Other.Crystal Seal Treatment Fi 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory IT 204-122 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23215-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651,25660 KRU 1E-126L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 12612' feet Plugs(measured) None true vertical 3573' feet Junk(measured) 7131, 7860 Effective Depth measured 12573' feet Packer(measured) 0 true vertical 3572' feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse Conductor 82 20 108 108 0 0 Surface 3765 13.375 37915 2306 0 0 Intermediate 8061 9.625 8088 36-5 0 0 B-Sand Liner 5153 5.5 12455 _ .3..3K... 0 0 Perforation depth: Measured depth: 7334-9768, 9893-12422 True Vertical Depth: 34712-3438, 3437-3397 Tubing(size,grade,MD,and ND) 4 1/2, L-80, 7062 MD, 3406 TVD FEB 1 7 2016 Packers&SSSV(type,MD,and ND) PACKER-NONE AOGCC SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in - - - - Subsequent to operation shut-in - - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: 1,1-• Daily Report of Well Operations F Exploratory A Development Service Stratigraphic Copies of Logs and Surveys Run 16.Well Status after work: Oil F Gas IT WDSPL Printed and Electronic Fracture Stimulation Data I— GSTOR r WINJ IT WAG IT GINJ E SUSP IT SPLUG 1- 17. 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: 315-364 Contact John Peirce @ 265-6471 Email John.W.Peirce@conocoohilliDs.com Printed Name John Peirce Title Sr. Wells Engineer Signature /J (� Phone:265-6471 Date aii 61 7#474 PrL. zl1 q I t4 Form 10-404 Revised 5/2015 RBDMS t.- FEB 1 8 2016 Submit Original Only 000rl 6 l �Q KUP f•►D • 1E-126L1 ConocoPhillips Well Attributes Max Angle&MD TD s`llrl"ik<f,S'..0 Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) • CorwcoPhiitilx 500292321560 WEST SAK PROD 94.05 9,260.53 12,468.0 An° • VComment H2S(ppm) Date Annotation End Date KB-Grd(k) `Rig Release Date 1E-126L1,2811/2016 3 47 57 PM SSSV:NIPPLE 80 8/24/2012 Last WO: 5/3/2007 33.71 8/31/2004 Vertical schematic(actual) Annotation Depth(ttKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW osborl 10/23/2013 k 11 HANGER.25.1 I l — asing rings �� el CasingDescriptionI00(in) IID(in) ITop(ftKB) ISet Depth(ftKB) ISet Depth)TVD(...I WOLen(I...I Grade I Top Thread �I� BSANDLINER 51/2 4950730261245583,394.9 15.50L-80 DWC � � � Liner Details Nominal ID %P 'III ii Top(ftKB) I Top(WD)(ftKB) Top Incl(°) Item Des Com (in) - - CONDUCTOR.26 0-108-- ^ 7,302.6 1 3,465.3 77.46 HANGER BAKER MODEL B-1 HOOK HANGER 4.760 NIPPLE;516.9 �� Perforations&Slots Shot Den Heat Trace;2,970.0 Top(TVD) Btm(WD) (shoal Top(ftKB) Btm(ftKB) (ftKB) (ttKB) Zone Date k) Type Com 7,334.0 9,768.0 3,471.7 3,437.8 WS B,WS C, 8/31/2004 40.0 IPERF Alternating w/blank pipe, IPERF I 1 E-126L1 slots 2.5"x.125",4 circumferential rows/ft- Applies to all Perfs SURFACE;29.6-3,795.0—) 1 1 11' '1 1 GAS LIFT;4,101 9 1 I. . Notes:General&Safety End Date Annotation II NOTE:TRI-LATERAL WELL:1E-126(A-SAND),1E-126L1(B/C-SAND),1E-126L2(D-SAND) 1111 9/8/2004 • 1 GAS L'i F.5.2806 - la NIPPLE;6,972.1 il GAUGE;6,988.7 e iii in 1 1 I I LOCATOR;7,039.1 MI, SEAL ASSY;7,040.2 _ I- 11 a ii 11 D-SAND LINER,7,103.4 I a 12,435.0 8'� It. D-Sand Window,7,105.0- 99 7,124.0 1 FISH;7,131.0 1 IV:', 1 D-SAND LINER LEM;7,029.8- -MK 3 7,286.2 ryry 'i 1( B-Sand Window;7,305.0-0 i B 8 7,321.0 V INTERMEDIATE;27.08,088.0 'l ;l B-SAND LINER LEM;7,245.2- 4 it 7,457.5 I` 11 4 i. IPERF,7,334.0-9,768.0 (PERF;9,893.0-12,422.0—. B-SAND LINER;7,302.6- ` 12,455.8 l E-105 Crystal Seal Treatment • DATE SUMMARY 5/24/2015 PULLED 5/16" CHOKE ON DB LOCK @ 503' RKB. BRUSHED AND FLUSHED TBG TO 7164' RKB. SET 1/4"CHOKE ON 3.81" DB LOCK @ 7164' RKB. COMPLETE. 7/13/2015 GAUGED TBG TO 3.86"TO 503' RKB; 3.79"TO CMU @ 7164' RKB. PULLED CHOKE @ 7164' RKB. READY FOR CTU. 7/14/2015 Pumped 25 bbls diesel down Tbg. Job complete. 7/21/2015 B&C CTU#1: RETREIVE TYPE 1 ISO-SLEEVE FROM B LEM AT 7524'WITH BAKER G- FORCE JARS. WHILE GOING TO WELL FOR SECOND RUN, UNABLE TO COME UP ON TROLLEY WINCH. MECHANIC CALLED OUT, WILL RESTART IN THE MORNING. 7/24/2015 B&C CTU#1: SETA SAND ISOLATION PLUG& PRONG IN DB NIPPLE AT 7578'WITH BAKER SI-DI HIPP TRIPPER, TWO RUNS. SET TYPE 1 DIVERTER IN B LEM AT 7524'. WILL RETURN IN THE MORNING TO SET A TYPE 2 ISO SLEEVE ACROSS D LEM. 7/25/2015 B&C CTU#1: SET A TYPE 2 ISO SLEEVE ACROSS D LEM AT 7258' WITH BAKER SI-DI HIPP TRIPPER. READY FOR ELINE TRACTOR PERF. 8/7/2015 UNABLE TO TRACTOR PAST 8225'. MADE MULTIPLE ATTEMPS AND TRIED TO USE A PUMP ASSIST BUT WERE UNABLE. DECISION MADE TO RDMO AND GO TO NEXT JOB 8/13/2015 B&C CTU#1: PERFORM DEPTH DETERMINATION LOG IN B LATERAL WITH PDS MEMORY UTILIZING A PUMP THROUGH TOOL CARRIER. DRY TAG AT 11226' CTMD (PERF DEPTH FROM 8945'-8950'). LOG PERF INTERVAL AND PAINT TIE IN FLAGS AT 8900'AND 9000' CTMD. WILL RETURN THE MORNING TO PERFORATE. 8/20/2015 B&C CTU#1: PERFORATE MBE INTERVAL IN B LATERAL FROM 8945'- 8950' RKB WITH SLB 2-IN POWERFLOW HSD GUNS(2006FP 6SPF, END 0.45", 4.5"PEN). DEPTH CORRECTED TO TAG FROM LAST MEMORY LOG, REFERENCED TO !PROF DATED 6-MAR- 06. WELL LEFT FREEZE PROTECTED AND SHUT IN. READY FOR CRYSTAL SEAL. 9/22/2015 INJECTIVITY TEST. PUMPED 2OBBLS DIESEL @ 1 BPM DOWN THE TUBING @ 200PSI. JOB COMPLETE. 9/23/2015 Perform MBE treatment with 2,805 lbs (51 sacks)of 4 millimeter CrystalSeal per design. Well freeze protected and to be left shut-in. ***Job in Progress with more steps in Procedure to follow.*"" 9/27/2015 Injectivity test,pump 20 bbls dsl down tbg at lbbl/min @ 625 psi,job complete OF(r., \ 1�j,sATHE STATEAlaska Oil and Gas ��, ofALAS�:A Conservation Commission t riti — 333 West Seventh Avenue • GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907,279.1433 OF ALAS�P Fax: 907.276 7542 Sa��G� JULI0 www aogcc alaska gov G John Peirce � I 9"-‘a- Sr. —Wells Engineer 4:2 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-126 Sundry Number: 315-363 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ' / Daniel T. Seamount, Jr. Commissioner DATED this / day of June, 2015 Encl. • RECEIVED ED STATE OF ALASKA , . 3KA OIL AND GAS CONSERVATION COM. .,ION JUN 12 2015 5 GCJA(9.),,,4 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC - 1 Type of Request Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate E Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other.Crystal Seal Treatment F7, 2 Operator Name 4 Current Well Class 5.Permit to Drill Number ConocoPhillips Alaska, Inc. + Exploratory r Development p, 204-122• 3 AddressStratigraphic r Service r 6.API Number P.O. Box 100360,Anchorage,Alaska 99510 50-029-23215-00 • 7 If perforating, What 8 Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No ' KRU 1 E-126 9 Property Designation(Lease Number). 10 Field/Pool(s): ADL 25651,25660 • Kuparuk River Field/West Sak Oil Pool - 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft). Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth TVD(ft) Plugs(measured) Junk(measured) 12612 3573 - 12573' - 3572'- none 7131',7860 Casing Length Size MD ND Burst Collapse CONDUCTOR 82 20 108' 108' SURFACE 3765 13.375 3795' 2306' INTERMEDIATE 8061 9.625 8088' 3605' A-SAND LINER 5194 5.5 12607' 3572' Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft) perfs from 8056-12574 - 3600-3572 4.5 L-80 7039 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER-LEM PRODUCTION PACKER MD=7077 TVD=3410 • PACKER-ZXP LINER TOP PACKER MD=7245 TVD=3452 • PACKER-HRD ZXP LINER TOP PACKER MD=7413 TVD=3487 • NIPPLE-CAMCO DS NIPPLE MD=517 TVD=515 12 Attachments: Description Summary of Proposal ' 13 Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r- Service r 14 Estimated Date for Commencing Operations 15. Well Status after proposed work: 7/8/2015 OIL WINJ r WDSPL r Suspended r 16 Verbal Approval Date GAS r WAG r GSTOR r SPLUG r Commission Representative GINJ r Op Shutdown r Abandoned r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Peirce @ 265-6471 Email John W.Peirce@conocoDhilliDs corn Printed Name John Peirce Title: Sr.Wells Engineer Signature .-�� Phone 265-6471 Date 6(iiiLc 7,4_14,1?—/A,� Commission Use Only Sundry Number: Conditions of approval Notify Commission so that a representative may witness 31 G ^3(„e� Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other. Spacing Exception Required? Yes ❑ No / Subsequent Form Required: /c — 4 c L,- ATeEDBCOMMISSION Date C.i ` /1 Approv- application is valid for 12 months from the date of approval. VT L «�� pp pp If Submit Form and Form 10-403 Revised 5/2015 g (2,)/(64- achments in Duplicate ORIGINAL . m67� RBDM JUN Z52015 . i KUP PROD 1E-126 ConocoPhillips a Well Attributes Max Angle&MD TD <118Ske,II1G. Wellbore API/UWI Flcld Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ynpe, 500292321500 `NI-S1 SAK PROD 94.07 11058.79 12,611.0 ... Comment H2S(ppm) Date Annotation - End Date KB-Grd(ft) -Rig Release Date 1E-12610/23/20131:51.15 AM SSSV:NIPPLE 80 8/24/2012 Last WO: 5/3/2007 33.71 8/31/2004 Vertical schemat C(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - -- -- - Last Tag: Rev Reason:WELL REVIEW osborl 10/23/2013 HANGER;251 `I op l .Casing Strings I �t�.. ,'';', Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth IND)... WULen(I...Grade Top Thread ii II CONDUCTOR 20 19.124 26.0 108.0 108.0 94.00 K-55 WELDED X1 9 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE _ 133x8 12.415 29.6 3,795.0 2,304.3 68.00 L-80 BTC �/ CONDUCTOR 28.4108.0 •1"1", Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread NIPPLE.516.9 _ INTERMEDIATE 95/8 8.835 270 8,088.0 3,605.3 40.00 L-80 BTC-M • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Heat Trace;2970.0 D-Sand Window 95/8 8.697 7,1050 7,124.0 3,422.0 4000 L-80 BTC-M Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • B-Sand Window 95/8 8.697 7,305.0 7,321.0 3,469.2 40.00 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)..,WVLen(I...Grade Top Thread A-SAND LINER 5 12 4.950 7,412.8 12.607.0 3572.4 15.50 L-80 DWC SURFACE;29.6-3,795.0- A Liner Details Nominal ID GAS LIFT;4,101.9 - Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,412.8 3,487.2 79.64 PACKER HRD ZXP LINER TOP PACKER 7.000 7,431.4 3,4905 79.91 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.875 GAS LIFT;5,28097,434.3 3,491.0' 79.92 HANGER FLEXLOCK LINER HANGER 4.853 MI 7,445.8 3,493.0 79.93,SBE 190-47 CASING SEAL BORE EXTENSION 4.750 ' NIPPLE;6,9721 I 7,465.11 3,496.41 79.941 X0 BUSHING 'CROSSOVER BUSHING ' 3.930 Casing Description IOD(in) IID(in) l Top(ftKB) I Set Depth(ftKB) 'Set Depth(ND)...I Wt/Len(1.1Grade IMP Thread GAUGE;6,988.7 - D-SAND LINER LEM 4 12 3.958 7,029 8 7,286.2 3.461,7 12.60 L-80 IBT Liner Details Nominal ID Top(ftl(B) TOP(TVD)(ftNB) Top Incl(°) Item Des Com (in) 7,029.8 3,397.4 74.96 SLEEVE 'HR'LINER SETTING SLEEVE 7.500 7,038.1 3,3995 74.87 XO BUSHING 4.880 LOCATOR;7,039.1 _ 7,044.1 3,401.1 74.81 SBE 4.760 SEAL AsSV;7,000.2 - 7,062.4 3,405.9 74.73 XO BUSHING 3.960 el 7,076.7 3,409.7 74.78 PACKER LEM PRODUCTION PACKER 3.870 • ,-.1 7,093.4 3,414.1 74.85 HANGER LEM HH ABOVE 3.950 7,105.5 3,417.2 74.89 HANGER LME HH BELOW 3.680 7,283.0 3,461.0 77.07 SEAL ASSY NON-LOCATING SEAL ASSEMBLY 3.890 • D-SAND LINER;7,103.4 ' ( Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WVLen(1...Grade Top Thread 'I 12.435.0, B-SAND LINER LEM 1 4 1/21 3.958 7,245.21 7,457.51 3.495.0] 12.601 L-80 1 IBT D-Sand Window;7,105.0. 7,124.0 Liner Details r Nominal ID Top(kKB) Top(TVD)(ftKB) Top Incl C) Item Des Corn (in) 7,245.2 3,452.3 76.32 PACKER ZXP LINER TOP PACKER 6278 FISH;7,131.0 7,263.8 3,456.6 76.69'XO BUSHING CROSSOVER BUSHING 7"x5.5" 4.760 7,265.6 3,457.0 76.72 SBE SEAL BORE EXTENSION 4.750 7,284.8 3,461.4 77.10 XO BUSHING CROSSOVER BUSHING 5.5"x4.5" 3.910 7,292.6 3,463.1 77.26 HANGER LEM ABOVE HOOK HANGER 4.020 _ 7,302.5 3,465.3 77.46 HANGER LEM INSIDE HOOK HANGER 4.020 s. 7,327.3 3,470.6 77.95 NIPPLE CAMCO'DB'NIPPLE 3.562 -T-` 7,454.3 3494.5 79.93 SEAL ASSY BAKER SEAL ASSEMBLY 3.875 DSAND LINER LEM;7,029.8- = f) 7,2862 Tubing Strings Tubing Description 'String Ma...IID(in) 'Top(ftKB) 'Set Depth Ik..l Set Depth(ND)(...I Wt(ldit) 'Grade 'Top Connection 8-SAND LINER;7,302.6- TUBING WO 41/2 3.830 251 7,0624 3,405.9 12.60 L-80 4.5 IBT 12.455.8A 3080- Completion Details B-Sand Window: 5 , P 7.321.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 25.1 25.1 0.00 HANGER TUBING HANGER 3.900 516.9 515.4 10.66 NIPPLE CAMCO 3.875"DS Nipple @ 500' 3.875 6,972.1 3,382.7 75.56 NIPPLE CAMCO 3.813""DB"Nipple 3.813 6,987.3 3,386.5 75.40 XO 3.830 I.illFI 6,988.7 3,386.9 75.38 GAUGE A-well Gauge Mandrel(Weatherford)4 1/2"8rd BxP 3.950 7,039.1 3,399.8 74.86 LOCATOR LOCATOR SUB 3.890 9-SAND LINER LEM;7.2452- 7,040.2 3.400.1 74.85 SEAL ASSY Baker GBH-22 Seal Assembly 3.890 7,457.5 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl FISH;7,860.0 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 2370.0 2,005.8 69.23 Heat Trace HEAT TRACE 2970'-3063' 5/3/2007 0.000 _ 7,131.0 3,423.8 74.99 FISH TYPE 1 ISO SLEEVE STUCK IN D LEM 6/15/2010 0.000 INTERMEDIATE;27.08,088.0 7,860.0 3,565.7 79.90 FISH Toolstring including coil connector tagged 4/18/08 2/8/2008 0.000 (PERF;8.056.0-6.148.0-r..-- Perforations&Slots Shot - - Den IPERF;8,271.0.8,333.0- Top(ND) Btm(ND) (shots/' Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 8,056.0 8,148.0 3,600.1 3,614.2 WS A3,WS 8/15/2004 40.0 IPERF Alternating w/blank pipe, - - A2,1E-126 slots 2.5"x.125",4 IPERF;8.799.0-8.984.0- circumferential rows/ft- - - Applies to all Perla - - 8,271.0 8,333.0 3,627.4 3,630.7 WS A2,1E- 8/15/2004 ' 40.0 IPERF IPERF;9,336.05.918.0- 1 26 8,799.0 8,984.0 3,622.3 3,611.8 WS A2,1E- 8/15/2004 40.0 IPERF - 126 IPERF;10,887.0-10.761.0- 9,336.0 9,918.0 3,593.7 3,582.0 WS A2,1E- 8/152004 40.0 IPERF - 126 1PERF;11.1440-12.122.0 - 10,087.0 10,761.0 3,591.7 3,581.0 WS A2,1E- 8/15/2004 40.0 IPERF - 126 I IPERF;12,378.0.12.574.0 - _ A-SAND LINER;7.412.8- 12,607.0 • KUP PROD 1E-126 ConocoPhillips s Kaska,Inc. c.onecdkwpa 1E-126.1023/2013 11:51'16 AM Vertical schematic(actual) or HANGER.251—..--. Perforations&Slots i Shot I 1 I Top(TVD) Btm(TVD) (ahs Top OMB) Btm(RKB) (RKB) (MB) Zone Date t) Type Com hM CONDUCTOR,Zed-108:0•• MPI 12,122.0 3,558.4 3,553.8 WS A2,1E- 8/152004 40.0 IPERF NIPPLE;516.9 I 444 _ 126 12,378.0 12,574.0 3,566.1 3,571.8 WS A2,1E- 8/152004 40.0 IPERF Heat Trace;2,970.0 126 Mandrel Inserts St • ati c SURFACE;29.6-3,795.0— A I Top(ND) Valve Latch Port Size TRO Run No Top(ftKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date in 1 4,101.9 2,409.8 CAMCO KBG-2- 1 GAS LIFT OV BK 0.250 0.0 7/10/2012 GAS LIFT;4,101.9 1R • 2 5,280.9 2.825.5 CAMCO KBG-2- 1 GAS LIFT OV -BK 0.250 0.0 5/22/2012 IR GAS LIFT;5,2800 Notes:General&Safety - End Date Annotation NIPPLE;6972.1 . 9/8/2004 NOTE:TRI-LATERAL WELL:1E-126(A-SAND),1E-126L1(B/C-SAND),1E-126L2(D-SAND) 4/18/2008 NOTE:ESTIMATE TOP OF FISH @ 7860'CTMD GAUGE;6,988.7 —a. 2/23/2009 NOTE:View Schematic w/Alaska Schematic9.0 9 _ LOCATOR;7,039.1 SEAL ASSY;7,040.2 _S D-SAND LINER;7,103.4- 12,435.0 ,103.412,435.0 D-Sand Window;7,105.0- 7,124.0 FISH;7,131.0 MI6 D-SAND LINER LEM;7,029.8- = _ 7,286.2 8-SAND LINER;7,302.6- 12,4558\ ,302.6-12,455,8\ B-Sand Window;7,3050- 7.321.0 _1 SEI I.I &SAND LINER LEM;7,245.2- 7,457.5 ,: FISH;7,860.0 INTERMEDIATE;27.0-8,088.0, IPERF;8,056.08,148.0— (PERF;8.271.0.8,333.0 IPERF;8,799.0.8,9840 IPERF;9,336.0.9,918.0 IPERF;10,087.&10,761.0IPERF;11,144.0-12,122.0— IPERF;12,378.012,5740��ff A-SAND LINER;7,412.8- 1l- 12,607.0� Treatment Proposal for 1E-105L1 to 1E-126L1 B Sand MBE's 1E-105 tri-lateral injector was drilled & completed in 2005 with laterals in West Sak A, B, & D sands. 1E-105L1 B Sand lateral has 5.5", L-80 slotted liner.Two MBE's occurred in 1E-105L1. The first occurred 12/28/05 from 1E-105 to 1E-126 producer. A 6/20/06 IPROF found a B MBE in 105L1 at 8750' RKB taking all PWI at 2711 BWPD. On 9/4/11, a Crystal Seal job pumped in 105L1 to seal this MBE. The treatment lasted -2 years before rising WC% at 1E-126 indicated another MBE occurred from 1E-105. An IPROF 1/28/14 in 1E-105L1 shows the B MBE at 8750' RKB again taking some PWI, plus a new MBE now at 8950 - 9150' RKB area. 1E-105 lost PWI May 2014 due to 1E PWI line SI for repairs, then PWI resumed April 2015 to 1 E-105L2 only (105L1 is Iso-Slv'd off due to B MBE's). A job procedure is now proposed to seal off the B MBE's to return 1 E-105L1 lateral to PWI service: Slickline: 1) A 0.25" choke was set on 5/24/15 on a 3.81" DB Lock at 7164' RKB in a Camco Sliding Sleeve. RIH & pull this choke to enable CT access to 1E-105L1 B Sand lateral. RD SL. Coil Tubing: 2) RIH to pull the Iso-Sly set across the B LEM at 7524' RKB. 3) RIH to set a Diverter in the B LEM at 7524' RKB. 4) RIH to set a Iso-Sly across the D LEM at 7258' RKB. RD CTU. E-line: 5) RIH with 5' perf gun on dual tractors to shoot 6 spf, 60 deg ph large hole perfs at 8945 - 8950' RKB. This perfs 5.5" slotted liner at the lower new MBE at -8950' to allow CrystalSeal entry through slotted liner to the MBE. Fire gun. POOH. RD. Perfs were shot in 2011 at the upper MBE at -8750'RKB. Coil Tubing: 6) RIH with a large down port nozzle on CT. Park nozzle at 8700' RKB above both MBE's, and then pump a Step Rate Injection Test (SRIT) followed by a Crystal Seal treatment as follows: a) Pump SRIT with Seawater down CT to MBE's. Select a steady treatment rate (likely to be in the 1.5 - 2 bpm range) to be held constant during the treatment (steps b through e) to Flush (step f) to monitor MBE response to treatment and to watch Crystal Seal screenout develop during the slurry pumping. Use 2% KCL for making Crystal Seal slurry (or Seawater of adequate salinity), then pump: b) 2% KCL Water with 0.05 ppg Crystal Seal (using 4 mm mesh all stages b through e) down CT. Each stage volume TBD during pumping based on treating pressure seen during stage. Then pump, c) 2% KCL Water w/0.10 ppg Crystal Seal down CT, or go to Flush (step f) if screen out develops. d) 2% KCL Water w/0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCL Water w/0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. Once Crystal Seal concentrations > 0.10 ppg starts exiting the nozzle, begin POOH with nozzle continuously at 5 - 10 fpm while pumping away all the remaining slurry to be pumped until the nozzle reaches a safe parking point just above the B LEM (7524' RKB). This practice is used now to help mitigate development of very sudden heavy PU weights that have been experienced during previous Crystal Seal treatments where the nozzle stayed parked at the MBE while pumping away all the Crystal Seal stages with only periodic weight checks. Continuously POOH allows for continuous monitoring of PU weight development to provide early warning re: rising PU weight issues. Once the nozzle reaches final parking location at the B LEM, Crystal Seal stacking behind CT cannot occur, since only CT x Tbg dead leg exists above the B LEM and pumping of at least 0.3 bpm will be kept down the CT backside. f) If screen out occurs, pump 1 CT volume Seawater Flush to displace Crystal Seal from CT to well while POOH and pumping 0.5 bpm 2% KCL down CT backside to mitigate Crystal Seal stacking behind CT (that can lead to excessive PU weight). Even if screen out is not seen prior to Flush, keep a minimum of 0.3 bpm of 2% KCL down the CT backside at all times to help keep Crystal Seal flushed away from CT backside to mitigate elevated PU weights. Pump 1 full CT volume of 2% KCL to displace remaining Crystal Seal Slurry from CT to liner while POOH, then swap to Diesel FP down CT, followed by 1 CT volume of Diesel to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait at least 6 hours to let the Crystal Seal particles fully hydrate and swell in the MBE's before returning 1E-105L1 to PWI. 7) RIH with jet swirl nozzle and tag top of Crystal Seal in well, then jet down through Crystal Seal to as deep as possible to shear & mechanically break all Crystal Seal remaining in the liner. POOH w/CT. Place 1 E-105L1 on PWI to evaluate the results of the MBE treatment. 8) RIH with IPROF BHA. Memory log down & up passes to verify if the MBE's are sealed off or still taking PWI. Wait 2 hours, then log a cool back pass. POOH with CT, RD CTU. Return 1 E-105L1 to PWI service. Leave 1E-105L1 on PWI to `B sand only' for a few months to ensure that the B MBE's continue to appear to be sealed off. Depending on surveillance, evaluate retreatment options for the MBE's, if needed. If several months have passed without obvious indications of treatment failure, proceed to normal up the well to resume unobstructed PWI to the A sand and D sand laterals as follows: Coil Tubing: 9) RIH to pull the Iso-Sly across the D LEM at 7258' RKB. 10) RIH to pull the Diverter in the B LEM at 7524' RKB. Return 1 E-105 to PWI service to all 3 laterals. XHVZE e e Image Project Well History File Cover Page This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q LJ. - L J. ~ Well History File Identifier Organizing (done) D Two-sided 1111111111111I11111 D Rescan Needed 1/11111" 1111 ""11 R~AN \.Ø' Color Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, Norrype: D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: BY: ~ Date: lj / fj JOb I D Other:: 151 W1P BY: ~ Date: uJ g-, 010 3 0 "1//11" 11I11 "'II 151 mP Project Proofing Scanning Preparation BY: +b = TOTAL PAGES 47 (Count does not include cove~ P 151 "1//111111//1 ,,1/1 Date: Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~S BY: ~ Date: II J ~ /D~ NO ISIVVlf NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: 151 111/1111111I111 11/1 Scanning is complete at this point unless rescanning is required. ReScanned "111111I" III "'II BY: Maria Date: 151 Comments about this file: Quality Checked II 1111/111/1/1111/1 10/6/2005 Well History File Cover Page.doc ~~~ • STATE OF ALASKA ~U~ ~ Q ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL O~I'~~~'S• ~ommi~sion 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ her ~ efL1-LEM Isolation Sleeve • Alter Casing ^ Pull Tubing ^ Perforate 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 ^ 204-122 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23215-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1 E-126 8. Property Designation: • 10. Field/Pool(s): ADL 25651& 25660 Kuparuk River Field /West Sak Oil Pool ~ 11. Present Well Condition Summary: Total Depth measured 12612' ~ feet true vertical 3573' feet Plugs (measured) Effective Depth measured 12573' feet Junk (measured) true vertical 3572' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' ' ~~+~~~ ~UN 1 ~ ~~~$ ' " ' i SURFACE 3696 2304 13-3/8 3795 INTERMEDIATE 8060' 9-5/8" 8088' 3605' L2 WINDOW 20' 9-5/8" 7125' 3422' L1 WINDOW 16' 9-5/8" 7321' 3469' LINER 5195' 5-1/2" 12607' 3572' Perforation depth: Measured depth: 8056'-8148', 8271'-8333', 8799'-8984', 9336'-9918', 10087'-10761', 11144'-12122', 12378'-12574' true vertical depth: 3600'-3614', 3627'-3630', 3622'-3612', 3594'-3582', 3592'-3581', 3558'-3554', 3566'-3572' Tubing (size, grade, and measured depth) 4-112" , L-80, 7062' MD. Packers &SSSV (type & measured depth) PKR= Baker PKR, ZXPLiner Top PKR, and HRp ZXP Liner Top PKR PKR= 7076', 7245', and 7412' SSSV= NIP SSSV= 517' 12. Stimulation or cement squeeze summary: ~r'c ~ti:~~~4~ v.SE`.~ ~ Sc~, acs. ~-~ Intervals treated (measured) N~q , E,-`~ ~/i [ aQt~.~ r~~~ ~`~~~~ \ 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 387 168 29 1146 205 Subsequent to operation 818 126 908 863 219 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development^ Service ^ Daily Report of Welt Operations _X 16. WeA Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz title Production Engineering Technic/i~n ~ ~tci Phone: 265-6471 Date ,~ 6 ~~~1 Signature ~ , s " ~ %~ G- Pre red b Sharon All u Drake 263-4612 ~~'n~G., . /G. Og Form 10-404 Revised 04/2006 ('~'~ ~'°`~ ~ ~~ } ~,, i Subm~!' ~'~~~.... 1 ,~;~ • 1 E-126 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/14!2008 RUN TYPE 1 ISOLATION SLEEVE INTO B-SAND LEM.NOTIFY DSO THAT B-SAND HAS BEEN SHUT OFF AND WELL IS READY TO BRING ONLINE.JOB COMPLETE. MHA.(2.25" x 1.38' CTC)(2.13" x 1.38' DBPV)(2.13" x 1.58' DISCO)(2.72" x 1.0' XO)(2.87" x 4.40' HIPP-TRIPPER)(3.13" x .86' XO)(3.50" x 1.86' GS SPEAR 4")(3.688" x 19.0' TYPE 1 ISO SLEEVE) OAL=31.46' ConocoPhillips Alaska, Inc. KRU 1 E-126 1E-126 API: 500292321500 WeIITy e: PROD An le TS: deg @ SSSV Type; - -- NIPPLE Ori Com letion: _ 8/31/2004 An Igo TD: _ 89 dep @ 12612 Annular Fluid:' Last W/O: _ _ _ _ 5/3/20 07 f~ev Reason: __ _ _ N/ORKOVER Reference Log: 28' RKB _ Ref Log Date: . _ st U ate: L a 5/14/2007 TUBING Last Tag: TD: _ 12611 ftKB _ _ (0.7062 Last Ta Date: i Max Hole An le: _ 94 d 11059 oD:a.SOO, Casin String - A_ LL 3i'R1N(35 ID:3s5e) De_s_crl >~n ___ _ Size _ _ _ Top B ottom TVD Wt Grade Thread I CONDUCTOR _20.000 _ 0_ _ __ _ 108 108 94.00 _ K-55 WELDED SURFACE 13.375 __ 0 _ 3795 2303 68.00 L-80 BTC PRODUCTION 9.625 0 _ 8088 3605 4 0.00 L-80 BTC-M WINDOW D-SAND 9.6_25 7105 _ _ 7106 3417 40.00 __ _ L 80 BTC-M WINDOW B-SAND 9.625 7305 7306 ~ 3466 40.00 _ L-80 BTC-M Casing String - A-SAND LI_N_ER 5.5" LINER alternating blank/slotted casi_n Description _ Size T~ Bottom TVD 1Nt Grade Thread A-SAND LINER 5.500 7412 12607 3572 15.50 L-80 DWC Tubin Str_in -TUBING Size ToQ Bottom TVD Wt Grade Thread 4.500 __ _ _ 0 _ _ 7062 _ _ _ 3406 12.60 L-80 IBT Pertorations Summa Interval _ __ _ TVD Zone Status Ft SPF Date T e Comment 8056 - 8148 3600 - 3614 WS A3,WS A2 _ 92 40 8/15/2004 IPERF Slotted liner, alternating w/blank pipe, constrictor packers between jts., slots 2.5"x.125", 4 circumferential rowsJft -applies to all A-Sand rfs LEM L2 ~ 8271 -8333 3627 -3630 ~ WS A2 62 40 8/15/2004 IPERF (7036-7103, 8799 - 8984 3622 -3612 WS A2 185 40 8/15/2004 IPERF OD:8.280) _ 9336 -9918 3594 - 3582 WS A2 582 _ 40 8/15/2004 IPERF 10087 - 10761 3592 - 3581 WS A2 674 _ 40 _ 8/15/2004 IPERF 11144 - 12122 _- 3558 -3554 WS A2 ---- 978 40 __ 8/15/2004 IPERF 12378 - 12574 3566 -3572 WS A2 196 40 8/15/2004 IPERF Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type - V OD Latch Port - - TRO Date Run Vlv Cmnt 1 4102 2410 CAMCO_ KBG-2-1R GLV 1.0 BK I 0.188 1485 5/12/2007 2 5281 2826 CAMCO KBG-2-1R _ OV 1.0 BK I 0.313 0 5/12/2007 Other._( plugs, a ui ., etc q pe . - COM_P_LETION Depth - TVD T Description ID 25 25 HANGER _ _ MCA 4.909 TUBING HANGER set 5/2/2007 3.900 517 515 NIP CAMCO 'DS' NIPPLE set 5/2/2007 3.875 2970 2006 Heat Trace_ HEAT TRACE 2970'-3063' set 5/2/2007 0.000 LEM L1 6972 3383 NIP CAMCO'DB' NIPPLE set 5/2/2007 3.813 (7245-7303, OD:s.s25) ' 6989 3387 Gauge Mandrel A-WELL GAUGE MANDREL (WEATHERFORD) set 5/2/2007 3.950 ACKER 7038 3400 LEM L2 D-SAND LATERAL ENTRY MODULE (LEM) set 5/2/2007, TOTAL LENGTH 248' - includes "HR" Liner Setting Sleeve, ID 7.6", XO Brushing ID 4.88", Seal Bore Extension ID 4.75", Production Packer ID 3.87", LEM HH Above Hook ID 3.95", LEM HH Below Hook ID 3.68", Non-Locating Seal Assembly ID 3.89" Install L2 diverter 9/7/2007 3.870 (7412-7413, 7040 3400 SEAL BAKER GBH-22 SEAL ASSEMBLY 3.890 OD:a.a3o) ~ 7103 3416 HANGER L2 B-SAND LEM BAKER MODEL B-1 HOOK HANGER 6.200 ^ ^ I , 7245 3452 LEM L1 8-SAND LATERAL ENTRY MODULE (LEM) set 8/15/2007, TOTAL LENGTH 52' - includes ZXP Liner Top Packer, ID 6.278", CSG Sealbore Receptcle 4.75", 15' Length, Orienting Profile, Seal Bore for Lateral Isolation 3.68" ID, Access Window VIA Thru Tubing Diverter, Seal Bore for Lateral Isolation 3.68" ID, 4.75" Isolation Seal Assembly 3.875" ID, 12' length, CAMCO DB nipple @ 7327', ID 3.562". Set ISO ~ Sleeve 9/7/2007 3.562 7303 3465 HANGER L1 B-SAND LEM BAKER MODEL B-1 HOOK HANGER 6.200 Other lutes, _e_c_Luip., etc - . - A-SAND LINER DETAIL - - 1 i Depth _TVD ~ Type 7412 _3487 PACKER 7434 ~ 3491 ~ HANGER -~ 7446 3493 SBE - Descr_I lion A-SAND HRD ZXP LINER TOP PACKER A-SAND FLEXLOCK LINER HANGER _ A-SANG 190-47 SEAL BORE EXTENSION ID 6.230_ _7.000 4.750 I 7465 i 3496 ~ BUSHING A-SAND XO BUSHING _ 5.500 1 1 General Notes _ Perf 8271 8333 Date _ _ jNOte ( - ) I 9/8/2004 NOTE: TRI-LATERAL WELL: 1E-126 A-SAND 1E-126L1 B/C-SAND , 1E-126L2 D-SAND Perf (8799-8984) Pert ;10087-10761) Perf ;11144-12122) Perf ;12378-12574) 1 1 I 1 1 I 1 1 ' I I I • • ~ ~ ConocoPhill~ps ~.. .RECEIVED Alaska APR 2 2 2008 RO. BOX 100360 ANCHORAGE, ALASKA. 99510-0360 ~(a a~ $ GaS CORS~ ~m • ~ICfi0fc1~8 Apri116, 2008, . Mr. Tom Maunder 11-~ Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 ~~ °~O ~ ,~ ~ `~-~ Anchorage, AK 99501 ~~~~ APR ~ ~ 20 t ~ Dear Mr. Maunder:. Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosioninhibitor/sealant was pumped on 3/29/2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sinc ~~~~ Perr ConocoPhillips Well Integrity Projects Supervisor • ' ConocoPhillips Alaska Inc. Surfaicd' Casing'by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off . _ Report of Sundry Operations (10-404) Kuparuk Field Ida+s~ • -..,. -~ MICROFILMED 03101 /2008 DO NOT PLACE _- .~'_.,. N-' ~, ?,°~"", ~ . r~r ANY. NEW MATERIAL UNDER THIS PAGE U F:~L.aserFiche\C~rPgs_Inserts~Microfilm Marker.doc 1. Operations Performed: Abandon 0 Repair Well 0 f Plug Perforations 0 Stimulate 0 Other L-.J " Alter Casing 0 Pull Tubing 0¿ Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0, Exploratory 0 204-1221 .r 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23215-00 .r 7. KB Elevation (ft): 9. Well Name and Number: .r RKB 28' / 1E-126 8. Property Designation: 10. Field/Pool(s): ./ ADL 25651 i. 25660 ' Kuparuk River Field 1 West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12612' / feet true vertical 3573' ;' feet Plugs (measured) Effective Depth measured 12573' feet Junk (measured) - true vertical 3572' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 3767' 13-3/8" 3795' 2306'SCANNED JUN 1 4 2007 PRODUCTION 8060' 9-5/8" 8088' 3605' LINER 5195' 5.5" 12607' 3572' i Perforation depth: Measured depth: 8056'-8148',8271'-8333',8799'-8984', 9336'-9918',10087'-10761',11144'-12122',12378'-12574' ...., ..j,;.,~~ ..-........-:~. true vertical depth: 3600'-3614',3627'-3630',3622'-3612', 3594'-3582', 3592'-3581', 3558'-3554', 3566'-3572' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7062' MD. Packers & SSSV (type & measured depth) Baker pkr, ZXP pkr, and HRD ZXP liner pkr @ 7076',7245', and 7412' Cameo 'OS' nipple @ 517' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not ðpplicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casino Pressure Tubino Pressure Prior to well operation SI .. Subsequent to operation 174 . 665 , 116 ~. -- 467 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after work: oil0 GasD WAG 0 GINJD WINJD WDSPL 0 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: Contact Jill Long @ 265-1102 Printed Name Lr rlfl Title Wells Group Engineer Signature _/ L0 0l1ßl--, Phone Date 05/ J4/ D 7 prenarecTh" Sharon AII~"n..Drake 263-4612 () t pc'" 5ßV ~1:> ç. z,>.d7 Form 10-404 Revised 04/2006 , t f RBDMS BFt ,¡UN J :I 2007 Submit ~ on0'~ . . ~~WÉfj STATE OF ALASKA ~ 'l-Þ iOW1 ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONSÅ\-G1;lcftœed'tRœ·_~Hw OR . . ConocoPhillips Alaska, Inc. KRU 1E-126 .~ WI SSSV Tvce: NIPPLE Orio Comcletion: 8/31/2004 Angle_@ TO: 89 dea @. 12612 Annular Fluid: Last W/O: 5/3/2007 Rev Reason: WORKOVER Reference Loa: 28' RKB Ref Loa Date: Last Update: 5/14/2007 TUBING Last Taa: TD: 12611 ItKB (0-7062, --- Max Hale Angle 00:4.500, ~ 10:3.958) Description Size Top Bottom TVD wt Grade Thread SURFACE 13.375 0 3795 2303 68.00 L-80 BTC PRODUCTION 9.625 0 8088 3605 40.00 L-80 BTC-M CONDUCTOR 20.000 0 108 108 94.00 K-55 WELDED WINDOW D-SAND 9.625 7093 7094 3414 40.00 L-80 BTC-M ~ To. ....m TVD '^ "G.... Th~d LINER 7412 I 12607 I 3572 I 15.50~ ' " Size ' ., Top Bottom I TVD I wt I Grade I .. ;~read II I Interval TVD Zone Status Ft SPF Date Tvpe Comment 8056 - 8148 3600 - 3614 WS A3,WS 92 40 8/15/2004 IPERF Slotted liner, alternating w/blank A2 pipe, constrictar packers between jts., slats 2.5"x.125", 4 circumferential raws/It - applies to all A-Sand oerfs 8271 - 8333 3627 - 3630 WSA2 62 40 8/15/2004 IPERF 8799 - 8984 3622 - 3612 WSA2 185 40 8/15/2004 IPERF 9336 - 9918 3594 - 3582 WSA2 582 40 8/15/2004 IPERF 10087 - 10761 3592 - 3581 WSA2 674 40 8/15/2004 IPERF 11144 - 12122 3558 - 3554 WSA2 978 40 8/15/2004 IPERF 12378 - 12574 3566 - 3572 WSA2 196 40 8/15/2004 IPERF ¡..I..v St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 2 BK 0.313 0 5/12/2007 , . DeDth TVD Type Description ID 25 25 HANGER MCA 4.909 TUBING HANGER set 5/2/2007 3.900 517 515 NIP CAMCO 'DS' NIPPLE set 5/2/2007 3.875 2970 2006 Heat Trace HEAT TRACE 2970'-3063' set 5/2/2007 0.000 6972 3383 NIP CAMCO 'DB' NIPPLE set 5/2/2007 3.813 6989 3387 Gauge A-WELL GAUGE MANDREL (WEATHERFORD) set 5/2/2007 3.950 ~. Mandrel 7038 3400 LEM L2 D-SAND LATERAL ENTRY MODULE (LEM), TOTAL LENGTH 248' - includes "HR" 3.870 PACKER Liner Setting Sleeve, ID 7.6", XO Brushing ID 4.88", Seal Bare Extension ID 4.75", Production Packer ID 3.87", LEM HH Abave Hook ID 3.95", LEM HH Belaw Haak ID (7412-7413, 3.68", Nan-Locatina Seal Assemblv ID 3.89" SET 5/1/2007 00:8.430) I 7040 3400 SEAL BAKER GBH-22 SEAL ASSEMBLY 3.890 · . 7103 3416 HANGER L2 BAKER MODEL B-1 HOOK HANGER FOR LEM FOR B-SAND L2 6.200 ~ 7245 3452 LEML1 B-SAND LATERAL ENTRY MODULE (LEM), TOTAL LENGTH 52'- includes ZXP 3.680 Liner Top Packer, ID 6.278", CSG Sealbare Receptcle 4.75",15' Length, Orienting Profile, Seal Bare for Laterallsalation 3.68" ID, Access Window VIA Thru Tubing Diverter, SEal Bare for Laterallsolatian 3.68" ID, 4.75" Isolation Seal Assembly 3.875" ID, 12' length 7303 L1 BAKER MODEL B-1 HOOKHANGERFO~ _11'11)1_1111111111.11I1)'), . I DeDth TVD Type Description ID . . · 7412 3487 PACKER HRD ZXP LINER TOP PACKER 6.230 .. .. 7434 3491 HANGER FLEXLOCK LINER HANGER 7.000 ...... I 7446 3493 SBE 190-47 SEAL BORE EXTENSION 4.750 =,. ::::::: 7465 = ~ = · I Perf = I ~ (8271-8333) == Date Note 1= 9/8/2004 I NOTE: TRI-LATERAL WELL: 1E-126(A-SANDI. 1E-126L 1 B/C-SAND , 1E-126L2(D-SAND ~ · · ~ Perf === I F (8799·8984) ::::::: F ::::. · · § Perf -.' I E (10087-10761) ~' f== ::::::: · · 'F=' Perf I (11144-12122) - · · I--- Perf == I F (12378-12574) = Þ= = I I Þ= ::::::::: ~ - . I I · ~. ConocoPhilIi ps Welfylew Web Reporting Time Log Summary 04/17/2007 12:00 15:00 3.00 DEMOB MOVE DMOB P Move rig to let camp pass. Break down stack and secure on skid. Camp moved to 1 E. 15:00 00:00 9.00 DEMOB MOVE WOEQ T Waiting on cats for descent down hill between 2L & 2M 04/18/2007 00:00 03:00 3.00 MIRU MOVE WOEQ T Waiting on cats for descent down hill between 2L & 2M. Stage 2 Cats at 2L. ~.~ " 03:00 13:30 10.50 MIRU MOVE MOB P Move rig from 2N to hill, about 5 miles. u ~ .') y \ Tie Cats onto back of rig and move l}J. ~'-' , ¡j.<.V . down hill to bridge. Release Cats to ~ ~ \'P;¡\ù1 . load out back at 2L Pad. Move rig it( ~() ) across bridge and continue moving to &. Y ,,'l ;:>.(\,\ 1.£-( 2B Pad. .\1" Jr;rt-i.þ 13:30 00:00 10.50 MIRU MOVE WOW T Wait on weather / storm to subside. ~, i "" I' Equipment needed to clear way for rig. "'ò Rig currently waiting on 2B pad. 5~~4~ Roads & Pads equipment tied-up keeping spine roads open, will also b \, need dozer to knock down drifts on both sides of road for ri to clear. 04/19/200700:00 00:00 24.00 MIRU MOVE WOW T Wait on weather / storm to subside. Equipment needed to clear way for rig. Rig currently waiting on 2B pad. Roads & Pads equipment tied-up keeping spine roads open, will also need dozer to knock down drifts on both sides of road for rig to clear. Winds subsiding around noon. Roads & Pads equipment catching-up to open roads, but equipment break downs (snow blower) limiting availability to clean out roadside drifts ahead of ri . 04/20/2007 00:00 12:00 12.00 MIRU MOVE WOW T Wait on weather 1 storm to subside. Equipment needed to clear way for rig. Rig currently waiting on 2B pad. Roads & Pads equipment tied-up keeping spine roads open, will also need dozer to knock down drifts on both sides of road for rig to clear. Roads & Pads equipment catching-up to open roads, but equipment break downs (snow blower) limiting availability to clean out roadside drifts ahead of ri . 12:00 13:00 1.00 MIRU MOVE MOB P Prep rig to move, warm up moving s stems Move rig from 2B pad to 2C pad. Rig catching up to road clearing e uipment. 15:30 19:00 3.50 MIRU MOVE WOW Set rig down and standby. Roads & Pads clearing drifts and road ahead of ri . 19:00 00:00 5.00 MIRU MOVE MOB P Move rig from 2C pad to 1 E - turn off spine onto 1 E access raod at midni ht. 04/21/2007 00:00 04:00 4.00 MIRU MOVE MOB P Continue move Nordic rig 3 from 1 E to 1 E pad. Arrive 1 E, cross pad, spot rig over well 1 E-126. 04:00 06:00 2.00 P PJSM, RU over 1E-126, take fluids to pits, begin prep for ND tree, lay hard lines for kill tank, berm in selected equip. Accept Nordic rig 3 0400 hrs this date 4/21/07 06:00 08:00 2.00 P RU 2" circulating lines to manifold. Check hardiines to Tiger Tank. Bring seawater into pits and mix in 6% KCI. Brin in lubricator. 08:00 10:00 2.00 P PJSM. RU crane & hoist ESP spooler and empty spool onto rig floor. Set up s ooler. RO crane. 10:00 10:30 0.50 RPCOI\ OTHR P RU Vetco Gray lubricator. Pull BPV. 10:30 13:30 3.00 RPCOI\ RURD P RU circulating lines & PT with rig air. Thaw frozen outside line and blow clear. Finish RU line to Tiger tank & PT with ri air. 13:30 14:00 0.50 P Check well pressures. Tubing & IA = 200 si. OA = 100 si. 14:00 17:30 3.50 P PJSM. Circulate 8.8 ppg SeaWater/6% KCI down tubing, taking diesel returns from IA through choke to outside Tiger tank, 5 BPM. Had diesel returns until a full circulation, then got 8.8 ppg KCI/SW returns with diesel cut. Circulated to 470 Bbls and had trace of diesel in 8.8 ppg KCIISW returns. Shut down 30 minutes to let diesel separate, circulated 15 Bbls, good 8.8 ppg KCIISW with trace diesel. Let set 30 minutes more, then reversed 5 Bbls, 8.8 ppg returns from tubin with no diesel. 17:30 20:30 3.00 P Monitor well, bleed slight gas migration, monitor well, no gas, no press build. Set BPV. 20:30 22:30 2.00 P PJSM, test packoffs 1 seals, repair threads on test port cover cap. NO tree. 22:30 00:00 1.50 P PJSM, NU BOPE. 04/22/200700:00 03:30 3.50 P Cont NU BOPE. 08:00 09:30 1.50 COMPZr RPCOI\, RURD P Rig down lines, pull balancing plug & back pressure valve 09:30 10:00 0.50 COMPZr RPCOI\, RCST P PJSM, Make up landing joint BOLDs, pull hanger to floor, broke free at 150k. PU 95k. 10:00 11 :30 1.50 COMPZr RPCOI\, CIRC P Break circulation, lost 32 BBLS. Filled at 5.5 BPM 140 psi. 11 :30 12:00 0.50 COMPZr RPCOI\, OWFF P Monitor well, well static 12:00 14:30 2.50 COMPZr RPCOI\, RURD P Rig up to spool ESP cable, lay down hanger and landing joint 14:30 22:00 7.50 COMPZr RPCOI\, RCST P Pull completion, spooling ESP cable and lavinQ down jewelry 22:00 23:30 1.50 COM pzr RPCOI\, RCST P Drain, break down and lay down motor and seal. 23:30 00:00 0.50 COMPZr RPCOI\, RURD P Clear floor 04/23/2007 00:00 02:00 2.00 COMPZr RPCOI\, RURD P Continue clear rig floor, unload tools and equipment from rig. Bring in Baker equipment for clean out BHA. Strap & caliper BHA. 02:00 02:30 0.50 COM pzr RPCOI\, RURD P Set wear bushing. 02:30 04:30 2.00 COM pzr RPCOII. OTHR P Change elevators. PU & MU cleanout BHA #1: 4-11/16" smooth 00 Shoe & Globe Basket (3-1/4" 10) + 2 XO + 8 Jts 2-7/8" PAC DP + 2 XO + 2 Boot Baskets + BS + Bumper + Oil Jar + Pump Out Sub + XO. 04:30 14:00 9.50 COMPZr RPCOI\, TRIP P RIH PU 9 DC. RIH PU 4" DP. Tag fill at 6705' MD, set down to 6711' MD. 14:00 14:30 0.50 COMPZr RPCOI\, OTHR P PU and MU head pin and hose. RU to reverse circulate and wash out fill. 14:30 16:00 1.50 COM pzr RPCOII. FCO P Close bag, reduce closing pressure. Reverse circulate and wash out fill from 6705' to 6718'. Reverse bottoms up, got very fine sand returns. 70 SPM, 4 BPM, 450 psi. 16:00 22:30 6.50 COMPZr RPCOI\, FCO P Continue washing down singles, reversing, 70 SPM, 4 BPM, 440 psi. Clean out fill from 6718' to 6861 ft. No further proaress. Will not wash. 22:30 00:00 1.50 COMPZr RPCOII. FCO P PJSM, Press check, open BOPE, flow check, line up for conventional eire, commence wash, immediate success, cont wash to 7038 ft. 140 spm 1990 psi. Fine sands to shaker. 04/24/2007 00:00 04:00 4.00 COMPZr RPCOI\, FCO P Wash to tag (btm SBR) at 7293 ft. Lose circ, 100% loss, no returns. Monitor well, no gas 1 wellbore not on vacuum. 04:00 05:30 1.50 COM pzr RPCOI\, CIRC P Call DHD for fluid level shot. Pump sweep dn tbg and annulus for cleanout residual sands while wait on eauip. " DA....A '1 ~~-itl·1 > < ." '. '", '\1 . 04/24/2007 05:30 06:00 0.50 COMPZr RPCOI\ OWFF P PJSM, RU I shoot fluid level resulting in level at 420 ft. Hole will fill at surface at 6 bpm, immediately falling to 420 ft, but no returns while pump dn DP or annulus. 06:00 07:30 1.50 COMPZr RPCOI\ TRIP P POOH from 7293' to 6369'. Overfill hole for trip volume. 07:30 09:00 1.50 COMPZr RPCOI\ OTHR P PJSM. RU crane. Remove old ESP cable spool. Bring in I-wire on spooler. Bring in clamps, etc. Set in heat trace cable and spooler. RD crane. 09:00 15:00 6.00 COMPZr RPCOI\ TRIP P Continue POOH from 6369' to 570'. Overfi!l hole for trip volume, pumping an extra 5 Bbls fill-up each 5 stands. 15:00 17:30 2.50 COMPZr RPCOI\ TRIP P LD 9 DC & cleanout BHA #1. All tools in good shape. Recovered only a few small pieces of thin metal from original window milling in globe basket. Only a small amount of fine sand in boot baskets. 17:30 18:30 1.00 COMPZr RPCOI\ OTHR P Clear floor. Pull wear bushing, verify LEM equipment will pass through WB, OK. Set test~lug. 18:30 19:30 1.00 COMPzr WELCI BOPE P Test variable PR with 4", retest annular, 250 psi & 2500 psi. 19:30 21:00 1.50 COMPZr WELCI BOPE P RID and UD test equipment. Set Wewar Rinq. 21:00 00:00 3.00 COMPZr RPCOI\ PULD P PIU and assembly LEM #2. Shoot fluid level at 2300 hrs, TOF @ 150 ft. 04/25/2007 00:00 01:00 1.00 COMPZr RPCOI\ PULD P M/U LEM. Orient wI MWD, RIH. 01:00 01:30 0.50 COMPZI RPCOI\ TRIP P Shuffle DC's and Drillstring for RIH. RIH w/5 stds DP. 01:30 02:00 0.50 COMPZI RPCOI\ OTHR P Shallow test MWD. 02:00 06:00 4.00 COMPZI RPCOI\ TRIP P RIH wI LEM Assembly. 06:00 09:00 3.00 COMPZr RPCOI\ TRIP P Cont RIH wI LEM Assembly. 09:00 11 :00 2.00 COMPZr RPCOI\ HOSO P Locate and attempt to latch into hook hanger wI LEM. Orient and circulate, wash to 7283', unable to latch. Pump 50 bbls down annulus to flush seal bore. Pump addnl 50 bbls, attempt to set again. Unable to circulate, fluid level wI pumping just below bell nipple on stack. 11:00 18:30 7.50 COMPZr RPCOI\ FCO T Continue attempting to set LEM wI alternate pumpingl rotating and recip. Unable to land and latch into Hook Hanger. Possible sand fill in wellbore. Decision made to POOH wI LEM as no progress. 18:30 00:00 5.50 COMPZr RPCOI\ FCO T POOH wI LEM assy f/7115' - 269'. ... ... : ...··.~Ji)1 .[>. J ......... ..' ..~ . /' 04/26/2007 00:00 01 :00 1.00 COMPzr RPCOI\, FCO T POOH to LEM. Prepare to layout MWD and LEM components. 01:00 06:00 5.00 COMPZr RPCOI\, FCO T While breaking out setting sleeve running tool, inner string backed off. Unable to extract inner string due to excessive sand pack-off. PJSM, begin break out inner string and LEM via individual component. Break out all. Extract MWD tools, inspect and prepare LEM I running equipment for shipment to shop for inspection and clean-up. Visual on Hanger and latch assembly revealed untouched paint so failure to set likely due to excessive sand in wellbore. 06:00 08:00 2.00 COM PZ~ RPCOI\, FCO T Load and strap 2 7/8" PAC pipe and handling tools in pipe shed for C/O run. 08:00 12:00 4.00 ICOMPZ~ RPCm, FCO T PJSM, RIH wI C/O 2 7/8" PAC pipe clean-out assembly on end of 4" DP work strinq to 7071'. 12:00 14:30 2.50 COMPZ~ RPCOI\, FCO T RU to pump down DP and annulus simultaneously. Pump at 3 bpm down annulus, 2 bpm dn DP wI annular SI fl 7071' - 7166'. 14:30 18:30 4.00 COM PZ~ RPCOI\, FCO T Work pipe wI pumping f/7166' - 7324'. Hit obstruction at 7286 and work through wI tbg. At end of clean-out, located hook wI no-go collar at 7103'. Mule shoe depth 7324'. 18:30 20:30 2.00 COMPZr RPCOI\, FCO T Blow dn top drive, and POOH wl5 stands wI pumping. SD and wait for 1 hr to observe. 20:30 21:30 1.00 COMPZr RPCOII. FCO T RIH wlo pumping to determine fill, none detected, again locate and land on hook at 7103'. Pump 20 bbls wI pumping at 3 bblsl min dn annulus and 2.5 bbl/min dn DP. 21:30 00:00 2.50 COMPZr RPCOI\, FCO T POOH f/7324' - 3078'. Overdisplace hole x 2 pipe displacement in attempt to minimise sand inflow. 04/27/2007 00:00 02:00 2.00 COM pzr RPCOI\, TRIP T TOH, Top Drive developed probem. 02:00 03:00 1.00 COM PZ~ RIGMN RGRP T Work on Top Drive electrical problem. 03:00 03:30 0.50 COMPZ~ RIGMN SVRG P Service and lube rig. 03:30 06:00 2.50 COMPZ~ RPCOI\, TRIP T POOH wI workstring and PAC clean-out string. 06:00 06:30 0.50 COMPZ~ RPCOII. TRIP T Finish wI Clean-out string. LD 2 7/8 PAC pipe and XO's. 06:30 08:00 1.50 COMPZ~ RPCOI\, PULD T Make up LEM. 08:00 12:00 4.00 COMPZ~ RPCOI\, PULD T Wait on pups for inner string and make up bull nose shoe jt. Work on Top Drive. .i ..... ::<;.. . ..; ....;.. ....... .................. PageP ." '" ... .. i ...... .... ..... v"···."i. . 04/27/2007 12:00 15:00 3.00 COMPZr RPCOII. PULD T PJSM. Make up inner string tools for LEM run. Assemble inner string wI MWD and install in LEM Run In tool. 15:00 15:30 0.50 COM pzr RPCOII. TRIP T @ 320 psi. PU 45klbs, SO 46klbs 15:30 23:30 8.00 COMPZr RPCOII. TRIP T SD TD and RIH wI LEM f/473' - 7019'. PU 125 klbs, SO 58 klbs. 23:30 00:00 0.50 COMPZr RPCOII. SFTY T PJSM wI Drlr, Tool Hnd, Co Rep and rig crew. Discuss procedure and wash-in I set procedure for LEM. 04/28/2007 00:00 01:30 1.50 COMPZr RPCOII. CIRC T Break circulation, rate 52 spm @ 460 psi. Orient assembly wI MWD, pump wI slowly work in hole to 7264', near top of csg seal bore assy. 01:30 05:00 3.50 COMPZr RPCOII. RCST T Cut pump rate to 10 spm, 50 psi and cont RIH to land hook hanger. Stack out at 7279. Based on PU and SO, determine top SBE at - 7273' dd. Unable to land assy. PU and tr¡ a!t LEM orientation. Noted pump press increase to 510 psi at 52 spm. Press same wI or wlo seals stabbed into Csg SBE, possible plugged hole on bullnose circ jt. Cont wI landing attempt by alternating LEM orientation and recip. Unable to proceed, noted stack-out depth same as original LEM run attempt. Decision made to POOH and alter lenth of seal spacer pups. 05:00 06:00 1.00 COMPZr RPCOII. TRIP T PJSM, POOH wI LEM assembly for modification. Pumping fld down backside at 16 - 20 bblsl hr. 06:00 07:00 1.00 COMPZI RPCOII. TRIP T Cont TOH to 6366'. 07:00 08:30 1.50 COMPZI RIGMN SVRG T PJSM, Slip and Cut Drill Line. 08:30 14:00 5.50 -- COMPZI RPCOII. TRIP T TOH wI LEM assembly. f/6366' - 0' 14:00 16:30 2.50 COMPZI RPCOII. PULD T Break out and lay down LEM assembly & MWD tools. 16:30 19:00 2.50 COMPZr RPCOII. WOEQ T Wait on composite bridge plug, clean floor and rig upkeep. 19:00 00:00 5.00 COMPZr RPCOII. PULD T PU and MU Bridge Plug on 2 7/8" PAC DP. RIH to 7299' MD. 04/29/2007 00:00 01:30 1.50 COM PZ~ RPCOII. PACK T Set 4" Baker model 360 Quik-Drill composite bridge plug @ 7295' dd inside tubing below csg seal bore assembly. Test wI tag. OK. Break circulation at 2 bpm to monitor for returns, 100 %. 01:30 05:30 4.00 COMPZr RPCOII. TRIP T PJSM, POOH wI setting tool. Break out running tool, LD 2 7/8" PAC string. 05:30 06:00 0.50 COMPZr RPCOII. PULD T PJSM, PU LEM assembly wI wash string for hook hanger latch test. (Test only, to confirm latch possible) 06:00 08:00 2.00 COMPZr RPCOII. PULD T PU LEM assembly wI MWD, RIH 3 stds. ........ ...... ..... Page 'lll] .. .. . . 04/29/2007 08:00 08:30 0.50 COMPZ~ RPCOI\. CIRC T Shallow test MWD @ 53 spm, 350 psi, OK. 08:30 11:30 3.00 COM PZ~ RPCOI\. TRIP T Cont RIH wI LEM - 6888'. 11:30 12:30 1.00 COMPZ~ RPCOI\. CIRC T Circulate wI TIH wI LEM 6888' - 7107'. 65 spm @ 650 psi, 120 klbs up, 57 klbls dn I wash through collet lock area wI jetted sub to remove debris. 12:30 19:30 7.00 COMPZr RPCOI\. DHEQ T Multiple attempts to latch in LEM. Vary orientation, set weights, circulating, washing etc in attempt to set and latch LEM. Last 5 attempts to latch succesful. LEM set and Latch depth 7105.5'0 Total TD BHA = DP 7133'. PU 125 klbs, SO 53 klbs. Last attempt after full pick-up and rotation of pipe to insure repeatability, OK. 19:30 21:30 2.00 ICOMPZ~ RPCOI\. C!RC T Circulate hi~vis sweep, CBU and prepare to POOH. 21:30 00:00 2.50 COM PZ~ RPCOI\. TRIP T TOH wI LEM and MWD assembly. fl 7133' - 3559'. 04/30/2007 00:00 02:30 2.50 COM PZ~ RPCOI\. TRIP T TOH wI LEM and MWD. Break out and LD LEM after inspection. No visible sign of damage or other. Inspection of collet latch and hook reveal latch OK. 02:30 03:00 0.50 COMPZ~ WELCT BOPE T Clear floor and prepare for BOPE test. 03:00 06:00 3.00 COMPZ~ WELCT BOPE T PJSM, Test BOP equipment. 06:00 09:00 3.00 COMPZ~ WELCT BOPE T Finish BOPE test. Test all components 250 I 2500 psi, all ok. Pull test pluç, set wear bushing. 09:00 12:00 3.00 COMPZr RPCOI\. PULD T PJSM, PU Globe baske on 2 7/8" PAC tail pip. RIH wI 4" DP t/6440'. (Calc disp 36 bbls, Acutal 34 bbls) 12:00 15:30 3.50 COMPZr RPCOI\. CIRC T Cont RIH fl 6440' - 7203'. Attempt to reverse circulate, Pump 70 bbls, no returns, no fluid observed at surface in well. Pump addnl 30 bbls, no returns. RIH tag bottom of SBE 7295' wI no fill detected. PIUp 6', pump addnl 25 bbls, FL shot TOF @ 282' in DP. PU 125 klbs, SO 60 klbs. POOH 3 stds t/7010', shoot fluid level, TOF @ 282' in DP. 15:30 20:30 5.00 COM PZ~ RPCOI\. TRIP T TOH wI clean-out assembly fl 7010' - 262'. 20:30 21:00 0.50 COMPZ~ RPCOI\. PULD T LD clean-out BHA. 21:00 00:00 3.00 COM PZ~ RPCOI\. PULD T PJSM. PU LEM assembly wI packer and seal assv. 05/01/2007 00:00 01:00 1.00 COMPZ~ RPCOI\. PULD T Finish PU I MU of LEM-2 assy wI packer, seal assy & MWD for orientation. <: )... . .... .. ..... ....... ù: I ... .. . ..... ..... ... I"age fOT 1 U .¡#'" 05/01/2007 01 :00 01 :30 0.50 COMPZr RPCOII. CIRC T Shallow test MWD, OK. 01:30 09:00 7.50 COMPZr RPCOII. TRIP T TIH w/ LEM-2 assembly at max trip speed of 30 ftImin. Observe fluid loss while TIH to 7296 ft. Losses at rate of 24+ bbl/hr, no returns. 09:00 10:30 1.50 COMPZI RPCOII. PACK T Work hook assy, orient to hook. In place at 18 deg to right. Pull up 10ft, partial rotation, set dn, confirm with return to 18 deg to right. No collet "snap" felt at surface after multiple attempts. Partial returns during I procedure. Up 140, Dn 70 10:30 11:30 1.00 COMPZr RPCOII. CIRC T Circ with partial returns while mix I pump 1 % lube. Note Up / Dn wts. decreased to 132 Up, Dn 70. 11:30 12:00 0.50 COMPZr RIGMN SVRG P Service rig while circ lube. 12:00 1-:t·-:tn 1.50 ICOMPZr RPCm, PACK P Latch LEM, Defined collet indicator. IV.VV Confirmed "snap" in / out of position. Drop ball, pump dn to pkr. Build to 4030 psi, pkr set. PKR 7076 ft, Top hook 7105.5 ft. 13:30 15:30 2.00 COMPn RPCOII. DHEQ P PJSM, test pkr (9-5/8 X 4" DP) to 2500 psi / 30 min and chart. Bleed and re-test 3 times to obtain final straight line test. (Aired I foamed fluids) 15:30 16:00 0.50 COMPZI RPCOII. TRIP P Blow down top drive, monitor well, takinq fluid, PJSM. 16:00 00:00 8.00 COMPZI RPCOII. TRIP P Continue POOH w/lay down 4" DP workstring. POOH f/7076' - 1537'. 05/02/2007 00:00 03:30 3.50 COMPZr RPCOII. TRIP P POOH lay down workstring. Lay down runninq tools, MWD and other. 03:30 04:30 1.00 COMPZr RPCOII. PULD P Clear floor, pull wear bushing and prepare for running of completion. Load remaining 4 1/2" IBT tubing in I pipeshed and strap. 04:30 06:00 1.50 COMPZ RPCOII. RURD P RU to run completion on 41/2" IBT tbg. Pull wear ring, RU and Tee-wire and heat trace spoolers, fct test. 06:00 12:00 6.00 COMPZr RPCOII. PULD P PJSM, Connect TEC-wire U inst sub, RIH w/ completion f/O - 2722'. Installing TEC-wire w/ single channel Cannon clamps as per proqram. 12:00 15:30 3.50 COMPZr RPCOII. PULD P Continue RIH wI completion f/2722' - 4185'. 15:30 16:30 1.00 COMPZr RPCOII. RURD P RU f/ start of Heat Trace installation. 16:30 00:00 7.50 COMPZI RPCOII. PULD P Cont RIH w/ completion f/4185' - 6768' w/ TEC-wire and heat trace attached . w/ dual channel Cannon clamps as I per program. I .... Page I Continue RIH w/4 1/2" IBT tubing to top of seal bore extension. Tag no go at 7041'. Fill annulus, monitor well. No losses. Determine PU/SO to insure tubing landed in tension wI locator at 7039ft, i.e. 2' off bottom. 06:30 10:00 3.50 COMPZ RPCOI\ HOSO P Space out, MU pups I tbg hgr I Idg jt. Total TEC-wire and Heat trace clamps used as follows: (131) Single channel Cannon @ 1/jt below heat trace. (455) 5' dual channel clamps, (9) 4' dual channel clamps, (9) 3' dual channel clamps, (9) 2' dual channel clamps, 89 Cplg dual channel clamps @ collars, 2 bands at hanger area. Heat trace start at 4092'. 10:00 14:00 4.00 COMPZ RPCOI\ OTHR P Prep hngr, terminate TEC wire I heat trace to h r. Test all connections. 14:00 16:00 2.00 COMPZ. RPCOI\ C!RC P Attempt reverse eire. No returns. Pump 170 bbls 1% CRW32 inhibitor dn tbg to 4-1/2 X 9-5/8 annulus. Approx 30% returns to surface during circ. 16:00 17:00 1.00 RPCOI\ HOSO P PJSM, land hgr, RILDS. Confirm hgr dn. 17:00 19:00 2.00 COMPZ RPCOI\ DHEQ P RU I test IA wI chart recorder. Build I hold 1000 psi, 30 min. OK. Build I hold 1500 psi 30 min, OK. Pressure / up to shear SOV. SOV sheared out at 1960 psi. Pump addnl18 bbls to insure clear. RD pressure sensors and clear floor for next task. 19:00 23:00 4.00 P PJSM. SET BPV, ND Stack wI service breaks for storage. Remove stack and clear area for settin tree. 23:00 00:00 1.00 P Test heat trace and TEC-wire DMS, OK. Prepare connections and wellhead for settin tree. 05/04/2007 00:00 03:00 3.00 COMPZ RPCOI\ NUND P Finish prep of wellhead set in place. Install tree. Pull BPV, Set 2-way check, pressure test pack-off 5000 psi ./ OK. Test tree 250/5000 psi, OK. Pull 2-wa check, set BPV. 03:00 05:00 2.00 COMPZ RPCOI\ RURD P Work on rig prep for move, while wait on hot oil for freeze protect. RU hard line, ull tar s etc.. 05:00 07:00 2.00 COMPZ RPCOI\ FRZP P RU, hot oil, PJSM, ptest lines 2500 psi. Freeze protect IA wI 160 bbls diesel, had 5 bbls total returns. Swap valves and freeze protect tbg by bullheading 60 bbls. ICP 100 psi, FCP 1375 wI pumping IA. ICP 150 psi, FCP 500 wI pumping tbg. Final static tbg press 200 psi, IA 400 psi. RD, release Hot Oil. 07:00 08:00 1.00 COMPZ RPCOI\ RURD P PU lubricator, set BPV. Finish clean pits & prep rig for move, NORDIC RIG #3 RELEASED THIS DATE 1000 HRS. )~~ DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permitto Drill 2041220 Well Name/No. KUPARUK RIV U WSAK 1E-126 Operator CONOCOPHILLlPS ALASKA INC Jì¡uJ ).~/~'1 API No. 50-029-23215-00-00 MD 12612 Completion Date 8/31/2004 Completion Status 1-01L Current Status 1-01L TVD 3572 --,~- UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Type Med/Frmt Number Name I Rpt Directional Survey D C Pds 13003 Induction/Resistivity C Lis 13003 Induction/Resistivity C Asc 13003 LIS Verification ./ Induction/Resistivity Log Log Run Scale Media No Interval Start Stop o 12611 108 12611 108 12611 108 12611 108 12611 25 25 Blu Well Cores/Samples Information: . OHI CH Open Open Open Open Open Received Comments 9/22/2004 ~~~~--~l I I I J MPRlGR MPR/GR Text File 2/3/2005 multiple propagation resistivity, gr, rwd Name Interval Start Stop Received Sample Set Number Comments Sent ADDITIONAL INFORMATION Well Cored? Y dtð Chips Received? ~ ~N GJN Daily History Received? Formation Tops Analysis Received? ~ ~-,-- Comments: ~---"" :~4Jo Compliance Reviewed By: . -~- ~-~--"~ Date: ;Z lò ~~ <e ~ 2oJ- /Z"L . d.OLI- /L ~ ao 1- /2 c.¡ r'ill [L:~~J BAKER '~, .' : HUGHES ~~~;~1 Anchorage GEOScience Center:~.. :::~' ~ _.! . Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason #nD~) Reference: lE-126, 1E-126Ll, & lE-126L2 Contains the following for each wellbore: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 707446 Date: Feb 4, 2005 Date: ~;r' Received PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 . . -- _._-. ' ,ª=i ~ i ';:7~~-:,,:--;) ~:...~-: ......~.....- ~--~-,--~.¡ -'..... ~~... ": : ~-¡ ----_..+._--~-.--------+--------- ~!~,...'... ~,.;;,::'" i ~ - , , ,....-... i í !- i·-·' j', !: !';:"'1, ro._. ~LLi~:~ (:~tff i_,C.:, ".i '~,I'_ '-) ii.' ' '_.:'~ ~:'t-;tM I.'J·:'¡ PI ' pri¡¡;' -. i J' ~. X[~~1: ~ ;~. '1 , , .'. '0;"",:,'1: '!:', ) .r -'0' ,'< ~----- ¡-----.....,.---:- I" ,. ...... ~ : ~:~.- ~~! ¡... .~~~~:'~'.~~:._::.:, ....-- L__~-1__~__ . Conocó'Phillips . Randy Thomas cf?t?7' - / ;l.. Ã Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 October 4, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 E-126, 1 E-126L 1, 1 E-126L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 E-126, 1 E-126L 1 and 1 E-126L2. If you have any questions regarding this matter, please contact me at 265-6830 or Steve Shultz at 263-4620. Sincerely, -("·"4 \ ~ - R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad RECEIVED OCT 0 6 2004 Alaska Oil & Gas Cons. Commission Anchorage OR'GtNAL . STATE OF ALASKA . ALA OIL AND GAS CONSERVATION COM' ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged U Abandoned U Suspended U WAGD 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory D GINJ D WINJ D WDSPL D No. of Completions _ Other - Service D Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: August 31, 2004 , 204-1221 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 August2,2004 .' 50-029-23215-00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 852' FSL, 631' FEL, Sec. 16, T11 N, R10E, UM ./ 1 E-126 August 14, 2004 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 2572' FNL, 1517' FEL, Sec. 22, T11N, R10E, UM 28' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): West Sak Oil Pool 1799' FNL, 1963' FEL, Sec. 27, T11N, R1OE, UM 12573' MD / 3572' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: / 5960439 , Zone-4 12612' MD 13572' TVD ADL 25651 & 25660 x- 549890 y- TPI: x- 554314 y- 5957045 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 553908 y- 5952537 Zone-4 none ALK 469 & 470 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1746' MD 21. Logs Run: GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD PULLED CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE 20"x34" 94# K-55 28' 108' 28' 108' 42" 348 sx ArcticSet 1 13-3/8 " 68# L-80 28' 3795' 28' 2306' 16" 740 sx AS Lite, 210 sx DeepCrete 9-5/8" 40# L-80 28' 8088' 28' 3605' 12.25" 726 sx DeepCrete 5.5" 15.5# L-80 7412' 12607' 3487' 3572' 8.5" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 6093' 7413' slotted liner - 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. slots in liner from 8056'-8148', 8271 '-8333', 8799'-8984', DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9336'-9918',10087'-10761',11144'-12122',12378'-12574' nla 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 20, 2004 Flowing (shares production with 1 E-126L 1 and 1 E-126L2) Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 9/21/2004 6 hours Test Period --> 270 253 0 15% 998 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. o psi not available 24-Hour Rate -> 1045 1043 1 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RECEIVED r 7c,:\i:;T:¡iÙ. 1 ,..:,,..,, . ¡ ..!l-3l~-º'Á NONE OCT 0 62004 t V~:~¡';·::::¡F·~· ~ j '1) -, ì î J,----- ¡ ORfG'~LAL Alaska Oil & Gas Cons. Commission ~"",.""""",.__......".,..-,__..__.",,,.......r CJ~ Anchorage Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ¡RØSBFL OCT 0 R 'rlf\ '" 28. . 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. list intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state 'None'. 1 E-126 West Sak A2 West Sak A1 8077' 12611 ' 3604' 3572' N/A RECEIVED OCT 0 6 2004 A¡as~(¡j' & Gas Cons. Commissíon Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4620 Printed Na~Thom~~ Signature \ ~- Title: .~one KUDaruk Drillina Team Leader <-"r'b ß3 e:> Date \.c,(s /o'r 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: Blow down rig, Move pipe shed, Boilers, Motors, Pumps, Pits, Rockwasher & Sub complexes off 1 E-112. Spot Sub & all complexes over 1E-126. Hook up Air, Water, Steam, Glycol, Mud lines, Prep. rig for accept. Accept rig @ 09:30 hrs 8/1/2004, Nipple up Diverter system, Take on water and mix Spud mud. Change out saver subs, Change to new drilling line spool. Pick up 50 stands 5" drill pipe and stand back in derrick. Note: Rig up on Injection well 1 E-34, Flush with 140 bbls Fresh water at rate of 1 bpm @ 1550 psi. Pick up 29 jts HWDP, Jars and stand back in derrick. Function test Diverter system, Test waived by AOGCC John Crisp. Service Top drive & Blocks. Pick up & Make up 16" BHA, Bit, Motor, Short NMDC, NM Stab, MPR, MWD, NMDC's, Orient & Program MWD tools, Flood Conductor and check for leaks. Spud well @ 05:00 hrs 8/2/04, Drill 16" hole f/1 08' to 558' MD / 557' TVD, (450') ART = 1.5 hrs, AST = 3.2 hrs, WOB 20/35K, RPM 0/40, 570 gpm @ 1150 psi, UP 66K, DN 68K, 67K, Mud wt. 8.8 ppg, Vis 300+. Drill 16" hole f/ 558' to 2000 MD' 11662' TVD, (1,442') ART = 0.0 hrs, AST= 9.1 hrs, 100% Sliding, WOB 40/45K, 607 gpm @ 2300 psi, UP 98K, DN 80K, Mud wt. 9.2 ppg, Vis 200+. Drilled 16" hole per directional plan from 2,000' to 3,331' MD/ 2,133' TVD (1,331 ') ART 3.4 hrs, AST 2.7 hrs, 5-45K wob, 80 rpm's, 175 spm, 740 gpm, off btm pressure 2,550 psi, on btm 2,700 psi, off btm torque 5K ft-Ibs, on btm 8K ft-Ibs, rot wt 84K, up wt 100K, dn wt 75K 1.00 RIGMNT RGRP SURFAC Changed out swab and liner on #2 mud pump 6.50 DRILL DRLG SURFAC Drilled 16" hole per directional plan from 3,331' to 3,802' MD/2,308' TVD (471'), surface csg point, ART 2.8 hrs, AST 1.3 hrs, 5-45K wob, 80 rpm's, 175 spm, 740 gpm, off btm pressure 2,500 psi, on btm 2,700 psi, off btm torque 8K ft-Ibs, on btm 10K ft-Ibs, rot wt 87K, up wt 125K, dn wt 65K, 9.4 ppg MW, began seeing gas hydrates after drilling below 3,792' Backreamed out of hole from 3,802' to 1,100', backreamed at 80 rpm's and 150 spm, 636 gpm at 1,700 psi, worked thru tight spots at 3,170', 2,550' and 1,100', gas hydrates stopped after backreamin9 out at 2,200' Pumped out of hole from 1,100' to 360', circ at 636 gpm at 1,600 psi, attempted to pull on elevators at 730' and 550' and was pulling tight, pumped out to 360' Stood back 2 stds HWDP and jars, LD 1-short NMDC and stabilizer, drained motor and broke out bit Downloaded MWD LD MWD, MPR and mud motor Made dummy run with hanger and landing it with no problems RU Doyon's 13 3/8" csg equipment with Franks fill-up tool Held PJSM with rig crew and tong operator on running of surface csg PU 133/8" float shoe and it #1 & RIH, PU float collar and it #2 and attempted to MU float collar, was unable to get float collar to MU into shoe jt, threads appeared ok, collar possibly egg shaped, LD float collar jt and shoe it 1.50 WAlTON EQIP SURFAC Waited on new float shoe and float collar to be delivered to rig 8.00 CASE RUNC SURFAC Ran 133/8" 68#, L-80, BTC csg and landed same at 3,795', MU new 13 3/8" float shoe onto it #1, MU new float collar on Jt #2 then onto shoe it, 02:00 - 08:00 MOVE 08:00 - 09:30 MOVE 09:30 - 13:30 SURFAC 13:30 - 18:30 5.00 RIGMNT RSRV SURFAC 18:30 - 00:00 5.50 DRILL PULD SURFAC 8/2/2004 00:00 - 01 :30 1.50 DRILL PULD SURFAC 01 :30 - 02:00 0.50 WELCT BOPE SURFAC 02:00 - 02:30 0.50 RIGMNT RSRV SURFAC 02:30 - 05:00 2.50 DRILL PULD SURFAC 05:00 - 12:00 7.00 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 8/3/2004 00:00 - 11 :00 11.00 DRILL DRLG SURFAC 11 :00 - 12:00 12:00 - 18:30 18:30 - 00:00 5.50 DRILL REAM SURFAC 8/4/2004 00:00 - 01 :30 1.50 DRILL TRIP SURFAC 01 :30 - 02:45 1.25 DRILL PULD SURFAC 02:45 - 03: 15 0.50 DRILL PULD SURFAC 03:15 - 04:00 0.75 DRILL PULD SURFAC 04:00 - 04:15 0.25 CASE OTHR SURFAC 04:15 - 06:00 1.75 CASE RURD SURFAC 06:00 - 06:30 0.50 CASE SFTY SURFAC 06:30 - 08:30 2.00 CASE RUNC SURFAC 08:30 - 10:00 10:00 - 18:00 v' ,/ Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/4/2004 10:00 - 18:00 8.00 CASE RUNC SURFAC thread locked connections below float collar and tack welded btm of collar below fit collar since float equipment was not bucked up at machine shop, RIH with Jt #3 and circ thru float equip and floats ck ok, cont to RIH with 90 its 133/8" csg (93 its total), MU landing it and hanger and landed csg with float shoe at 3,795' MD/2,306' TVD and float collar at 3,756', ran 15 bow spring centralizers, worked thru tight spot at 800' then RIH, broke circ and washed down its # 68 thru 71 due to heavy mud back and very little returns, after washing down had good returns and cont RIH to btm with no other problems, St wt when landed, Up Wt 225K, Dn Wt 115K 1.50 CEMEN CIRC SURFAC Circ btm's up with Frank's tool. Broke circulation at 2.5 bpm and staged pump rate up 7 bpm @ 300 psi. Reciprocated csg, St Up wt 205K, Dn Wt 110K. 0.50 CEMEN RURD SURFAC LD Franks fill-up tool and MU Dowell's cement head 3.00 CEMEN CIRC SURFAC Cont to circ and condition mud for cementing, circ at 7 bpm at 400 psi, reciprocated csg with 215K up wt and 115K dn wt, final MW, 9.3 ppg, 40 vis, 9 YP and 16 PV, held PJSM with Dowell, vac truck drivers and rig crew on cementing surface csg while circ hole 1.00 CEMEN PUMP SURFAC Began cementing 133/8" csg, Dowell pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 42 bbls of 10.5 ppg mudpush, began mixing and pumping Arcticset lead slurry, as of 24:00 hrs have mixed and pumped 100 bbls of lead cement at 10.7 ppg and 4.45 yield with additives, ave 4 bpm at 100 psi, reciprocating csg while pumping cement 1.75 CEMEN PUMP SURFAC Cont cementing 133/8" csg, finished mixing and pumping 485 bbls of lead cement at 10.7 ppg and 4.45 yield with additives, pumped a total of 585 bbls (740 sxs) of ArticSet Lite cmt, ave 6.5 bpm at 110 psi, followed with 93 bbls (210 sxs) of DeepCrete tail cmt at 12.1 ppg and 2.47 yield with add., ave 6 bpm at 110 psi, reciprocated csg and had full retums, shut down and dropped top plug 1.75 CEMEN DISP SURFAC Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 541 bbls of 9.4 ppg mud, displaced cmt at 7 bpm, initial circ pressure 400 psi, max pressure 850 psi, slowed rate to 4 bpm and bumped plug on calc displacement, pressured up to 1,350 psi, checked floats and held, CIP @ 03:15 hrs, had full returns during job and had 100 bbls of 10.7 ppg cmt back to surface, reciprocated csg till 02:00 hrs with approx 60 bbls of lead cmt around shoe Tested 133/8" csg to 3,000 psi for 30 min, good test RD cement head and LD landing it, cleared rig floor ND 21 1/4" 2M divertor and lines, set out same NU & Orient Vetco Gray MB 222 Wellhead, Tested seals to 5,000 psi for 10 min. NU 13 5/8" 5M BOP stack RU and tested BOPE, tested rams, valves and choke manifold to 250 psi low and 5,000 psi high, tested annular to 250 psi and 3,500 psi, lower IBOP failed to test, NOTE: Lou Grimaldi W/AOGCC waived witnessing of test Changed out lower IBOP on top drive and tested to 250 psi and 5,000 psi and tested ok RD test equipment and installed wear bushing Began MU 12 1/4" BHA #2 with AutoTrak and initialized same Fin MU 12 1/4" BHA #2 and RIH with HWDP to 1,055', surface tested 18:00 - 19:30 19:30 - 20:00 20:00 - 23:00 23:00 - 00:00 8/5/2004 00:00 - 01 :45 01 :45 - 03:30 03:30 - 04: 15 0.75 CASE DEQT SURFAC 04:15 - 05:30 1.25 CEMEN RURD SURFAC 05:30 - 10:00 4.50 WELCT NUND SURFAC 10:00 - 12:00 2.00 WELCT NUND SURFAC 12:00 - 15:00 3.00 WELCT NUND SURFAC 15:00 - 19:00 4.00 WELCT BOPE SURFAC 19:00 - 21 :30 2.50 RIGMNT RGRP SURFAC 21 :30 - 22:00 0.50 WELCT OTHR SURFAC 22:00 - 00:00 2.00 DRILL PULD SURFAC 8/6/2004 00:00 - 01 :00 1.00 DRILL TRIP SURFAC Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/612004 00:00 - 01 :00 1.00 DRILL TRIP SURFAC MWD/Autotrak 01 :00 - 01 :30 0.50 RIGMNT RSRV SURFAC Serviced top drive and blocks 01 :30 - 03:15 1.75 DRILL TRIP SURFAC MU ghost reamer and RIH, PU 5" DP from pipe shed to 2,546' 03:15 - 04:15 1.00 DRILL DEQT SURFAC Shallow tested Autotrak downlink 04:15 - 05:30 1.25 DRILL TRIP SURFAC Cont RIH PU 5" DP from pipe shed to 3,746', washed down and tagged plugs above float collar at 3,753', had +/- 10' of soft cement on top of plugs 05:30 - 07:30 2.00 CEMEN DSHO SURFAC Drilled out cement plugs, float collar at 3,756', shoe jt and float shoe at 3,795', cleaned out to 3,802' then drilled 20' of new formation to 3,822' MD/ 2,314'TVD, 5-25K wob, 90 rpm's 700 gpm at 2,150 psi 07:30 - 08:45 1.25 DRILL CIRC SURFAC Circ hole clean and conditioned mud with 9.3 ppg MW in & out 08:45 - 09:15 0.50 DRILL LOT SURFAC RU and performed LOT to 13.4 ppg EMW, 492 psi, 9.3 ppg MW at 2,306' TVD 09:15 - 21:30 12.25 DRILL DRLG INTRM1 Drilled 12 1/4" hole W/Autotrak from 3,822' to 5,151' MD/2,773' TVD, (1,329') ADT 7.2 hrs, 10-25K wob, 120-150 rpm's 155 spm, 657 gpm, off btm pressure 1,900 psi, on btm 1,950 psi, off btm torque 9.5K ft-Ibs, on btm 11 K ft-Ibs, rot wt 99K, up wt 132K, dn wt 74K, 9.2 ppg MW, *** NOTE****Drilled hydrates section from shoe to 4,500', max gas 2,210 units, below 4,500' BGG ave 250-300 units 21 :30 - 22:45 1.25 DRILL CIRC INTRM1 Circ hole at a reduced rate evaluating Autotrak tool, unable to get desired turn rate from tool, decision made to POOH and PU mud motor, downlinked tool for ribs off on Autotrak 22:45 - 00:00 1.25 DRILL TRIP INTRM1 Pumped out of hole from 5,151' to 4,236', pumped out at 339 gpm at 600 psi, backreamed thru tight spot at 4,456' - 4,385' 8/7/2004 00:00 - 00:30 0.50 DRILL TRIP INTRM1 Fin pumping out of hole from 4,236' to 3,750', (inside csg shoe) 339 gpm at 600 psi with no problems 00:30 - 01:15 0.75 DRILL CIRC INTRM1 Circ btms up from 3,750' and clean at shakers, circ at 613 gpm at 1,725 psi 01:15 - 01:30 0.25 DRILL OBSV INTRM1 Monitored well-static, pumped dry job 01 :30 - 02:45 1.25 DRILL TRIP INTRM1 POOH to BHA at 1,060' 02:45 - 03:00 0.25 DRILL OBSV INTRM1 Monitored well at BHA-static 03:00 - 05:15 2.25 DRILL PULD INTRM1 LD ghost reamer and POOH standing back HWDP and jars, LD stab and bit, downloaded MWD, found steering tool on AutoTrak had failed, found a seal leaking on one of the hatches on AutoTrak tool along with a 1 1/2" O-Ring found inside of bit, LD AutoTrak tool 05:15 - 08:45 3.50 DRILL PULD INTRM1 MU directional BHA #3, adjusted MM to 1.4 deg bend, MU short NMDC, MWD and programmed MWD, RIH with HWDP and jars to 1,100' 08:45 - 10:15 1.50 DRILL TRIP INTRM1 TlH with BHA #3 to 3,795' (csg shoe) 10:15 - 12:00 1.75 RIGMNT RSRV INTRM1 Slip and cut 58' of drlg line, serviced top drive, blocks and drawworks coupling 12:00 - 12:45 0.75 DRILL TRIP INTRM1 TIH from 3,795' to 5,002', 12:45 - 13:15 0.50 DRILL REAM INTRM1 Washed 149' to btm with no problems, took check shot survey at 5,095', circ at 420 gpm at 1,200 psi 13:15 - 22:45 9.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole per directional plan from 5,151' to 5,850' MD/3,033' TVD (699') ART -0-, AST 5.4 hrs, 10-20K wob, -0- rpm's, 145 spm, 615 gpm, off btm pressure 1,900 psi, on btm 2,100 psi, off btm torque 10K ft-Ibs, rot wt 106K, up wt 141 K, dn wt 76K, 9.2 MW, ave bgg 100 units 22:45 - 00:00 1.25 DRILL TRIP INTRM1 Backreaming out of hole to 5,268' at drlg rate, 615 gpm at 2,100 psi, POOH to PU AutoTrak tool 8/8/2004 00:00 - 01 :45 1.75 DRILL TRIP INTRM1 Backreamed out of hole at drlg rate from 5,268' to 5,002', pumped out of hole from 5,002' to 3,795', (csg shoe) 615 gpm at 2,100 psi 01 :45 - 02:30 0.75 DRILL CIRC INTRM1 Circ btms up and till clean at shakers, circ at 615 gpm, 1,800 psi and 40 rpm's, circ out large amount of sand, max gas 250 units and dropped Printed: 9/10/2004 9:19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/812004 01 :45 - 02:30 0.75 DRILL CIRC INTRM1 out to 50 units 02:30 - 02:45 0.25 DRILL OBSV INTRM1 Monitored well at shoe-static, pumped dry job 02:45 - 03:30 0.75 DRILL TRIP INTRM1 Began POOH from 3,609' to 3,516' had 25-30K overpull and well / swabbing, had 7 bbl gain, ran back in hole to 3,700' 03:30 - 04:15 0.75 DRILL CIRC INTRM1 Circ 1 complete hole volume to circ out dry job and check gas at btms up, at btms had a max gas of 200 units and dropped right out to 50 units, circ at 615 gpm at 1,800 psi 04:15 - 06:00 1.75 DRILL TRIP INTRM1 Pumped out of hole 5 stds to 3,238' at 148 gpm at 300 psi with no problems, then pulled 3 stds wet and hole was taking calc fill, pumped dry job and POOH to BHA at 1,103' 06:00 - 08:45 2.75 DRILL PULD INTRM1 POOH standing back HWDP and jars, downloaded MWD and LD MWD, MPR and mud motor, cleared rig floor, BHA was clear, swabbing possibly due to sand inside csg 08:45 - 10:45 2.00 DRILL PULD INTRM1 MU 12 1/4" BHA #4 with AutoTrak tool, program AutoTrak and MWD, RIH with BHA #4 to 1,060' 10:45 - 13:15 2.50 DRILL TRIP INTRM1 TIH with BHA #4 from 1,060' to 5,400', tested AutoTrak tool at 1,895', filled pipe at 3,752' and tagged tight spot at 5,400' 13:15 - 13:45 0.50 DRILL TRIP INTRM1 Washed thru tight spot from 5,400' to 5,414', PU and went thru spot with pumps off and had no problems, cont RIH to 5,795' 13:45 - 14:00 0.25 DRILL REAM INTRM1 Washed 55' to btm at 5,850', circ at 678 gpm at 1,750 psi, no problems washing to btm 14:00 - 20:30 6.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole with AutoTrak tool from 5,850' to 6,656' MD/3,303' TVD, (806') ADT 3.4 hrs, 5-25K wob, 120 rpm's, 720 gpm, off btm pressure 1,850 psi, on btm 1,900 psi, off btm torque 15K ft-Ibs, on btm 16K ft-Ibs, rot wt 109K, up wt 163K, dn wt 77K max gas at btms up from ,,/ trip 80 units, ave BGG 50 units, max gas from Ugnu A, 325 units, screens blinding off, Top of Ugnu A @ 6,240' MD/3,170' TVD 20:30 - 21 :30 1.00 DRILL OTHR INTRM1 Changed out shaker screens due to blinding off from Ugnu A 21 :30 - 00:00 2.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole with AutoTrak tool from 6,656' to 6,905' MD/3,366' TVD, (249') ADT 1.8 hrs, 5-25K wob, 120 rpm's, 720 gpm, off btm pressure 1,850 psi, on btm 1,900 psi, off btm torque 15K ft-Ibs, on btm 16K ft-Ibs, rot wt 109K, up wt 163K, dn wt 77K, ave BGG 75 units with 9.2 ppg MW 8/9/2004 00:00 - 11 :00 11.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole with AutoTrak tool from 6,905' to 8,094' MD/3,607' TVD (1,189') 95/8" Csg Pt., ADT 7.1 Hrs, 10-25K wob, 120 rpm's, 720 gpm, off btm pressure 2,000 psi, on btm 2,000 psi, off btm torque 18K ft-Ibs, on btm torque 20K ft-Ibs, rot wt 11 OK, up wt 190K, dn wt 70K. While drlg West Sak sands, BGG ave 200-400 units, max gas 1,200 .- units with 9.3+ MW, Pumped 30 bbl weighted hi-vis sweep prior to T.D. 11 :00 - 12:00 1.00 DRILL CIRC INTRM1 Circ out wt'd hi-vis sweep, had 20% increase in cuttings back from sweep, circ hole at 720 gpm at 2,000 psi and 120 rpms, BGG ave 250 units, downlinked AutoTrak to Ribs Off 12:00 - 14:00 2.00 DRILL TRIP INTRM1 Monitored well-static, backreamed out of hole at drlg rate from 8,094' to 6,997', overlapping ghost reamer from point of last trip 14:00 - 18:30 4.50 DRILL TRIP INTRM1 Pumped out of hole from 6,997' to 3,752', (inside 133/8" csg) pumped out at 720 gpm at 1,800 psi 18:30 - 19:30 1.00 DRILL CIRC INTRM1 Pumped weighted hi-vis sweep and circ out of hole, had 10% increase in cuttings back from sweep, circ 1-add. btms up and was clean at shakers, circ hole at 720 gpm, 1,400 psi and 80 rpm's 19:30 - 19:45 0.25 DRILL OBSV INTRM1 Monitored well at shoe, well-static 19:45-21:00 1.25 DRILL TRIP INTRM1 POOH wet 5 stds and hole took calc fill, pumped dry job and POOH to BHA at 1,060' 21 :00 - 00:00 3.00 DRILL PULD INTRM1 Monitored well at BHA-static, LD ghost reamer, POOH standing back Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: HWDP and Jars, downloaded MWD and LD BHA #4 with AutoTrak, cleared rig floor, calc fill on trip out 44 bbls, actual fill 52 bbls Pulled wear bushing, installed test plug, changed out upper set of VBR's to 9 5/8" csg rams, tested same to 250/3,000 psi, RD test jt and pulled test plug RU Doyons 9 5/8" csg equipment with Franks fill up tool Held PJSM on running 9 5/8" csg with rig crew and tong operator MU 95/8" Float shoe, 2 jts csg, float collar, thread locked btm 3 conn's and circ thru float equip and ch ok, RIH with 93 add. jts along with pup jts for spacing out to 3,725', ran 65 tandem bowspring centralizers on 52 stop rings per well plan (avg MU - 8,000 ft-Ib) 1.00 CASE CIRC INTRM1 Circ a 9 5/8" csg cap at 13 3/8" shoe, staged pump rate up to 6.5 bpm at 350 psi, st wt up 140K, dn wt 87K, 6.25 CASE RUNe INTRM1 Cont RIH with 9 5/8" csg, worked thru tight spot at 5,738', RIH to btm, MU hanger and landed 9 5/8" csg at 8,088' MDI 3,605' TVD with float collar at 8,010', ran a total of 207 jts 9 5/8", 40#, L-80 BTC-M csg with 3-pup jts and hanger (Total 8,061 ') 1.75 CEMEN CIRC INTRM1 Circ btms up with fill up tool, circ and cond mud, staged pump rate up to 6 bpm at 400 psi, reciprocated csg with 285K up wt, 80K down wt, max gas while circ 178 units 0.50 CEMEN RURD INTRM1 RD Franks fill up tool and MU cement head 1.75 CEMEN CIRC INTRM1 Fin circ and condo mud for cementing, circ at 6 bpm at 400 psi, reciprocated pipe with 305K up wt and 75K down, conditioned mud to 9.2 ppg MW, 42 vis, 13 PV, 16 YP, Held PJSM with Dowell, APC vac truck drivers and rig crew while circ and conditioning mud 1.50 CEMEN PUMP INTRM1 Dowell pumped 10 bbls CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped 30 add. bbls (40 total) of CW 100, pumped 57 bbls of MudPush at 10.5 ppg, dropped btm plug then pumped 290 bbls, (726 sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6 bpm at 275 psi, reciprocated pipe with full returns, shut down and dropped btm plug 1.50 CEMEN DISP INTRM1 Dowell pumped 3 bbls FW and turned over to rig and rig displaced cement with 9.1 ppg OBM, bumped plug after pumping 605.5 bbls OBM (95% pump eff.) (Calc Disp 607.75 bbls) ave 7 bpm while displacing cmt, max pressure 1,050 psi, slowed pump rate to 4 bpm with 15 bbls left to pump and bumped plug to 1,600 psi, ck floats and held CI P at 23:55 hrs, reciprocated pipe 1800 strokes into displacement when hole began getting tight and stopped reciprocating, had full returns throughout job, est TOC @ 4,170' Tested 9 5/8" csg to 3,000 psi for 30 min, good test RD cement head and 9 5/8" csg equipment, LD landing jt. Installed 9 5/8" pack-off, energized seals and tested both seals and pack-off to 250 I 5,000 psi for 10 min each RU on 133/8" x 9 5/8" annulus, pressured up to 800 psi and was able to pumped 2.5 bbls into annulus (9.3 ppg mud in annulus) Installed test plug, changed out upper set of pipe rams FI 9 5/8" to 3 1/2" x 6" VBR's, tested same to 250/5,000 psi, pulled test plug and installed wear bushing Serviced top drive and blocks MU 8 1/2" BHA #5 W/Autotrak tool and programmed MWD tool, RIH with 3- flex Dc's, 2 stds of 5" HWDP and jars to 330' TIH with BHA #5, PU 21 jts of 5" DP from pipe shed, MU ghost reamer and cont TIH PU add 104 jts of DP, TIH to 4,703' 8/10/2004 00:00 - 02:00 INTRM1 02:00 - 03:30 1.50 CASE RURD INTRM1 03:30 - 03:45 0.25 CASE SFTY INTRM1 03:45 - 09:45 6.00 CASE RUNC INTRM1 09:45 - 10:45 10:45 - 17:00 17:00 - 18:45 18:45 - 19:15 19:15-21:00 21 :00 - 22:30 22:30 - 00:00 8/11/2004 00:00-01:15 1.25 CASE DEQT INTRM1 01:15 - 02:45 1.50 CASE RURD INTRM1 02:45 - 04:15 1.50 WELCT EQRP INTRM1 04:15 - 05:15 1.00 DRILL INTRM1 05:15 - 07:30 2.25 WELCT EQRP INTRM1 07:30 - 08:00 0.50 RIGMNT RSRV INTRM1 08:00 - 10:30 2.50 DRILL PULD INTRM1 10:30 - 15:00 4.50 DRILL PULD INTRM1 Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/11/2004 15:00 - 17:00 2.00 DRILL TRIP INTRM1 TIH from 4,703' to 7,860' with DP f/ derrick 17:00 - 18:45 1.75 CEMEN DSHO INTRM1 RIH and tagged cement at 8,000', (top of fit Collar @ 8,010'), drilled out plugs and float collar at 8,010', firm cement in shoe jts and float shoe at 8,088', cleaned out to TD at 8,094', drilled at 5-15K wob, 100 rpm's, 509 gpm at 2,500 psi, rot WI 104K up WI 137K, dn WI 82K 18:45 - 19:30 0.75 DRILL DRLG INTRM1 Drilled 20' of new hole from 8,094' to 8,114' MD/3,610' TVD for LOT, ADT .7 hrs 19:30 - 20:15 0.75 DRILL CIRC INTRM1 Circ btms up evening MW in and out at 9.1 ppg OBM, circ at 600 gpm at 3,000 psi 20:15 - 21:15 1.00 DRILL LOT INTRM1 RU and performed LOT to 14.4 ppg EMW, 1,000 psi, at 3,605' TVD with 9.1 ppg OBM mud 21 :15 - 23:00 1.75 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 8,114' to 8,228' MD/ 3,624' TVD, (114') ADT.7 hrs, 5-18K wob, 120 rpm's, 140 spm, 600 gpm, off btm pressure 3,000 psi, on btm 3,050 psi, off btm torque 8K ft-Ibs, on btm 9K ft-Ibs, 9.1 ppg OBM, rot WI 105K, up WI 140K, dn WI 79K 23:00 - 00:00 1.00 DRILL CIRC PROD Circ btms up and performed PWD baseline, with 9.1 ppg mud at 600 gpm and 120 rpms, clean hole ECD = 10.47 ppg 8/12/2004 00:00 - 09:30 9.50 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 8,228' to 9,156' MD/ 3,604' TVD, (928') ADT 5.2 hrs, 5-25K wOb, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,600 psi, on btm 3,675 psi, off btm torque 10.5K ft-Ibs, on btm 1 0.5K ft-Ibs, 9.1 ppg OBM, rot WI 104K, up WI 157K, dn WI 67K, ave BGG 350 units, max gas 725 units. Elbow on #2 mud pump pulsation dampner washed out 09:30 - 20:15 10.75 RIGMNT RGRP PROD Changed out #2 mud pump pulsation dampner, backreamed slowly out of hole from 9,156' to 8,045' (csg Shoe) while working on mud pump, backreamed out at 80 rpm's, 339 gpm at 1,190 psi, changed out pulsation dampner and mud cross 90, found bladder to be bad and changed out also, tightened drive belts on on #2 pump, pressure tested pump to 3,500 psi and checked ok. TIH from 8,048' to 9156' with no problems 20:15 - 00:00 3.75 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 9,156' to 9,518' MD/3,584' TVD, (362') ADT 1.9 hrs, 5-20K wob, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,650 psi, on btm 3,675 psi, off btm torque 12K ft-Ibs, on btm 11 K ft-Ibs, 9.1 ppg OBM, rot WI 100K, up WI 161 K, dn WI 63K, ave BGG 250 units, max gas 675 units 8/13/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 9,518' to 10,641' MD/3,585' TVD, (1123') ADT 6.3 hrs, 5-25K wob, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,800 psi, on btm 3,810 psi, off btm torque 15K ft-Ibs, on btm 13K ft-Ibs, rot WI 101 K, up WI 173K, dn WI 63K, ave BGG 250-350 units, max gas 850 units, 9.0+ OBM, ave ECD 10.9 ppg NOTE: at 11 :45 a spill at the injection skid occured, 25 bbls of OBM was caught inside containment under the injection skid with 3-4 gals going onto the ground 12:00 - 00:00 12.00 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 10,641' to 11,848' MD/3,547' TVD, (1207') ADT 7.0 hrs, 5-20K wob, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,850 psi, on btm 3,890 psi, off btm torque 14K ft-Ibs, on btm 15K ft-Ibs, rot WI 97K, up WI 175K, dn WI 45K, ave BGG 200-350 ./ units, max gas 2000 units, 9.0+ OBM, ave ECD 11.0 ppg, max ECD 11.2 ppg 8/14/2004 00:00 - 06:45 6.75 DRILL DRLG PROD Drilled 8 1/2" hole from 11,848' to 12,394' (763') ADT 3.0 hrs 06:45 - 08:45 2.00 RIGMNT RGRP PROD Repaired top drive service loop, circ hole at a reduced rate and worked pipe slowly 08:45 - 10:30 1.75 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 12,394' to 12,611' MD/3,573' Printed: 9/10/2004 9:19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/14/2004 08:45 - 10:30 1.75 DRILL DRLG PROD 10:30 - 11 :45 1.25 DRILL CIRC PROD 11 :45 - 12:00 0.25 DRILL OBSV PROD 12:00 - 20:30 8.50 DRILL REAM PROD 20:30 - 21 :45 1.25 DRILL CIRC PROD 21 :45 - 22:00 0.25 DRILL OBSV PROD 22:00 - 00:00 2.00 DRILL TRIP PROD 8/15/2004 00:00 - 02:30 2.50 DRILL TRIP PROD 02:30 - 05:00 2.50 DRILL TRIP PROD 05:00 - 06:00 1.00 DRILL PULD PROD 06:00 - 06:30 0.50 CASE RURD CMPL TN 06:30 - 06:45 0.25 CASE SFTY CMPL TN 06:45 - 11 :30 4.75 CASE PULR CMPL TN 11 :30 - 12:45 1.25 CASE OTHR CMPL TN 12:45 - 13:00 0.25 CASE CIRC CMPL TN 13:00 - 15:15 2.25 CASE RUNL CMPL TN 15:15 - 16:00 0.75 CASE CIRC CMPL TN 16:00 - 19:15 3.25 CASE RUNL CMPL TN 19:15 - 20:30 1.25 CASE OTHR CMPL TN TVD, T.D. (546') ADT 1.3 hrs, 10-20K wob, 120 rpm's, 150 spm, 635 gpm, off btm pressure 4,050 psi, on btm 4,100 psi, off btm torque 15K ft-Ibs, on btm 14K ft-Ibs, rot wt 112K, up wt 190K, dn wt 61 K, ave BGG 250-350 units, max gas 1100 units, 9.0 OBM, ave ECD 11.2 ppg, max ECD 11.35 ppg, PU 8 stds of HWDP to TD well, pumped 30 bbl weighted hi vis sweep while drlg last std down Fin circ out wt'd hi vis sweep, had 10% increase in cuttings back from sweep, circ at 635 gpm, 4,050 psi at 120 rpm's, took survey on btm and slow pump rates Monitored well-static Backreamed out of hole from 12,611' to 8,041', inside 9 5/8" csg. Washed and reamed thru tight spot at 11,680', backreamed out at 120 rpm's, 135 spm, 572 gpm, initial circ pressure 3,425 psi, final circ pressure 2,700 psi, no other problems backreaming out Pumped 30 bbl weighted hi vis sweep and circ hole clean, had no increase in cuttings back from sweep, circ a total of 2X btms up, circ hole clean at 572 gpm, 2,700 psi at 80 rpm's, rot wt 96K, up wt 138K, dn wt 75K, off btm torque 9K ft-Ibs Monitored well at shoe-static, dropped 1 7/8" rabbit on wire and pumped dry job POOH with BHA #5 to 6,560', while POOH, installed 17 Lo-Tads onto DP (1/std) POOH 23 stds from 6,560' to 4,424' with BHA #5, MU 23 add. Lo-tads (40 total) POOH from 4,424' to 50', stood back HWDP and BHA to AutoTrak tool Downloaded MWD and stood back AutoTrak tool RU Doyon's 5 1/2" liner running equipment Held PJSM with rig crew and tong operator on running liner PU and ran 5 1/2" liner per well program, ran 5 1/2" ROT silver bullet guide shoe with no float, 159 jts, 5,139.10' of 51/2" 15.5#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 69 jts (2,369') of blank liner and 90 jts (2,768') of slotted liner, ran 1- 51/2" x 8 1/4" spiralglide centralizers 1/jt to shoe (137 total) then ran 12 restrictor packers with 24 spacer rings placed on blank liner to isolate shale sections per geology. MU Baker 190-47 csg seal bore ext' 7" x 9 5/8" Flexlock liner hanger, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 5,204' Est circ at 1.5 bpm at 30 psi, st wt up 85K, dn wt 64K, est rotation at 10 rpm's with 3K ft-Ibs torque and 70K rotating wt RIH with liner on 5" DP to 8,001' Circ 2 DP volumes at 9 5/8" csg shoe, circ at 2 bpm at 200 psi, st wt up 122K, dn wt 80K, rotated at 10 rpm's with 7K ft-Ibs torque and 95K rotating wt RIH with liner in open hole from 8,001' to TD at 12,611' with no problems, tagged btm and PU liner 4' to liner setting depth, 12,607' Dropped 29/32" ball and pumped down to seat, staged up pump rate to 4 bpm at 575 psi, slowed to 3 bpm at 400 psi, with ball on seat pressured up to 2,500 psi to set hanger, then pressure up to 3,500 psi to set packer, cont to set packer by PU and releasing dogs then setting 50K string wt down, then rotated at 10 rpms and set 80K down w/rotating, packer set with no problems, set lower lateral liner with TOL @ 7,413' and shoe at 12,607', st wt up after setting liner 110K Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/15/2004 20:30 - 20:45 0.25 CASE DEQT CMPL TN Tested ZXP liner top packer to 1,000 psi for 5 min, good test 20:45 - 21:45 1.00 CASE CIRC CMPL TN Circ hole with reconditioned 9.0 ppg OBM, circ at 339 gpm at 900 psi 21 :45 - 22:30 0.75 DRILL TRIP CMPL TN Monitored well-static, pumped dry job and began POOH from 7,413', POOH to 6,184' when chain on drawworks broke 22:30 - 00:00 1.50 RIGMNT RGRP CMPL TN Began changing out chain on drawworks 8/16/2004 00:00 - 02:15 2.25 RIGMNT RGRP CMPL TN Finished changing out chain on drawworks 02:15 - 05:00 2.75 DRILL TRIP CMPL TN POOH from 6,184' to 20' to liner running tool 05:00 - 05:30 0.50 DRILL PULD CMPL TN Made service breaks and LD running tool 05:30 - 09:00 3.50 WINDO ULD CMPL TN PU Whipstock and mills to rig floor, MU Baker seal assembly, 2 jts of 5" DP for space out and 9 5/8" Baker btm trip whipstock, milling assembly with LWD/MWD, uploaded MWD and oriented BHA #6 09:00 - 13:00 CMPL TN TIH with whipstock assembly BHA #6, RIH with 9 stds HWDP and slick DP to 6,705', shallow tested MWD at 2,345' and ck ok 13:00 - 13:45 CMPL TN Est Circ and made MAD pass to correlate DP to K-13 sand, Logged down from 6,705' to 6,742' (GR Depth 6,645' to 6,682') corrected MWD 2.5' to put on depth, circ at 510 gpm at 1,975 psi, st WI 142K, dn WI 81 K 13:45 - 14:15 CMPL TN TIH from 6,742' to 7,358' 14:15 - 14:45 CMPL TN Oriented whipstock and RIH, tagged top of liner at 7,413', set btm trip anchor and whipstock at (0 deg) high side, set top of whipstock at 7,305', worked 45K wi down and sheared bolt, no problems shearing bolt, str. wi up after setting whipstock 142K and 81 K dn 14:45 - 18:00 Milled window in 9 5/8" csg, top of window at 7,305', btm of window at 7,321', drilled 81/2" hole to 7,343' MD/3,474' TVD (38'), 2-6K wob, 60-100 rpm's, 510 gpm, 1,800 psi, rot wi 100K, up wi 142K, dn WI 81 K, torque off btm 7K ft-Ibs, on btm 9-13K ft-Ibs 18:00 - 19:00 Pumped hi vis sweep and circ hole clean while working mills thru window, had no increase in cuttings back from sweep, circ at 510 gpm at 1,800 psi, ran mills thru window without any problems 19:00 - 19:15 0.25 WINDO RIP CMPL TN Monitored well-static, pumped dry job and POOH from 7,343' to 7,151' 19:15 - 20:30 1.25 RIGMNT RSRV CMPL TN Slip and cut 123' of drlg line, serviced top drive and drawworks 20:30 - 22:30 2.00 WINDO RIP CMPL TN POOH from 7,151' to HWDP at 936' 22:30 - 00:00 1.50 WINDO ULD CMPL TN POOH to 110', LD 27 jts 5" HWDP and bumper sub, Note: HWDP to be sent in for inspection, and replacement HWDP is on location 8/17/2004 00:00 - 01 :00 1.00 WINDO CMPL TN Rack back MWD in Derrick, Lay down Milling assembly, Jars & HWDP. 01 :00 - 09:45 8.75 WELCT PROD2 Pull wear bushing, Wash out stack, Rig & test BOPE to 250 psi low & 5000 psi high, Hydril to 250 low & 3500 psi high, Test witnessed by AOGCC Jeff Jones, Install wear bushing. 09:45 - 11: 15 1.50 DRILL PULD PROD2 Pick up 29 jts. HWDP, Jars & stand back in derrick. 11 :15 - 15:30 4.25 DRILL PULD PROD2 Pick up Bit, Motor, MWD tools, Orient & Program same, RIH w/ HWDP, Jars, Drill pipe & Ghost reamer, Surface test tools. 15:30 - 18:30 3.00 DRILL TRIP PROD2 RIH to 7,206', Orient & slide thru window @ 7,305' with no problems, Ream down to 7,343' w/ 510 gpm @ 2775 psi. 18:30 - 00:00 5.50 DRILL DRLH PROD2 Drill 8-1/2" hole f/7,343' to 7,943' MD/ 3,465' TVD (600') ART = 2.4 hrs, AST = 1.4 hrs, WOB 5/20K, 80/100 RPM, 550 gpm @ 2800 psi, UP 155K, DN 104K, ROT 73K, BGG 275 units, Ave. ECD's 10.1 ppg wI 9.2 ppg mud. 8/18/2004 00:00 - 12:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole f/7,943' to 9,093' MD/3,446' TVD (1150') ART = 4.7 hrs, AST = 2.5 hrs, WOB 5/25K, 100 RPM, 550 gpm @ 2750 psi, UP 153K, DN 76K, ROT 105K, TQ on btm 10/15K off 11/12K ft/lb, Ave. BGG 400 units, Max gas 1302 units, Ave. ECD's 10.3 ppg wI 9.1 ppg mud. 12:00 - 00:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole f/9,093' to 10,060' MD/3,442' TVD (967') ART = 6.0 hrs, AST = 2.2 hrs, WOB 5/25K, 90/110 RPM, 550 gpm @ 2800 psi, UP Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/212004 End: 8/31/2004 Group: 8/18/2004 12:00 - 00:00 12.00 DRILL DRLH PROD2 160K, DN 70K, ROT 105K, TO on btm 10/11 K off 12K ftllb, Ave. BGG 450 units, Max gas 1022 units, Ave. ECD's 10.4 ppg wI 9.0 ppg mud. 8/19/2004 00:00 - 12:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole f/10,060' to 11,197' MD/3,427' TVD (1,137') ART = 5.2 hrs, AST= 2.0 hrs, WOB 5/20K, 120 RPM, 550 gpm @ 2950 psi, UP 164K, DN 63K, ROT 100K, TO on btm 12/13K off 13/14K ftllb, Ave. BGG 450 units, Max gas 912 units, Ave. ECD's 10.6 ppg w/ 9.0 ppg mud. 12:00 - 00:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole f/11, 197' to 12,215' MD/ 3,405' TVD (1,018') ART = 5.2 hrs, AST = 2.1 hrs, WOB 5/25K, 120 RPM, 550 gpm @ 3200 psi, UP 170K, DN 65K, ROT 108K, TO on btm 15K off 14/15K ftllb, Ave. BGG 410 units, Max gas 795 units, Ave. ECD's 10.8 ppg wI 9.0 ppg mud. Note; Last 24 hours, having extreme difficulty keeping sand content down below 2% due to fine sand. 8/20/2004 00:00 . 02:30 2.50 DRILL DRLH PROD2 Drill 8-1/2" hole f/ 12,215' to 12,468' MD/ 3,394' TVD (253') ART= 1.7 hrs, AST = 0.2 hrs, WOB 5/25K, 120 RPM, 550 gpm @ 3300 psi, UP 176K, DN 74K, ROT 115K, TO on btm 14K / off 14K ftllb, Ave. BGG 410 units, Max gas 738 units, Ave. ECD's 10.9 ppg w/ 9.0 ppg mud, Pumped Hi-vis weighted sweep on last connection. 02:30 - 03:30 1.00 DRILL CIRC PROD2 Circ out sweep- had 10% increase in cuttings, Survey, Monitor well. 03:30 - 10:30 7.00 DRILL TRIP PROD2 Back ream out of hole to 7,200' at drilling rate, No problems - hole in good shape. 10:30 - 12:00 1.50 DRILL CIRC PROD2 Pump Hi-vis sweep & circ hole clean w/3 times btm's up. 12:00 - 13:30 1.50 DRILL TRIP PROD2 Monitor well, Dry pipe, POOH 11 stands to 6,177' (Hole not taking proper fill). 13:30 - 14:30 1.00 DRILL TRIP PROD2 RIH to 7,200', Circ btm's up. 14:30 - 17:30 3.00 DRILL TRIP PROD2 Pump out of hole f/7,200' to 3,800' due to hole not taking proper fill. 17:30 - 20:30 3.00 DRILL TRIP PROD2 Monitor well, POOH on elevators to MWD. 20:30 - 22:00 1.50 DRILL PULD PROD2 Down load MWD tools, Lay down BHA. 22:00 - 00:00 2.00 DRILL TRIP CMPL TN Make up Fixed Lug whipstock retrieving tools, RIH w/ HWDP. 8/21/2004 00:00 - 03:15 3.25 CMPL TN TRIP CMPL TN Continue RIH to 7,260', Break circ wI 253 bpm @ 600 psi, Record weights- UP 136K, DN 86K, Hook whipstock on third attempt @ 7,312', Pull up to 175K & bleed open Jars, Pull on up to 225K and whipstock released, Pull up to 7,260', Observed indicator weight of 142K. 03:15 - 04:00 0.75 CMPL TN CIRC CMPL TN Circ btm's up at rate of 630 gpm @ 2750 psi, Monitor well - Static, Drop rabbit. 04:00 - 09:30 5.50 CMPL TN TRIP CMPL TN Pull 2 stands and observe well for swabbing- OK, Pump dry job, POOH, Lay down whipstock tools to whipstock- No recovery of whipstock, Fixed lug retrieving tool showed damage to upper part of lug where whipstock slipped off. 09:30 - 10:30 1.00 CMPL TN PULD CMPL TN Make up whipstock retrieving BHA #2. 10:30 - 11 :30 1.00 RIGMNT RSRV CMPL TN Service rig, Drawworks, Top drive. 11 :30 - 15:00 3.50 CMPL TN TRIP CMPL TN Make up New Fixed lug retrieving tool, RIH to 7,260', Break circ wI 253 bpm @ 600 psi, Record weights- UP 136K, DN 86K, Hook whipstock @ 7,312', Pull up to 175K & bleed open Jars, Pull on up to 225K and whipstock released, Pull up to 7,260', Observed indicator weight of 142K. 15:00 - 15:30 0.50 CMPL TN TRIP CMPL TN Circ btm's up at rate of 510 gpm @ 1800 psi, Monitor well- Static. 15:30 - 21 :30 6.00 CMPL TN TRIP CMPL TN Pull 10 stands and observe well for swabbing- OK, Pump dry job, POOH, Lay down whipstock tools to whipstock- Recovered whipstock. 21 :30 - 23:00 1.50 CMPL TN PULD CMPL TN Lay down whipstock assembly and clear floor. 23:00 - 00:00 1.00 CASE RURD CMPL TN Rig to run 5-1/2" liner. 8/22/2004 00:00 - 04:00 4.00 CASE PUTB CMPL TN Pick up Total of 152 joints 5-1/2",15.5#, L-80, DWC Slotted liner w/4 jts blank w/2 Swell packers, Ran 150, 5-1/2"x 8-1/4" Centralizers Printed: 9/10/2004 9:19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/22/2004 00:00 - 04:00 4.00 CASE PUTB CMPL TN sliding on every jt., Btm joint blank and bent. 04:00 - 04:30 0.50 CASE PUTB CMPL TN Pick Baker 7"x 9-5/8" B-1 Hook Hanger for LEM. 04:30 - 12:00 7.50 CASE RUNL CMPL TN RIH wI liner, Work liner thru window @ 7,305' to 7,321' (Made thru on 2nd attempt), Continue to RIH to btm UP 170K, DN 88K, Hook liner in window @ 7,324.5' (3.5' low)- Rehook liner to comfirm, TOL @ 7,302.51' wI Shoe @ 12,455.80'. 12:00 - 13:00 1.00 CASE CIRC CMPL TN Drop ball, Circ down at rate of 5 bpm @ 800 psi, Release liner, Shear out ball w/ 4800 psi, Circ btm's up. 13:00 - 16:00 3.00 CMPL TN TRIP CMPL TN Observe well, Dry pipe, POOH, Lay down Baker liner running tools. 16:00 - 18:00 2.00 CMPL TN RURD CMPL TN Clear floor, Rig & make up LEM assembly. 18:00 - 21 :30 3.50 CMPLTN TRIP CMPL TN RIH w/ LEM assembly to 7,300', RIH slow & Latch LEM in Hook hanger @ 7,302' w/ ZXP liner top packer @ 7,245', Check for proper set w/10K over pull- OK. 21 :30 - 00:00 2.50 CMPL TN CIRC CMPL TN Drop ball, Circ down at rate of 5 bpm @ 800 psi, Set ZXP Packer, Release fl running tool & Neutralizer push tool w/ 3800 psi, Pressure test annulus & ZXP packer wI 1500 psi fl 5 min- OK, Rig & shear out ball w/ 5100 psi, Circ btm's up, Observe well, Dry pipe. 8/23/2004 00:00 - 03:30 3.50 CMPL TN TRIP CMPL TN POOH & Lay down LEM running tools. 03:30 - 05:00 1.50 WINDO ULD CMPL TN Make up Whipstock & Milling assembly, Orient tools w/ MWD tools. 05:00 - 09:30 4.50 WINDO RIP CMPL TN RIH wI Whipstock to 6,724'. 09:30 - 10:00 0.50 WINDO CIRC CMPL TN Circ & Madd pass f/ 6,724' to 6,758'. 10:00 - 11 :30 1.50 WINDO SETW CMPL TN RIH to 7,220', Orient whipstock to 15 deg. Left, Tag top of ZXP packer @ 7,249' (3.5' low), Set Anchor, Shear off whipstock bolt w/ top of whipstock @ 7,305'. 11 :30 - 15:30 4.00 WINDO CMPL TN Mill window f/7, 105' to 7,143', (Window f/7, 105' to 7,121'). 15:30 - 16:00 0.50 WINDO CMPL TN Pump Hi-vis sweep, Circ hole clean. 16:00 - 20:00 4.00 WINDO CMPL TN Observe well, Dry pipe, POOH & Lay down Mill assembly. 20:00 - 21 :00 1.00 WELCT PROD3 Rig & wash metal from stack. 21 :00 - 22:30 1.50 DRILL PROD3 Make up 8-1/2" BHA #8, Orient & Program same. 22:30 - 00:00 1.50 DRILL PROD3 RIH w/ BHA to 1,850' 8/24/2004 00:00 - 02:00 2.00 DRILL TRIP PROD3 RIH wI 8-1/2" BHA #10 to 7,021' 02:00 - 03:30 1.50 RIGMNT RSRV PROD3 Cut & slip drilling line, Service rig. 03:30 - 04:15 0.75 DRILL TRIP PROD3 Break eire, Orient & slide thru window @ 7,105' to 7,121' (Window in good shape- No obstructions), Ream out of guage hole f/7, 126' to 7,143'. 04:15 - 12:00 7.75 DRILL DRLH PROD3 Drill 8-1/2" hole f/7, 143' to 7,870' MD/3,407' TVD (727') ART = 2.3 hrs, AST= 2.7 hrs, WOB 2/15K, 120 RPM, 550 gpm @ 2850 psi, UP 146K, DN 70K, ROT 100K, TQ on btm 10K / off 10K ft/lb, Ave. BGG 300 units, Max gas 388 units, Ave. ECD's 10.4 ppg wi 9.0 ppg mud. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 8-1/2" hole f/ 7,870' to 8,970' MD/3,407' TVD (1,100') ART = 601 hrs, AST = 2.2 hrs, WOB 2/10K, 120 RPM, 550 gpm @ 2800 psi, UP 155K, DN 70K, ROT 100K, TQ on btm 12K / off 13K ft/lb, Ave. BGG 300 units, Max gas 1230 units, Ave. ECD's 10.4 ppg wI 9.0 ppg mud. 8/25/2004 00:00 - 12:00 12.00 DRILL DRLH PROD3 Drill 8-1/2" hole f/ 8,970' to 9,805' MD/ 3,408' TVD (835') ART= 7.0 hrs, AST = 1.9 hrs, WOB 2/1 OK, 120 RPM, 550 gpm @ 2900 psi, UP 160K, DN 63K, ROT 102K, TQ on btm 12/13K / off 13/14K ft/lb, Ave. BGG 250 units, Max gas 500 units, Ave. ECD's 10.5 ppg w/ 9.0 ppg mud. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 8-1/2" hole f/ 9,805' to 10,895' MD/3,402' TVD (1,090') ART = 4.1 hrs, AST= 3.1 hrs, WOB 2/5K, 120 RPM, 550 gpm @ 3000 psi, UP 180K, DN 65K, ROT 105K, TQ on btm 15K / off 15K ft/lb, Ave. BGG 520 units, Max gas 700 units, Ave. ECD's 10.6 ppg w/ 9.0 ppg mud. 8/26/2004 00:00 - 06:30 6.50 DRILL DRLH PROD3 Drill 8-1/2" hole f/ 10,895' to 11,469' ART = 1.8 hrs, AST = 1.6 hrs, WOB 5/10K, 120 RPM, 550 gpm @ 3350 psi, UP 195K, DN 60K, ROT 116K, Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/26/2004 00:00 . 06:30 6.50 DRILL DRLH PROD3 TO on btm 16K I off 17K ftIlb, Ave. BGG 500 units, Max gas 580 units, Ave. ECD's 10.8 ppg wI 9.0 ppg mud. Running out of weight to slide with. 06:30 - 07:45 1.25 DRILL TRIP PROD3 Monitor well, Backream out of hole to 11,101', Pick up 12 jts. HWDP. 07:45 - 17:00 9.25 DRILL DRLH PROD3 Drill 8-1/2" hole f/11 ,469' to 12,115' ART = 3.6 hrs, AST = 1.8 hrs, WOB 5/10K, 120 RPM, 550 gpm @ 3400 psi, UP 207K, DN 55K, ROT 133K, TO on btm 17K / off 18K ftlJb, Ave. BGG 400 units, Max gas 580 units, Ave. ECD's 10.8 ppg wI 9.0 ppg mud. Running out of weight to slide with. 17:00 - 18:00 1.00 DRILL TRIP PROD3 Monitor well, Backream out of hole to 11,654', Pick up 15 jts. HWDP. 18:00 - 23:00 5.00 DRILL DRLH PROD3 Drill 8-1/2" hole f/12, 115' to TD 12,457' MD I 3,382' TVD ART = 2.3 hrs, AST= 0.3 hrs, WOB 2I5K, 120 RPM, 550 gpm @ 3400 psi, UP 225K, DN 65K, ROT 126K, TO on btm 18K I off 18K ftIlb, Ave. BGG 400 units, Max gas 648 units, Ave. ECD's 10.9 ppg w/ 9.0 ppg mud, Pump Hi-vis weighted sweep on last connection. 23:00 - 00:00 1.00 DRILL CIRC PROD3 Circ Hi-vis sweep out of hole - 10% increase in cuttings. 8/27/2004 00:00 - 07:00 7.00 DRILL TRIP PROD3 Survey, Monitor well- Static, Back ream out of hole at drilling rate 550 gpm @ 3400 to 2500 psi, 120 RPM, Pulling at rate of 40/45 ftImin., No tight spots - Hole in very good shape. 07:00 - 08:30 1.50 DRILL CIRC PROD3 Pump Hi-vis weighted sweep, Circ hole clean wI 550 gpm @ 2500 psi, while rotating and reciprocating pipe, Monitor well. 08:30 - 13:00 4.50 DRILL TRIP PROD3 POOH to BHA. 13:00 - 14:00 1.00 DRILL PULD PROD3 Lay down NMDC's, Down load & lay down MWD/LWD, Lay down Motor & Bit. 14:00 - 20:30 6.50 DRILL PULD CMPL TN Lay down 60 stands 5" drill pipe from derrick in mouse hole. 20:30 - 00:00 3.50 WINDO RIP CMPL TN Make up Whipstock retrieving tools, RIH to 6,200'. 8/28/2004 00:00 - 00:15 0.25 WINDO RIP CMPL TN Continue RIH w/ Whipstock retrieving tools to 7,111 '. 00:15 - 00:45 0.50 WINDO RIP CMPL TN Break eire, Work & latch onto Whipstock, Jar same loose w/90K overpull, Pull whipstock up to 7,068' (Whipstock dragging 10K over) 00:45 - 01 :30 CMPL TN Circ btm's up at rate of 320 gpm @ 800 psi, Observe well- OK. 01:30 - 06:15 CMPL TN POOH slow due to mild swabbing and hole not taking proper fill, Work pipe up & down in order to make well take proper fill, Hole began taking proper fill after 15 stands, Dry pipe & continue to POOH to BHA slow w/ whipstock. 06:15 - 09:45 CMPL TN Stand back HWDP, Lay down whipstock retrieving tools and whipstock tools, Clear & clean floor. 09:45 - 15:30 5.75 CASE PULR CMPL TN Rig & run Baker 5-1/2" Guide shoe, 1 Bent Blank jt. 5-1/2",15.5#, L-80, DWC liner, 129 jts. Slotted 5-1/2",15.5#, L-80, DWC liner, Pick up Baker 7" x 9-5/8" Model B-1 Hook Hanger for LEM, Rig down casing tongs, Clean floor. 15:30 - 20:00 4.50 CASE RUNL CMPL TN RIH wI liner, Work linerthru window @ 7,105' to 7,121' (Took 3 attempts), Continue RIH w/ liner with no restrictions until the last 25', Work liner to btm- OK. 20:00 - 20:30 0.50 CASE RUNL CMPL TN Run Hook Hanger down and Hooked window on first attempt @ 7,123', Turn Hook & run past window 7'- OK, Turn Hook & rehook window at a final depth (A definite solid hook- Checked 3 times) of 7,124.73', Top of liner @ 7,103.65', Shoe @ 12,435.24'. 20:30 - 22:00 1.50 CASE CIRC CMPL TN Drop & circ down ball on seat at rate of 5 bpm @ 800 psi, Release from liner hanger w/ 3800 psi, Set back 1 stand HWDP, Rig & shear out ball wI 5300 psi using BOP test pump, Circ btm's up at rate of 510 gpm @ 1800 psi. 22:00 - 22:45 0.75 CMPLTN TRIP CMPL TN Monitor well, Dry pipe, POOH w/6 stands HWDP, (Broke Hi gear chain in drawworks). Printed: 9/10/2004 9:19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/28/2004 8/29/2004 8/30/2004 Replace Hi gear chain in drawworks. Continue Replacing Hi gear chain in drawworks. POOH, Lay down Baker liner running tools, Clean rig floor. Rig & RIH w/ 17 stands HWDP, 7 stands drill pipe, Lay down 17 stands HWDP & 1 stand drill pipe- Pipe skate chain broke. Repair pipe skate chain. Finish laying down drill pipe. Rig & Pick up 192jts. 4-1/2",12.6#, L-80, IBTTubing. Circ hole clean at rate of 425 gpm @ 1200 psi, Reciprocate pipe while circ. Monitor well, Pump dry job, POOH & stand back tubing in derrick. Rig & Lay down remaining 5" drill pipe and Lo-Tad's from derrick in mouse hole. Finish laying down remaining 5" drill pipe and Lo-Tad's from derrick in mouse hole. Pull wear bushing, Rig to run 4-1/2" ESP Completion, Held PJSM with all personnel. Make up Motor centralizer to motor, Pump guage, Motor, Seal section, X/O, Screen Intake, Fill motor wI oil, Test & Clamp ESP wire, RIH installing clamps every other jt, Test ESP wire every 10 stands. Make up Vetco Gray hanger UP 85K, DN 60K, Install penetrator, Cut wire & splice same to penetrator. Cont to splice ESP wire and test same, landed tbg at 6,155' MD, RILDS, LD landing jt and tested upper and lower hanger seals to 5,000 psi for 15 min, ck ok, installed TWC ND BOP's NU Vetco Gray tree and adapter, tested adapter void to 5,000 psi for 15 min, ck ok, tested tree to 250 psi low and 5,000 psi high for 5 min each and tested ok, pulled TWC, check ESP penetrator continuity and checked ok 3.50 CMPL TN FRZP CMPL TN RU and displaced out 9.0 ppg OBM to diesel, pumped 460 bbls diesel down 9 5/8" x 4 1/2" annulus at 6,093', initial circ pressure 450 psi at 3 bpm, final circ pressure 875 psi at 3 bpm (thru willis choke) 1.00 WELCT EORP CMPL TN RU lubricator and installed BPV 2.00 CMPL TN OTHR CMPL TN Secured well, finished cleaning out mud pits, RD scaffolding around well and cleaned out cellar RELEASED RIG @ 12:00 hrs, 8/31/04 22:45 - 00:00 1.25 RIGMNT RGRP CMPL TN 00:00 - 01 :00 1.00 RIGMNT RGRP CMPL TN 01 :00 - 04:15 3.25 CMPL TN TRIP CMPL TN 04:15 - 06:30 2.25 CMPL TN TRIP CMPL TN 06:30 - 07:30 1.00 RIGMNT RGRP CMPL TN 07:30 - 08:00 0.50 CMPL TN TRIP CMPL TN 08:00 - 15:30 7.50 CMPL TN TRIP CMPL TN 15:30 - 16:30 1.00 CMPLTN CIRC CMPL TN 16:30 - 20:30 4.00 CMPL TN TRIP CMPL TN 20:30 - 00:00 3.50 CMPL TN PULD CMPL TN 00:00 - 03:45 3.75 CMPL TN PULD CMPL TN 03:45 - 07:30 3.75 CMPLTN RURD CMPL TN 07:30 - 21 :30 14.00 CMPL TN RUNT CMPL TN 21 :30 - 00:00 2.50 CMPL TN RURD CMPL TN 8/31/2004 00:00 - 02:30 2.50 CMPL TN RUNT CMPL TN 02:30 - 03:30 1.00 WELCT NUND CMPL TN 03:30 - 05:30 2.00 WELCT NUND CMPL TN 05:30 - 09:00 09:00 - 10:00 10:00 - 12:00 Printed: 9/10/2004 9:19:43 AM Conoc~illips . ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska SURVEY ulG Page 1 Well bore: 126 Wellpath: MWD wI Sag <0-12611'> Date Printed: 16-Sep-2004 '&ii. BAKER HUGHES INTEQ 1~lbore 126 I creat~ 3-Au -2004 I Last R;'Vised 16-Au -2004 I Well ~ I ~~~~~~~~\I~OO-OO I L9~~U~:;~Ò: Installation Pad 1E 550528.194 5959591.109 AK-4 on NORTH AMERICAN DATUM 1927 datum True l~k_U"' IE sti a ~87754 6208 INorth~ 8985 8206 I~~ = IN"'" 1\1;0,_ I R ERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and 1YD's are from Rig (Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8863.06 Feet on azimuth 153.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ?: Cj L-! - f cl ~ · Conoc~illips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska SURVEY U.G Page 2 Well bore: 126 Wellpath: MWD wI Sag <0-12611'> Date Printed: 16-Sep-2004 "~i. BAKER HUGHES INTEQ Wellpath (Grid) Report MO[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severi~ Vertical Easting Northing Position(Y) Position(X) Sectionfftl 000 000 000 000 OOON OOOF 000 000 <;.1QAAQ ¡:;o ¿I<; 108.00 000 000 10800 OOON OOOF 000 000 <;.1QAAQ ¡:;O A~ 209.41 0.90 114.39 209.41 0.33S 0.72E 0.89 0.26 549890.33 5960439.13 ::1000::1 ? ?4 qq87 ?qq qq o q::l.<=; ::I 1?F 1 5::1 o fl? <;.1QAQ? 7? <;.1 391.52 5,12 9658 ::19128 170S 8MF ::116 08::1 <:" 0<>0<> "'" .81 483.64 9.27 97.96 482.66 3.20S 20.37E 4.51 1.21 549909.99 5960436.39 572.47 12q8 10::1::15 56q 80 fl50S ::I717F 4::1::1 ? 8fl <;.1QQ?¡:; A1 ?O 662.42 15.78 103.17 656.9::1 11.62S 58.91 E ::1.11 584 <;¿I QQ¿lA 5A ?<I 755.04 19.55 101.70 745.16 17.63S 86.36E 4.10 9.16 549976.07 5960422.40 846.00 24.00 98::19 82962 ?::\.42S 11 q58F 507 11.70 <;<;OOOQ ::I? 5960416.83 q::l<; <;0 27.29 99.90 910.29 29.605 157.81 E 3.75 14.15 550047.59 5960410.90 1026.26 29.64 101.60 990.07 37.70S 200.30E 2.74 18.08 550090.13 5960403.09 1118.20 33.68 102.22 1068.32 47.675 247,51E 4.41 23,42 550137.39 4::1 1?11.40 ::17 ::19 100.0<; 1144.1<; 5R.OR'<=; ::IOO.fl4F ¿I.?O ?R fl? 5501qO.!'9 .::18 1304.17 38.95 102.48 1217.08 69.30S 356.86E 2.33 34.33 550246.87 5960372.53 1::1q7 qO ¿l0 <;R 105.56 1289.14 83.845 415.00E 2.73 43.17 550::10511 <17 14q110 4401 107 ::IR 1::1<;R 07 101 fl<;'<=; ¿l7<; 1?F ::I q1 <;<; Ofl <;<;O<l¡:;<; "ILl 1583.57 47.65 107.32 1422.49 121.43S 538.42E 3.94 68.59 550428.76 5960321.61 1fl7<; 7::1 <;009 105.39 1483.11 140.955 605.02E 3.08 81.56 <:<:n"o<: "0 <;<1 17flq?::\ <;::1 11 10::1 4<; 1541 1R 15917'<=; fl7<; qRF ::Ifl? 9? RO <;<;O<;¡:;¡:;<;¡:; f~ 1861.22 57.30 105.05 1593.67 177.78S 749.17E 4.77 104.23 550639.86 5960266.66 19<;5 flO fl::l 5fl 107.34 1640.22 200.715 827.94E 6,96 119 ¿l0 <;<;071R 77 ?OMI5? 69 ?<; 107 fl::l 1 fl77 RO ??fl <;7'<=; q1000F flOfl 1::1717 <;<;OAOO QQ 2142.11 69.33 108.17 1710.54 253.198 992.41 E 0.55 155.67 550883.57 5960192.88 ??::I47::1 fl9 54 107.61 1743.08 279.825 1074.94E 0.61 174.17 <;<;OQ¡:;¡:; ?¡:; 2::1?76::1 68?q 105.R::I 177fl.<;0 ::104 77'<=; 1157 MF ? ?4 1q09::1 <;510494::1 5960142,41 2421.01 66.99 104.87 1812.03 327.63S 1241.22E 1.69 205.61 551132.84 5960120.10 ?51::1.76 fl7.?7 1 05 4fl 184R 07 ::149 99'<=; 1 ::I?::I 70F o flfl 219 R5 <:"."." A'" 2606.33 7086 105.7? 1881.14 ::I7::1.2?S A nn nn~ ::I 89 2::14.90 551298.87 2695.45 70.14 106.23 1910.89 396.348 1487.73E 0.97 250.07 551379.78 5960053.04 ?78Q::I6 70 ::Ifl 1 Ofl ::18 1M?fl::l 4?1 15'<=; o ?8 ?flfl 5::1 <;<;1¿1R11 77 2880.37 69.2Q 10677 HI74 01 44552S ."'". A<l1:: 1?4 28284 <;<; 1 <;¿I¡:; 7Q 2974.98 69.23 106.10 2007.52 470.568 1739.30E 0.67 299.51 551631.81 5959980.50 3067.52 6941 10507 ?040 ?O 4q::l8?S 106 31457 55171535 3160.99 69.26 105,72 2073.18 517,0::15 067 329.49 <;517QQ R1 1" 3252.46 67.41 105.54 2106.95 539.93S 1988.87E 2.03 344.34 551881.81 5959912.79 3346.55 67,44 106.31 214::1.07 56::1.77S 076 ::15996 <;<;1Q¡:;<; '11 ::1440 11 704q 105.18 2176.65 587.465 3.45 ::175 ::17 <:<:?nAO ¡:;Q '>0 3532.82 69.37 105.39 2208.47 610.41S 2240.45E 1.23 390.07 552133.83 5959843.99 3625.15 69.68 105,45 2240.76 6::13,41S 2323.84E 0.34 404.86 552217.36 5q59R?1 54 ::I71fl.45 flfl.q::l 105.75 ??7451 656.228 2405.54E ::1.0::1 41qfl4 <;<;??QQ ?O 3899.31 70.51 106.06 2340.86 702.91S 2569.38E 1.96 450.21 552463.33 5959753.68 ::1990 ::Ifl 700::1 106.53 2371.60 726.96S 2651.64E 0.72 466.15 55?545 74 5q597::10 18 4086.16 69.95 1068Q ?404 ::18 75?84S ?7::17 8flE 0.::16 48::155 552632.12 on 4177.61 70.26 106.39 2435.50 777.47S 2820.24E 0.62 500.06 552714.67 5959680.80 4?70.40 70.?0 104.00 2466.89 ROO.::I5'<=; "nn. ". I:: ?4? 514.flfl <;5?7QQ 07 An 436::1.26 7005 10?flQ ?4984fl 8?051S 1::14 5?647 55288416 on 4456.89 70.42 101.98 2530.13 839.33S 3075.55E 0.82 536.85 552970.35 5959620.64 454897 flQ 85 101 4? ?5fl1 4? R5fl 8Q'<=; 084 54fl 10 <;<;<10<;<; ?¡:; 4fl4?6Q 7016 10115 ?59::14fl 8741::1S 04::1 554 87 55314173 4735.71 70.33 102.44 2624.91 892.02S 3332.42E 1.32 564.36 553227.54 5959569.66 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig (Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8863.06 Feet on azimuth 153.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocJ'Phillips ConocoPhillips Alaslnc.,Slot #126 Pad 1 E, Kuparuk River Unit,North Slope, Alaska SURVEY LI.G Page 3 Well bore: 126 Well path: MWD wI Sag <0-12611'> Date Printed: 16-Sep-2004 ,-'... BAKER HUGHES INTEQ Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severi!) Vertical Easting Northing Position(Y) Position(X) Sectionfft 1 4R2Rlì2 70 ::1::1 102 ::I1ì 21ì!'i1ì 1R 910 R1~ o OR !'i7471ì !'i!'i::l::l1::!10 A. 4918.49 1ì91ì0 1011ì7 2lìRIì 97 92R::I9!=: ~~~~ ..~ 109 !'iM24 <;<;~~9" 7P. .~ 5014.01 68.39 101.89 2721.21 946.59S 3587.74E 1.28 593.89 553483.19 5959516.80 !'i101ì7R 1ì77!'i 102 OR 27!'i!'i R!'i 9M 4!'i~ ::IR71 9?1= 071 RO::l49 <;<;~<;&;7 LIP. <;n 5200.79 1ì1ì20 101ì11ì 2792 M 9R5 !'i1!=: 4::14 1ì11ì::l1 <;<;~&;<;1 "n 5294.94 65.14 111.39 2831.45 1013.10S 3837.00E 5.18 635.89 553732.86 5959451.95 !'i::lRIìIìIì IìR 02 11R 21 2R1ì79::1 ~,~ ,~~ 7 !'i1 IìR::IIì::l <;<;~p.n9 Lln 14 54RO.79 1ì770 12::1.90 290::14::1 ::I9R7971= !'i1ì1 701.12 55::18M.34 5573.03 68.96 129.92 2937.52 1144.83S 4056.45E 6.22 745.70 553953.16 5959321.69 51ì1ì5.89 7078 1::15.R2 291ì9.!'i0 1204.1::1!=: 4120::101= 1ì2R 79R!'i2 !'i54017.39 A? 5758.03 6927 140.46 3000.99 1268.59S 4178.08E 5,01 857.07 554075.59 75 5851.06 68.20 143.94 3034.74 1337.08S 4231.21E 3.67 920.07 554129.18 5959130.63 5941.86 69.40 149.49 30671ì0 140782!=: 42771ì3F 5.85 985.98 554176.06 ')1 RO::l!'i4!'i 1ì977 149.14 310024 0.53 1056.70 "54??1.::I? 6125.38 70.10 150.36 3131.10 1556.22S 4364.95E 1.33 1125.20 554264.35 5958912.40 R?199R R9 M 154,70 3163.51 4.32 1199.68 ""A'>n" Q'" 0'" 1ì::l1254 1ì99!'i 11ì1 ?R 3195.36 6.66 1?7R RR <;<;A,>,>P. 0<; <;<; 6406.10 70.73 168.12 3226.87 1800.49S 4461.73E 6.95 1358.93 554362.75 5958668.80 M91 ?4 7140 173.91 3254.52 .... ""... 1ì,48 1436.84 ""A'>7<; QA '>0 1ì!'i92 00 nR9 1R14" ::I2R!'i4!'i 727 1531.76 <;<;A ~Qn ~') 6684.82 75.02 183.83 3311.11 2064.84S 4474.03E 3.37 1620.83 554376.80 5958404.57 6777.40 7!'i 79 178,16 3334.46 "."'A "0'"' 5.98 1710.10 ""A ,>7<; QA IìR70 ::I!'i 7!'iRO 17779 ::I::I!'i74? ""A """ 044 H99 ::17 <;<;A ~79 &;? 6963.10 75.65 179.09 3380.45 2334.20S 4478.11E 1.36 1888.52 554382.67 5958135.27 7054.77 74.70 181.03 3403.91 2422.81S 4478,02E 229 1976.73 !'i54::1R::I.17 714R41ì 7!'i Olì 1R2.94 ::I42R ::I!'i 4474.89E ?01 201ì1ì 99 !'i54::1RO.Iì::l 7240.79 76.23 183.32 3451.24 2602.51S 4470.00E 1.33 2156.36 554376.34 5957866.93 7::1::1444 7R09 183.96 3472.05 AAC. "".-- 2.09 2247.61 !'i54::171 1!'i 7426,51 7991 1 MIìR ::I4R9 1ì2 278::1 7!'i~ 212 ?::!::I7.91ì <;<;A~1':.4 QiI 7520.11 79.99 185.03 3505.95 2875.58S 4449.60E 0.38 2430.12 554357.75 5957593.76 71ì1219 797!'i 1R!'i 1? ::I!'i221!'i 4441 "RI= O?R ?"?O 71ì <;<;A ~<;n ~~ ,~ 7704,96 7980 18!'i1::1 ::I!'i::lR1ì2 00!'i 21ì120!'i <;<;A "ùl? 7P. .'" 7797.77 80.03 185.67 3554.87 3147.77S 4424.82E 0.62 2703.43 554334.79 5957321.44 78901ì9 79M 1R!'i 1::1 ::I!'i71 11 o 1ì1 2704 92 <;<;A ~?&; 7A '>< 7983,49 79.M 1842!'i ::I5R74R .~n ...... 0.9::1 28Rlì25 ,,<;A ''11 9 9? 8051.32 80.16 184.67 3599.26 3396.49S 4403.55E 0.77 2953.04 554315.17 5957072.61 8181.52 82.79 18771ì ::I1ì1R!'i1ì ""'>A A7C' ::110 ::IOR171ì <;<;A~O? 07 "'''' R?7¡:¡ ?R R¡:¡O::l 186,84 3627,79 3.55 3176.01 ""A')on 71 8367.77 89.47 185.17 3631.38 3708.90S 4368.06E 4.18 3267.41 554281.76 5956760.00 846029 91.92 185.75 3630.21ì 2,72 3359.92 !'i54?7::1 !'i7 R7 R!'i!'i291ì 90RR 184.61 3627.99 3893.24S 1.66 <\4!'i?!'iR <;<;A,)"'<; A? ~~ 8645.95 90.33 185.92 3627.01 3985.84S 4342.36E 1.53 3545.54 554257.90 5956482.93 R7::19.17 9? ?¡:¡ 185.37 3624.91 4078.57S 4333,19E 2,15 3638.73 554249.35 <A RR::I4.2:'I 9::100 1R!'i.::IR ::Ilì20 54 4173.12S 4324.30E 07R ::I7::1::1.1ì9 !'i54241.0R ~~ 8922.88 93.52 183.51 3615.50 4261.35S 4317.44E 2.19 3822.17 554234.81 5956207.28 90174R 9::1 2!'i 184.06 3609.92 4355.58S 431121E 0.65 3916.56 <;<;iI')')o?n 9101ì!'iR 9214 1M 07 ::IIìO!'i 7::1 AAA. "cC' A'>". nn!:: 12!'i 400!'i!'i::l <;<;A ??~ LlA 9202.67 93.25 184.52 3601.21 4540.07S 4297.71E 1.25 4101.49 554216.93 5955928.47 929!'i!'i::l 9::1 22 1M ::I? ::I!'i9!'i 97 n 2? 4104 1R <;<;A?in Lln 93RR,20 9312 1R!'i00 ::I!'i90M Ll7?LI 7~C:: 074 42RIì 70 <;<;A ?no:¡ <;n 9481.19 93.06 184.86 3585.83 4817.24S 4275.07E 0.16 4379.55 554196.13 5955651.18 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8863.06 Feet on azimuth 153.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated c.onocdíhïllips ConocoPhimp. Ala.!.c..Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska SURVEY U.G Page 4 Wellbore: 126 Wellpath: MWD wI Sag <0-12611'> Date Printed: 16-Sep-2004 "~i. BAKER HUGHES INTEQ WellDath (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severi!} Vertical Easting Northing Position(Y) Position(X) Sectionrftl 9573.70 92.85 183.23 3581.06 4Q()Q ,,\QC::: A')'''' """= 1.77 4471.90 "''''Aian ')'" ",at;t;t;t;A aa 9RRR 4!'i 91 1R 1R4 ?n "\!'i77 R? t;nni Aa", ? in 4!'iR4 'i4 t;t;LIiA.d AA rnrr ,nn A7 9759.65 90.14 183.22 3576.76 5094.88S 4256.51E 1.52 4657.68 554179.43 5955373.45 9R!'i? 1!'i 87.41 182.11 3578.74 5187,25S 3.19 47!'in 1'1"\ !'i'i417!'i 74 rnrrnnA n¡; 994!'i Cù1 RRR4 1R3nR 3!'iR3 !'iR t;?7a a?", 133 4M? R7 !'i'i417?1R "'''''''''1 AA "\$1 10036.90 86.68 183.39 3588.91 5371.48S 4242.84E 0.34 4934.30 554167.59 5955096.79 87.29 182.28 3593.75 <;.ð.¡;,,\ ??c::: A')"'A "'n<: 1.38 !'in?R Cù1 t;t;1I1¡;", ¡;¡; t;at;t;nnt;f\A 1n??1 71'1 91'1 RR 182.10 3!'i9!'i ?3 5555.94S 4234.75E 3.87 !'i11R.RR !'i'i41RO.73 "\1'1 10315.68 91.56 184.74 3593.23 5649.72S 4229.15E 2.90 5212.56 554155.75 5954818.49 91.65 187.28 3590.66 5740,99S 4219.54E 2.77 !'i3Cù1.33 !'i'i414R74 !'i9!i47?717 10!'in11R 914R 1 R7 4R 3!'iRR 11 !'iR33 R7C::: 4?n7.!'i?F o ?R !'i397.93 !'i!i4135.3!'i ",a"'"¡;"'A ?"\ 10594.00 91.52 188.28 3585.70 5925.78S 4194.82E 0.89 5490.64 554123.26 5954542.24 91..<19 1R9.9? 3!'iR3.?R 6017.56S 4180.12E 1.7R !'i!'iR341 !'i!i410917 "'a"'"A"'" "\R 107RO.m 9211 191}\? 3!'iRn.:u ß10R.9ßC::: 41ß? 9RF 1.R4 !'iß7ßO!'i <;'i4n9? R4 R7 10871.81 92.91 189.24 3576.32 6199.18S 4146.62E 2.43 5767.43 554076.88 5954268.55 1n"<>A 0'> 93 R3 1R717 3!'i7n R!'i ¡;?a1 n7'" ?43 !'iRßO 17 <;t;LInR4 '14 :'>Hh4' (t),59 110!'i8.79 9407 1MßO 3!'iR437 ¡;"\A.d "\'1C::: 2.74 !'i953.91 t;","n¡:;¡:; ?'" ¡:;a¡:;AnA", ?a 11149.76 93.99 184.21 3557.98 6474.79S 4116.79E 0.44 6044.64 554048.88 5953992.78 91Rn 1R3R9 3!'i!'i3?9 ¡;t;¡;7 "'?c::: 23R ß137.3ß "''''Anll? all t;a",,,,ann ?? 91,40 1R2.9!'i 35!'i0.76 ß657R7S AU.. nn... 1.13 6228.01 !'i'i4n3R 13 rnrnnnn, R4 11428.48 91.13 183.22 3548.66 6752.80S 4099.71E 0.40 6322.99 554033.65 5953714.69 11 !'i?13R R947 1R30!'i 3!i4R 17 ¡;A.d¡:; t;t;c::: 1RO R41!'iBO 554029.18 Q1 89.44 1M.23 3!i49,03 ¡;Q,,\¡; ?¡;c::: An"" "",c 1.30 6506,63 ¡:;¡:;lIn?LI n? t;a¡:;"'¡:;"'1 1R 11706.71 91.25 185.67 3548.47 7030.34S 4080.71E 2.45 6601.06 554016.49 5953437.06 1179221 90.39 1Rß!'i1 3!i47?4 711 !'i.:UC::: 4071 R4F 1.41 ßßR6.!'i!'i "''''Ann7 aa !'iQ<;33!'i? 1'11'1 90.67 1R9.3R 354ß.37 7201'\R3S 405R!'i9E 3.05 6780.86 ¡:;¡:;",aa¡:; ¡:;¡; LILI 11980.43 88.24 188.69 3547.26 7301.47S 4043.86E 2.69 6874.49 553981.45 5953165.72 12073.09 Rß9!'i 1R7.70 3!'i!'i1.1!'i 739310c::: 4030 R7F 17!'i ß9ß6.9ß 553968.86 5953074.01 12162.57 86.83 1R7.49 3556.00 74R1.ß6S 401RB6E 0.27 7056.26 !'i!'i39!'i7 R4 !'i9!'i?9R!'i.3R 12254.48 88.02 187.04 3560.13 7572.748 4007.25E 1.38 7148.03 553946.64 5952894.24 86.R4 1R7.13 3!'iR4.37 7¡;¡;? Q1C::: 1.52 7238,87 ¡:;",,,,a,,,¡;n,,, ¡:;a¡:;')A(\L\ nn 88.45 187.23 3!'iRR ?Q 77<;"\ <;3C::: 1.98 7331'117 ¡:;¡:;",a?¡:; ?? "''''''''71''',32 12527.85 88.36 186.29 3570.82 7843.84S 3973.92E 1.04 7421.09 553915.12 5952622.94 1?¡:;"'1 "'''' 88.98 185.82 3571.60 7877.138 "'a7n ",ac 2.32 74'i4 !'iR !'i!'i3911 R1 "''''''''''''''' R4 1?R11 1'11'1 RR 9R 1R!'iR? 3!'i7? 4R 7a?¡; ¡:;"'''' ",a¡;¡:;",t;¡::: 1'11'11'1 7!'iCù1 ?? <;<;,,\Q(}7 in <;Q<;?'i4n ?1 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8863.06 Feet on azimuth 153.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocJ'Phillips ConocoPhiJIips Alas'nC.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska SURVEY LING Page 5 Well bore: 126 Well path: MWD wI Sag <0-12611'> Date Printed: 16-Sep-2004 r&i. BAKER HUGHES INTEQ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8863.06 Feet on azimuth 153.42 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . (ill 1Ä\ ~ IA\ ~ ~ . FRANK H. MURKOWSK', GOVERNOR A .,ASIiA. OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 1E-126 ConocoPhillips Alaska, Inc. Permit No: 204-122 Surface Location: 4428' FNL, 631' FEL, SEC 16, TllN, R10E, UM Bottomhole Location: 1796' FNL, 1952' FEL, SEC. 27, T11N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) - 07 (pager). BY ORDER OF ¥HE COMMISSION DATED this~day of July, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encL . . ConocoPhillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com July 3, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ./::. . ....,..\ Re: Applications for Perm~ to Drill, West Sak pruduce~ 126 L1 and lE-126 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a multilateral horizontal well in the West Sak "A", "B" and "D" sands. The main bore of the well will be designated 1 E-126, and the lateral bore of the well will be designated 1 E-126L1 ("B" Sand) and 1 E-126L2 ("D" Sand) Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1E-126 is 8/1/2004. If you have any questions or require any further information, please contact Steve Shultz at 263-4620. Sincerely, ~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ORIGINAL 1a. Type of Work: Drill 0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL RedrillU ExploratoryU Development Ojl ~ Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-126 6. Proposed Depth: 12. Field/Pool(s): 01 Kuparuk River Field 20 AAC 25.005 1 b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 4428' FNL, 631' FEL, Sec. 16, T11N, R10E, UM Top of Productive Horizon: 2645' FNL, 1528' FEL, Sec. 22, T11N, R1OE, UM ./ Total Depth: 1796' FNL, 1952' FEL, Sec. 27, T11N, R1OE, UM / 4b. Location of Well (State Base Plane Coordinates): i/ Surface: x- 549890 16. Deviated wells: Kickoff depth: 300 18. Casing Program Size ft. Hole 42" 16" Casing 20"x34" Weight 94# 68# 40# 15.5# 13-3/8 ' 9-518" 12.25" 8.5" 5.5" 19 Total Depth MD (ft): y- 5960439 ., MD: 12575' TVD: 3571' Maximum Hole Angle: Specifications Grade Coupling K-55 Welded L-80 BTC L-80 BTCM L-80 DWC '" 7. Property Designati~; ./ ADL 25651 & 25660 8. Land Use Permit: ALK 469 & 470 9. Acres in Property: 2560 1/ ... Zone- 10. KB Elevation 4 ~ I~) . West Sak Pool 13. Approximate Spud Date: 8/1/2004 14. Distance to Nearest Property: 8764' 15. Distance to Nearest Well within Pool: 1E-112, 953' @ 8121 94° Downhole: 1562 psig Setting Depth (Height above GL): 28 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) / Top Bottom Length MD TVD MD 80' 28' 28' 108' 3858' 28' 28' 3886' 8093' 28' 28' 8121' 4454' 8121' 3617' 12575' TVD 108' 2300' 3617' 3571' PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee 0 Property Plat 0 Length Size Cement Volume MD BOP SketchL! Diverter Sketch 0 Perforation Depth TVD (ft): Drilling Program ~ Seabed Report 0 Time v. Depth Plot U Drilling Fluid Program 0 Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature \ Randy Thomas ~J~ , Surface: 1154 psig Quantity of Cement c. f. or sacks (including stage data) 260 cf ArcticCrete 730 sx ASLite, 200 sx DeepCrete 710sx DeepCrete slotted liner TVD Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team Leader Phone (:.¿,r 6f ~ Ò Date '? /'710" PrevarRrl hv 8haron Allc"n-nrpkp Commission Use Only API Number: Permit APpro1 /. 50- ózq... 232./Ç-CJD Date: 1//;; / I; L/ Conditions of approval: Samples required 0 Yes ~No Mud log required 0 Yes g No ~drogen sulfide measures 0 Yes ~NO Directional survey required ~Yes 0 No """,,,~r ~, ?Y:f'" \ ""-. "" \',M' ~¡,., ~OÇ> ~Ö\. ì r«. n,Q. \ ~ S ~\.., r\ \..6." \L\ ~h'" ( L,/r,),'f I BY ORDER OF ... j í^;t'J~ Approved~: /~tI\.. THE COMMISSION Date: 1/10 ð ï ~ Form ~ R~ W200:- 0 RIG I N A L I sUbL in D:Plicate Permit to Drill. . i ~ Number: 2Õ 7- I Z 2- See cover letter for other requirements · .tion for Permit to Drill, Well 1 E-126 Revision No.O July 3, 2004 Permit It - West Sak Well #1 E-126 ("A" Sand) Application for Permit to Drill Document Mo)xi.....izE Well Vgll,J~ Table of Contents 1. Well Name .....................................................................................................................2 Requirements of 20 AA C 25.005 (f) ........... ...... ........ ....... ............. ......... ..... ..... ...... ....... ...... ......... ........ 2 2. Location Summary....................................................................................................... 2 Requírements of 20 AA C 25.005(e)(2) .... ......... ............. ....... ........ ..... ....... .................. ....... ......... ......... 2 Requírements of 20 AA C 25. 050(b) .................................................................................................... 3 3. Blowout Prevention Equipment Information ............................................................3 Requírements of 20 AA C 25. 005( e)(3) ................................................................................................ 3 4. Dri Iii ng Hazards Information ...................................................................................... 3 Requírements of 20 AAC 25.005 (e)( 4) .. ..... ...... ............... ........... ......... ....... ............ ..... ............... ........ 3 5. Procedure for Conducting Formation Integrity Tests.............................................3 Requírements of 20 AAC 25.005 (e)(5) ...... ........ ....... ...... ........ ..... ........ ...... .......... ......... ....... ........ ....... 3 6. Casi ng and Cementing Prog ra m................................................................................ 4 Requírements of 20 AAC 25.005(e)(6) ....... ........ ..... ....... ............... ..... ......... ........... ...................... ....... 4 7. Diverter System Information ......................................................................................4 Requírements of 20 AAC 25.005(e)(7) ..... ......... ...... ....... ....... ........ .... ........ ............. ..... ...... ......... ......... 4 8. Dri II i ng Flu id Prog ram................................................................................................. 5 Requírements of 20 AAC 25.005(e)(8) ..... ....... ........ .............. ....... ...... ........ .................. ...... ...... ........... 5 Lateral Mud Program (MI FloPro NT) .......... ...... ................ ........ ........... ......... .......... ........ ..... ...... ......... 5 9. Abnormally Pressured Formation Information ........................................................ 5 Requírements of 20 AAC 25.005 (e)(9) . ...... ..... ................. ........ ......... ......... .......... .......... ............. ....... 5 1 O. Seism ic Analysis.......................................................................................................... 5 Requírements of 20 AAC 25.005 (e)(10) .. ......... ........ ..... .............. ................ .... ...... .............. ....... ........ 5 11. Seabed Condition Analysis .............................. .......................................................... 5 Requírements of 20 AAC 25.005 (e)(11) ... .............. ........ .............. ..... .......... ........... ...... ....... ........ ....... 5 12. Evidence of Bonding .......... .................... ............. ......... ............................................... 6 Requírements of 20 AAC 25.005 (e)(12) ... ....... ........ ...... ........ .............. ....... ................... ............... ...... 6 ORIGINAL PERMIT /T (Producer) RevO.doc Page 10'8 Printed: July 3, 2004 · .tion for Permit to Drill, Well 1 E-126 Revision No.O July 3, 2004 13. Proposed Drilling Program ............................................ ........... ....................... ..... ...... 6 Requirements of 20 AAC 25.005 (c)(13) .......... ...... ....... .............. ........................ ...... ...... ....... ........ ..... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................1 Requirements of 20 AAC 25.005 (c)(14) . ....... ............ ......... ............ ........ ...... ...... ...... ..... ............. ........ 7 15. Attach ments.................................................................................................................. 8 Attachment 1 Directional Plan ... ....... .... ......... ...... ..... ......... ...... ..... ........ ........... ........ .......... .......... ....... 8 Attachment 2 Drilling Hazards Summary... ... ........ ..... ........ ....... ..... ........ ....... ...... ............ .............. ....... 8 Attachment 3 Cementng Data.......... ...... ...... ........ ..... ........ ........ .... ........ ....... ...... ...... ...... .... ....... ... ....... 8 Attachment 4 Well Schematic.. ........ ..... ........ ...... ..... ........ ........ .... ....... ........ ........... ........ ... .......... ....... 8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1E-126. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surfacer at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates ofthe proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface I ASP Zone 4 NAD 27 Coordinates Northings: 5,960,439 Eastings: 549,890 FNL:4428', FEL:631', See 16, TllN/RlOE, UM RKB Elevation I 94.3' AMSL I Pad Elevation I 66.3' AMSL Location at Top of Productive Interval FNL:2645', FEL:1528, See 22, T11N/R10E, UM ,,' (West Sak "A" Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 8121' Northings:5,956,972 Eastings: 554,303 Total Vertical Depth, RKB: 3617' Total Vertical Depth, 55: 3522.7' Location at Total De th ASP Zone 4 NAD 27 Coordinates Northings:5,952,539 Eastings: 553,918 FNL:1796', FEL:1952', See 27, T11N/R10E, UM Measured De th, RKB: Total Vertical De th, RKB: Total Vertical De th, 55: ./ 12575' 3571' 3476.7' i.- and (D) other information required by 20 MC 25. 050(b); OR\GiNAl PERMIT IT (Producer) RevO.doc Page 2 of 8 Printed: July 3, 2004 · .tion for Permit to Drill, Well 1 E-126 Revision No.O July 3, 2004 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviate~ the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c){3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25. 036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-126. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c){4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountere~ criteria used to determine it, and maximum potential surface pressure based on a methane gradient," The expected reservoir pressures in the West Sak sands in the 1E-126 area vary from 0.0.42 to 0.0.45 ,; psi/ft, or 8.1 to 8.6 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand formation is 1154.46 psi, calculated thusly: MPSP =(3470 ft)(0.0.45 - 0.11 psi/ft) =1154.46 psi (B) data on potential gas zones; ,/ The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identitied in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25. 030(!); The parent wellbore,lE-126, will be completed with 9 5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance ORIGINAL PERMIT IT (Producer) RevO.doc Page 3 of 8 Printed: July 3, 2004 · .tion for Permit to Drill, Well 1 E-126 Revision No.O July 3, 2004 with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c){6) An application for a Permit to Drill must be accompanied by each of the fol/owing item~ except for an item already on file wIth the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25. 030, and a description of any slotted line¡; pre- perforated line¡; or screen to be installed; Casing and Cementing Program See also Attachment 3, APD for 1E-126: Cement Summa/) Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 X 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE 13 3/8 16 68 L-80 BTC 3858 28 / 28 3886 /2300 Cemented to Surface with 730 sx ASLite Lead, 200 sx DeepCRETE Tail 95/8 12 1/4 40 L-80 BTCM 8093 28 / 28 8121 / 3617 Cement Top planned @ 4266' MD / 2440' 1VD. Cemented w/ 710 sx DeepCRETE 51/2 8 1/2" 15.5 L-80 DWC 4454 8121/3617 12575/3571 Slotted- no slotted "A" Lateral cement (lE-126) 51/2 81/2" 15.5 L-80 DWC 5138 7300/3475 12438/3401 Slotted- no slotted "B" Lateral cement ( lE-126 Ll) 51/2 81/2 15.5 L-80 DWC 5380 7054/3418 12434/3335 Slotted-no slotted "D" Lateral cement (IE-126 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c){7) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 M C 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h}(2); A diverter system will be used ,/ ORIGINAL PERMIT IT (Producer) RevO.doc Page 4 of 8 Printed: July 3, 2004 · eation for Permit to Drill, Well 1 E-126 Revision No.O July 3, 2004 Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (8) a drilling tluid program, including a diagram and description of the drilling tluid system, as required by 20 MC 25, 033,' Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Properties Surface Intermediate Production Density (ppg) 8.6-9.2 9.0-9.2 9-9.2 Funnel 150-300 45-55 30 Viscosity (seconds) Yield Point 30-70 26-30 18-28 (cP) Electric Stability NA NA 650-900 Chlorides (mg/I) <500 <500 40000 pH 8.5-9.0 9.0-9.5 N/A API filtrate <6 <6 <4 (cc / 30 min) **HTHP filtrate <10 <10 <10 (cc / 30 min) MBT (Ib / gal) NA NA <5 ,/ Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test we/~ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f),' Not applicable: Application is not for an exploratory or stratigraphic test well. 8. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test we/~ a seismic refraction or refiection analysis as required by 20 AAC 25.061(a)/ Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following Items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or tloating drilling vesse~ an analysis of seabed conditions as required by 20 AAC 25,061(b)/ Not applicable: Application is not for an offshore well. ORIGINAL PERMIT IT (Producer) RevO.doc Page 5 of 8 Printed: July 3, 2004 . .ation for Permit to Drill, Well 1 E-126 Revision No.O July 3, 2004 10. Evidence of Bonding Requirements af 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. Ilt""M. 'I (( ~-o ~ Note: nder the 1 E- pplication for Permi rill 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon 141. Install 21-1/4" Annular with 16" diverter line and function test. ./" 3. Spud and directionally drill 16" hole to casing point at +/- 3886' MD / 2300' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 133/8",68#, L-80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 hrs before test. 6. PU 12 1/4" bit and drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 9 5/8" casing point at 8121 MD / 3617' TVD. ./ 9. Run 9 5/8", 40# L -80, BTCM Mod casing to surface. Pump cement and displace with mud and pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead 9 5/8" packoff and test to 5000 psi. 11. flush 13 3/8" x 95/8" annulus with water, followed by diesel. ../ 0/ 12. PU 8 1/2" Bit and drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. 14. Directionally drill 81/2" hole to TD at +/- 12575' MD / 3571' TVD as per directional plan. / ~~ ~015. POOH, back reaming out of lateral. POOH. ~ ~ 16. PU and run 5 1/2" slotted liner. '\ 17. Land liner, set liner hanger. Displace liner annulus 11. Proposed Drilling Program Requirements af20AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program for 1E-126 is listed below. 'T~\~ ~Q~'\- ~ . hted brine. POOH. Note: Remaining operations are covered under the 1E-126L1 Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of 7300' MD / 3475' TVD, the top of the B sand. ORIGINAL PERMIT IT (Producer) RevO.doc Page 6 of 8 Printed: July 3, 2004 · eation for Permit to Drill, We1l1E-126 Revision No.O July 3, 2004 19. Mill 8 1/2" window. POOH. 20. Pick up drilling assembly with LWD and MWD and PWD. RIH. 21. Displace to new drilling mud at ppg. Drill to TO of B sand lateral at 12438' MD /3401' 1VD, as per directional plan. 22. POOH, back reaming out of lateral. POOH. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 5 1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool, POOH. 27. PU Lateral Entry Module "LEM", RIH and latch unit into hook hanger, shear off POOH Note: Remaining operations are covered under the 1E-126L2 Application for Permit to Drill, and are provided here for information only. 28. Run and set Baker WindowMaster whipstock system, at window point of 7054' MD /3418' 1VD, the top of the 0 sand. 29. Mill 8 1/2" window. POOH. 30. Pick up drilling assembly with LWD and MWD and PWD. RIH. 31. Drill to TO of 0 sand lateral at 12434' MD /3335' 1VD, as per directional plan. 32. POOH, back reaming out of lateral. POOH. 33. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 34. PU and run 5 1/2" slotted liner. 35. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 36. Release hanger running tool, POOH. 37. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing, Set BPV. 38. Nipple down BOPE, nipple up tree and test. 39. Pull BPV and move rig off. 40. Freeze protect well with diesel by pumping into 4 1/2"" x 9 5/8" annulus, taking returns from tubing and allowing to equalize. 41. Rig up wire line unit. 42. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. 43. Replace gas lift valves with blank dummy valves. 44. Run ESP through tubing. 45. Operate well with ESP 12. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. 080 for an annular disposal operation in the wel/.; ORIGINAL PERMIT IT (Producer) RevO.doc Page 7 of 8 Printed: July 3, 2004 · .ation for Permit to Drill, Well 1 E-126 Revision No.O July 3, 2004 Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids u into a permitted annulus on IE Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on IE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 13. Attachments Attachment 1 Directional Plan Attachment 2 Drillíng Hazards Summary Attachment 3 Cementing Data Attachment 4 Well Schematic ORIGINAL PERMIT IT (Producer) RevO.doc Page 8 of 8 Printed: July 3, 2004 · . lE-126 Drilling Hazards Summarï (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 16" Open Hole 113 3/8" Casing Interval Hazard Broach of Conductor Risk Level Low Gas Hydrates Low Running Sands and Gravels Moderate Hole swabbing on trips Moderate Miti ation Strate Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Dri Itreat. Maintain planned mud parameters, Increase mud weight, use weighted swee s. Trip speeds, Proper hole filling (use of trip sheets um in out 12 1/4" Open Hole I 9 5/8" Casing Interval Hazard Running Sands and Gravels Risk Level Moderate Stuck Pipe Low Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips "Il Low Low Moderate Miti ation Strate Maintain planned mud parameters, Increase mud weight, use weighted swee s. Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, Decreased mud wei ht BOP training and drills, increased mud wei ht. Reduced um rates, mud rheolo ,LCM Trip speeds, Proper hole filling (use of trip sheets, um in out 8 1/2" Open Hole I 5 1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low v Low Lost Circulation Hole Swabbing on Trips Moderate High Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole o ener, Decreased mud wei ht Reduced um rates Mud rheolo LCM Trip speeds, Proper hole filling (use of trip sheets, Pum in out ORIGINAL 1E-126 Drilling Hazards Summary prepared by Steve Shultz 5/27/2004 9:26 AM Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 6/28/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < Toe at Surface Previous Csg. < 20", 91.5# casing at 120' MO < Base of Permafrost at 1,750' MD (1,513' TVO) < Top of Tail at 3,100' MD < 133/8", 72.0# casing in 16" OH TO at 3,900' MD (2,305' TVD) Mark of Schlumberger Scblulb8PgBP Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 30% excess below the permafrost. The top of the tail slurry is designed to be at 3,100' MD. Lead Slurry Minimum pump time: 280 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 122.3 ft3 2399.5 ft3 738.2 ft3 3260 ft3 732.6 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 200 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 437.4 ft3 66.5 ft3 503.9 ft3 200 sks BHST = 51 of, Estimated BHCT := 66°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (minl CW100 5.0 10.0 2.0 2.0 Pause 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 MUDPUSH II 6.0 50.0 8.3 28.3 Pause 0.0 0.0 5.0 33.3 ASL 7.0 585.6 83.7 117.0 DeepCRETE 5.0 92.7 18.5 135.5 Pause 0.0 0.0 5.0 140.5 Water 5.0 20.0 4.0 144.5 Pause 0.0 0.0 5.0 149.5 Mud 7.0 530.7 75.8 225.3 Mud 3.0 15.0 5.0 230.3 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 17-21, Ty ? 20-25 Centralizers: Program calls for 1 per joint in tail cement section. ORIGINAL Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 6/28/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265~205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 133/8", 72.0# casing at 3,900' MD < Top of Tail at 4,266' MD < 95/8", 40.0# casing in 12 1/4" OH TDat8,121'MD (3,617' TVD) ScIIlUlRblPgBP Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 30% excess. Tail slurry is designed for +/- 1000' MD above Ugnu - (3855' MD annular length). Tail Slurrv Minimum thickening time: 250 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 1569.6 ft3 34.1 ft3 1603.7 ft3 709.6 sks ::: BHST::: 85°F, Estimated BHCT ::: 73°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bb!) (min) CW100 5.0 10.0 2.0 2.0 Pause 0.0 0.0 10.0 12.0 CW100 5.0 30.0 6.0 18.0 MUDPUSH II 6.0 40.0 6.7 24.7 Pause 0.0 0.0 5.0 29.7 West Sak DeepCRETE 5.0 285.6 57.1 86.8 Pause 0.0 0.0 5.0 91.8 Mud 7.0 594.7 85.0 176.8 Mud 3.0 15.0 5.0 181.8 MUD REMOVAL Recommended Mud Properties: 9.2 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv::: 21-25, Ty ::: 25-29 Centralizers: Recommend 1-~ bow centralizers per joint to a point 800' MD above West Sak "D" sand lateral and 1 per joint across the Ugnu formation. ORIGINAL Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 68.70 2686.54 911.498 56 68.42 2704.58 924.298 57 67,95 2741.76 955,688 58 67.63 2779.59 994.228 59 67.45 2817.82 1039.678 60 67.41 2856.22 1091.738 61 67.53 2894.55 1150.108 62 67.79 2932.58 1214.428 63 68.19 2970.08 1284.288 64 68.70 3004.49 1354.338 65 68.70 3006.81 1359.258 66 68, 3043.14 1436.348 67 68.70 3079.47 1513.438 68 68.70 3115. 1590.518 69 68.70 3118. 1595.198 70 68.95 3151. 1669.538 71 69.36 3187. 1752.598 72 69.89 3222.38 1839.198 73 70. 3256.23 1928.808 74 71.34 3288, 0.878 75 72,24 3320.15 2114.838 76 73.25 3349.82 2210,098 77 74.36 3377.73 2306.098 78 75.00 3392, 2358.458 79 75.00 3403.91 2402.238 80 75.00 3418.00 2454.588 81 75.00 3429.79 2498.378 82 75.00 3438.44 2530.498 83 78.00 3461.78 2627.268 84 80.00 3474.50 2692.398 85 80. 3491.85 2790.338 86 80.00 3509.22 2888.348 87 80.00 3526.58 2986,368 88 80.00 3543.95 3084,388 89 80.00 3561 .31 3182.398 90 80.00 3578.68 3280.418 91 80.00 3596.04 78.438 92 80.00 3613.41 .448 93 80.00 3623.79 .068 94 84.00 3637. .608 95 88.00 3644.68 3732.868 96 90.41 3645.51 3792,948 97 91.17 3644.13 3892.468 98 91.92 3641.45 3991.958 99 92.67 3637.45 4091.408 100 93.35 3632.68 4181.788 101 93.35 3627. 4270.108 102 93.35 3621.65 4369.468 103 93.35 3621.27 4375,998 104 92.60 3616.09 4475.388 105 91.85 3612.21 4574.838 106 91.10 3609.64 74.338 107 90.41 3608.44 64.828 108 89,66 3608.37 358 109 88.91 3609.61 .878 110 88.16 3612,1 .378 111 87.91 3613. 5097.198 112 87.91 3615. 5165.328 113 87.91 3619.4 5264.788 114 87.91 3622,6 5352.258 115 88.66 3625.67 5451.738 116 89.41 3627.35 5551.258 117 90.16 3627.73 5650.778 I 118 90.81 3627.00 554099,94 5736.508 119 91.00 3626.59 554097.61 5762.298 120 91.74 3624.20 554088.73 5861.818 121 92.48 3620.53 554080.07 5961.318 122 93.22 3615.56 554071.64 6060.778 123 93.74 3611.29 554065,83 6130.728 124 93.74 3609.36 554063.41 60.188 125 93.74 3602.84 554055.23 59.578 126 93.74 3596,32 554047.06 6358.978 127 93.74 3592.01 554041.65 6424.658 128 92.99 3586.15 554033.48 6524.088 129 92.24 3581.59 554025.29 6623.598 130 91. 3578.65 554018.07 11 .468 131 90.83 3576.55 554009.88 6811.048 132 90.08 3575.77 554001.68 6910.658 133 89.33 3576.29 553993.49 7010.258 134 88.64 3577.90 553986.04 7100.818 135 88.64 3579,19 553981,56 7155.308 136 88.64 3581, 553973,37 54.888 137 88.64 3582.50 553970.12 7294.428 138 89.39 3584.21 553961,93 7394,018 139 90.14 3584.62 553953.74 7493.618 140 90.89 3583.71 553945.54 7593.228 141 91. 3581. 553938.10 7683.778 142 92.33 3578. 553929.91 7783.328 143 93.08 3573.63 553921.73 7882.828 144 93.42 3571.07 553918.03 7927.818 I . . .,^' ConocòPhillips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 1 Well bore: 126 Well path: 126 Ver#4 Date Printed: 30-Jun-2004 ... ... INTEQ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8869.10 Feet on azimuth 153.36 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ~/ ConocòPhillips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 2 Wellbore: 126 Well path: 126 Ver#4 Date Printed: 30..Jun-2004 .... 'III.s INTEQ ... .. ...... ....... < > ...... ......> .......... ..... ... /.... ..... ... ...... i' MO[ftt · '.. .,... ..,. ."" 'iT\ft>{ftF peþ(hJ,$ "V, ~'I"¡ I Ëast[ftL ....... §tì:lt1on. .... þ1ì:1tloO ..... .",. -'" .... ~1éttf()n ........ .. < ii < North) Ëast) . IÒftf ....... .< .... ............. lu < / 0.00 0.00 0.00 0.00 -99.00 O.OON O.OOE 5960439.45 549889.60 0.00 0.00 Tie on 100.00 0.00 0.00 100.00 100 O.OON O.OOE 5960439.45 549889.60 0.00 0.00 200.00 0.00 0.00 200.00 101.00 O.OON O.OOE 596Q439.45 549889.60 0.00 0.00 300.00 0.00 0.00 300.00 201.00 O.OON O.OOE 5960439.45 549889.60 0.00 0.00 KOP End of Hold 400.00 3.50 95.00 399.94 300.94 0.27S 3.04E 5960439.20 549892.64 3.50 -0.03 500.00 7.00 95.00 499.50 400.50 1.065 12.16E 5960438.47 549901.76 3.50 -0.12 585.71 10.00 95.00 58427 485.27 2.175 24.77E 5960437.45 549914.39 3.50 -0.25 Bld/Trn 4/100. End of Build/Turn 600.00 10.56 95.53 598.32 499.32 2.40S 27.31E 5960437.23 549916.93 4.00 -0.26 700.00 14.53 98.10 695.92 596.92 5.055 4886E 5960434.72 549938.49 4.00 0.29 800.00 18.50 99.59 791.77 692.77 9.47S 76.93E 5960430.49 549966.59 4.00 1.96 837.57 20.00 100.00 827.24 728.24 11.585 89.14E 5960428.47 549978.81 400 2.87 Bld/Trn 5/100 End of Build/Turn 900.00 23.11 100.69 885.30 786.30 15.71S 111.70E 5960424.49 550001.39 5.00 4.79 1000.00 28.10 101.50 975.45 876.45 24.055 154.09E 5960416.43 550043.83 5.00 8.98 1100.00 33.09 102.08 1061.50 962.50 34.46S 203.89E 5960406.35 550093.70 5.00 14.52 1146.58 35.42 102.30 1100.00 1001.00 39.995 229.52E 5960400.98 550119.36 5.00 17.54 Bld/Trn 3/100 End of Build/Turn 1200.00 37.01 102.53 1143.10 1044.10 46.785 260.34E 5960394.41 550150.22 3.00 21.30 1300.00 40.00 102.92 1221.34 1122.34 60. 50S 321.06E 5960381.09 550211.03 3.00 29.07 1400.00 42.99 1 03.27 1296.23 1197.23 75.515 385.59E 5960366.51 550275.65 300 37.75 -~ 1405.16 43.15 103.28 1300.00 1201.00 76.32S 389.02E 5960365.72 550279.08 3.00 38.22 Bld/Trn 5/100 End of Build/Turn 1500.00 47.88 103.69 1366.44 1267.44 92.115 454.80E 5960350.37 550344.95 5.00 47.55 1600.00 52.87 104.07 1430.19 1331.19 110.59S 529.55E 5960332.39 550419.82 500 58.70 1700.00 57.87 104.40 1487.00 1388.00 130.825 609.28E 5960312.69 550499.67 5.00 71.10 1746.64 60.20 104.54 1511.00 1412.00 140.815 648.00E 5960302.96 550538.46 5.00 77.28 Base Permafrost 1800.00 62.86 104.69 1536.43 1437.43 152.645 693.38E 5960291.43 550583.91 5.00 84.66 1900.00 67.85 104.96 1578.12 1479.12 175.895 781.22E 5960268.77 550671.89 5.00 99.28 1916.89 68.70 105.00 1584.37 1485.37 179.95S 796.38E 5960264ßi 550687.07 500 101.84 EOC ,End of Build/Turn 2000.00 68.70 105.00 1614.56 1515.56 199.995 871.17E 5960245.27 550761.99 0.00 114.53 2100.00 68.70 105.00 1650.89 1551.89 224.10S 961.16E 5960221.76 550852.13 0.00 129.80 2200.00 68.70 105.00 1687.22 1588.22 248.215 1051.16E 5960198.25 550942.28 0.00 145.07 2300.00 68.70 105.00 , 1723.55 1624.55 272.335 1141.15E 5960174.73 551032.42 0.00 160.34 2356.28 68.70 105.00 174400 1645.00 285. 90S 1191.79E 5960161.50 551083.15 0.00 168.93 Too T-3 2400.00 68.70 105.00 1759.88 1660.88 296.445 1231.14E 5960151.22 551122.56 000 175.61 2500.00 68.70 105.00 1796.21 1697.21 320.555 1321.13E 5960127.71 551212.70 0.00 190.88 2600.00 68.lQ... 105.00 1832.54 1733.54 344.675 1411.13E 5960104.19 551302.84 0.00 206.15 270Q.00 68.70 105.00 1868.87 1769.87 368.785 1501.12E 5960080.68 551392.99 0.00 221.42 2800.00 68.70 105.00 1905.20 1806.20 392.89S 1591.11E 5960057.17 551483.13 0.00 236.69 2900.00 68.70 105.00 1941.53 1842.53 417.015 1681.10E 5960033.65 551573.27 0.00 251.96 3000.00 68.70 105.00 1977.86 1878.86 441.125 1771.10E 5960010.14 551663.41 0.00 267.23 .- 3100.00 68.70 105.00 2014.19 1915.19 465.245 1861.09E 5959986.63 551753.55 0.00 282.50 3200.00 68.70 105.00 2050.52 195152 489.355 1951.08E 5959963.12 55184369 000 297.77 3223.33 68.70 105.00 2059.00 1960.00 494.975 1972.08E 5959957.63 551864.72 0.00 301.33 Top K-15 3300.00 68.70 105.00 2086.85 1987.85 513.465 2041.08E 5959939.60 551933.84 0.00 313.04 3400.00 68.70 105.00 2123.18 2024.18 537. 58S 2131.07E 5959916.09 552023.98 000 328.31 3500.00 68.70 105.00 2159.51 2060.51 561.695 222106E 5959892.58 552114.12 0.00 343.58 --ªººº'ºº- ~.68.70 105.00 2195.84 2096.84 585.80S 2311.05E 5959869.06 552204.26 0.00 358.85 3700.00 6ß.70 105.00 2232.17 2133.17 609.925 2401.05E 5959845.55 552294.40 0.00 374.11 3800.00 68.70 105.00 2268.50 2169.50 634.035 2491.04E 5959822.04 552384.55 0.00 389.38 3886.69 68.70 105.00 2300.00 2201.00 654.93S 2569.06E 5959801.65 552462.69 0.00 402.62 5urface Csa 3900.00 68.70 105.00 2304.83 2205.83 658.145 2581.03E 5959798.52 552474.69 0.00 404.65 4000.00 68.70 105.00 2341.16 224216 682.26S 2671.02E 595977501 552564.83 000 41992 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.00 above mean sea level) Vertical 5ection is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8869.10 Feet on azimuth 153.36 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . Cor1oc.Ò'Phillips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 3 Well bore: 126 Well path: 126 Ver#4 Date Printed: 30-Jun-2004 .... ..,. INTEQ .... ... LI.. .....-.'.... ...... ...iL .... ....... .. ....... .... > ... .... i ...... ... ... ....> . ........... ........ IMq[ftl IVI.i!TtJ ...., ., Ëàst{ftl I Static>r'l ...... !=:t"t¡"""· l'1t1nt..n .»i ,. ~, !3".""", ..... . ic ~""""""...,. .. ..... II\I()rìhT EastY. ...... Òftf tl." ............. ........ ..... .......... . ............ i ... 4100.00 68.70 105.00 2377A~ 2278.49 706.378 276102E 5959751.50 552654.97 000 435.19 4200.00 68.70 105.00 2413.82 2314.82 730.48S 2851.01E 5959727.98 552745.11 0.00 450.46 4300.00 68.70 105.00 2450.15 2351.15 754.60S 2941.00E 5959704.47 552835.25 000 465.73 4400.00 68.70 105.00 2486.48 2387.48 778.718 3030.99E 5959680.96 552925.40 0.00 481.00 4500.00 68.70 105.00 252281 2423.81 802.82S 3120.99E 5959657.45 553015.54 0.00 496.27 4600.00 68.70 105.00 2559.14 2460.14 826.948 3210.98E 5959633.93 553105.68 0.00 511.54 -~ 4700.00 68.70 105.00 2595.47 24964L _851.058 3300.97E 5959610.42 553195.82 0.00 526.81 4800.00 68.70 105.00 2631.80 2532.80 875.168 3390.96E 5959586.91 553285.96 0.00 542.08 4900.00 68.70 105.00 2668.13 2569.13 899.288 3480.96E 5959563.39 553376.11 0.00 557.35 4950.66 68.70 105.00 2686.54 2587.54 911.49S 3526.55E 5959551.48 553421.77 0.00 565.08 Turn 4.5/100 3DXS Kick off Point 5000.00 68.42 107.37 2ZP4.58 2605.58 924.298 3570.65E 5959538.98 553<165.95 4.50 573.54 -- 5100.00 67.95 112.19 274176 2642.76 955.688 3657.98E 5959508.17 553553.48 4.50 596.32 5200.00 67.63 117.04 2779.59 2680.59 994.228 3742.12E 5959470.1~ 553937.86 4.50 626.51 5266.56 67.49 .120.2L 2805.00 2706.00 1023.728 3796.09E 5959441.06 553692.03 4.50 650.63 TODU~ 5300.00 67.45 121.90 2817.82 271881 1039.678 3822.54E 5959425.29 553718.58 4.50 663.94 5400.00 67.41 126.78 2856.22 2757.21 1091.73S 3898 76E 5959373.74 553795.14 4.50 708.37 5500.00 67.53 131.65 289455 2795.55 1150.108 3970.30E 5959315.85 55386706 4.50 759.52 5600.00 67.79 136.50 2932.58 2833.58 1214.42S 4036.73E 5959251.98 553933.90 4.50 81709 5700.00 68.19 141.34 2970.08 2871.08 1284.288 4097.62E 5959182.53 553995.25 4.50 880.71 5793.62 68.70 145.83 3004.49 2905.49 1354.338 4149.28E 595911283 554047.37 4.50 945.42 EOC End of Turn 5800.00 68.70 145.83 3006.81 2907.81 1359.25S 4152.63E 5959107.94 554050.75 0.00 949.99 -- 5900.00 68.70 145.83 3043.14 2944.14 1436.348 4204.95E 5959031.21 554103.5L 0.00 1021.64 5906.07 68.70 145.83 3045.34 2946.34 1441.028 4208.12E 5959026.55 554106.78 O. ºlL ,1025.99 8tart 200' PumD Tanaent 6000.00 68.70 145.83 3079.47 2980.47 1513.438 4257.27E 5958954.48 554156.40 0.00 1093.29 6001.47 68.70 145. 8_3... .-3.080.00 298100 1514.568 4258.04E 5958953.35 554157.18 0.00 1094.34 Top UQnu B 6100.00 68.70 145.83_ ~ªº- .3016.80 1590.51S 4309.59E 5958877]4 554209.23 0.00 1164.94 6106.07 68.70 145.83 3118.00 3019.00 1595.19S 4312.77E 5958873.09 554212.44 0.00 1169.29 End 200' Pump Tangent, BldlTrn 4.5/10 f------- -~ ~,- -- End of Hold 6147.44 68.79 147.83 3133.00 3034.00 1627.46S 4333.86E 5958840.96 554233.74 4.50 1199.36 TOD Uanu A 6200.00 68.95 150.36 315195 3052.95 1669.538 4359.04E 595879907 554259.20 4.50 1238.78 6300.00 69.36 155.15 3187.55 3088.55 1752.598 4401.80E 5958716.30 554302.50 4.50 1317.30 6400.00 69.89 159.92 3222.38 3123.38 1839.19S 4437.60E 5958629.95 ~4338ß7 4.50 1400.02 ,.- 6500.00 70.56 164.65 3256.23 3157.23 1928.808 4466.21 E 5958540.54 554368.08 4.50 1486.44 6578.58 71.16 168.34 3282.00 3183.00 2000.978 4483.5.'!Ç ~Þ846e.~ _554385.8-ª-. -.AJ5JJ 1556.59 K-13 6600.00 71.34 169.34 3288.88 3189.88 2020.87S 4487.47E 5958448.62 554389.94 4.50 1576.01 6700.00 72.24 173.98 3320.15 3221.15 2114.838 4501.23E 5958354.77 554404.33 4.50 1668.19 6800.00 73.2L 178.57 3349.82 3250.82 221009S 4507.4Z,.Ç ,-5958259.55 554411.15 4.50 1762.41 -- 6900.00 74.36 183.12 3377. 73 3278.73 2306.098 4505.99E 5958163.56 554410.36 4.50 1858.08 6954.45 75.00 185.57 3392.12 3293.12 2358.458 4502.02E 5958111J.ª-. _554406.73 4.50 1910.58 EOC End of BuildlTurn 7000.00 75.00 185.57 3403.91 3304.91 2402~~ 4497.75E ~58067.37 554402.75 000 1954.58 7054.45 75.00 18557 3418.00 3319.00 2454.588 4492.65E 5958015.00 554398.00 0.00 2007.17 Top West 8ak 0, W8 1 E D5 0 TOP '. RV8D050504 End of Hold 7100.00 75.00 185.57 3429 79 3330.79 2498.37S 4488.38E 5957971.18 554394.02 0.00 2051.17 7133.41 75.00 185.57 3438.44 3339.44 2530.498 4485.25E 5957939.05 554391.11 0.00 2083.44 Bid 3/100 End of Hold 7193.17 76.79 185.5L .MQ3.00 3354.00 2588.18S 4479.63E 595788133 554385.87 3.00 2141.40 C 723.3.41 78.00 185.57 3461.78 3362 78 2627.26S 4475.82E 5957842.23 554382.32 3.00 2180.67 7300.01 80.00 185.57 3474.49 3375.49 2692.328 4469.4 7E 5957777.13 55437§AL 3.00 2246.04 EOC ,--~.- 7300.08 80.00 185.57 3474.50 3375.50 2692.39S 4469.47E 595777706 554376.40 3.00 2246.11 TOD West 8ak B End of Build 7 400~-ºº- ----ªO.OO 185.57 3491.85 3392.85 2790.338 4459.92E 5957679.07 554367.51 0.00 2344.51 7498.76 80.00 185.57 3509.00 3410.00 2887.138 4450.49E 5957582.22 554358.72 0.00 2441.77 A-4 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8869.10 Feet on azimuth 153.36 degrees from Wellhead Calculation rnethod uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ~/ ConocòPhillips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 4 Well bore: 126 Wellpath: 126 Ver#4 Date Printed: 30-Jun-2004 JNTEQ .... ... ,...... -., ....... .... ...... .../ > .............. ..... .. .... ....... .. ... <>i IMD(ftJ IAploeg¡ ,..yÞ{ft Ea.$~ftl <'.~.,. ..... DOOJea vemcal. .. 'i ...... ,Ç''''''''L. 1"'.''''',,0' ...... .... ..... I .... ...>'",,,......, . East) > .... Ótt1'"' tf ..... .> » ......... .......... ...... > 7500.00 80.00 18557 3509.22 3410.22 2888.348 4450.37E 5957581.00 55.4358.61 0.00 2442.99 7600.00 80.00 185.57 3526.58 3427.58 2986.368 4440.81E 5957482.94 554349.70 0.00 254147 7700.00 80.00 185.57 3543.95 3444.95 3084.388 4431.26E 5957384.87 554340.80 0.00 2639.95 7752.14 80.00 185.57 3553.00 345400 3135498 4426.28E 5957333.73 55433616 0.00 2691.31 Ä-3 7800.00 80.00 185.57 3561.31 3462.31 3182.39S 4421.71E 5957286.80 554331.90 0.00 273844 7900.00 80.00 185.57 3~ 3479.68 3280418 4412.15E 5957188.73 554323.00 0.00 2836.92 8000.00 80.00 1aML 3596.04 3497. 04 3378438 4402.60E 5957090.66 554314.10 0.00 293540 ,-, 8100.00 80.00 185.57 3613.41 351440 347644S 4393.05E 5956992.60 554305.20 0.00 3033.88 8120.70 80.00 185.57 3617.00 3518.00 3496.74S 4391.07E 5956972.29 554303.35 0.00 3054.27 TOD West 8ak A2 Int Csa. PI. 8159.80 80.00 185.57 3623.79 3524.79 3535.068 4387.33E 5956933.95 554299.87 000 3092.77 Bid 4/100 End of Hold 8259.80 84.00 185.57 3637.70 3538.70 3633.608 4377.73E 5956835.36 554290.92 4.00 3191.78 8359.80 88.00 185.57 3644.68 3545.68 3732.86S 4368.05E 5956736.04 554281.91 400 3291.51 8420.18 9041 185.57 3645.51 354651 3792.948 4362.20E 5956675.93 55427645 4.00 3351.88 EOC End of Build ~t8 91.17 185.57 3644.13 3545.13 3892468 4352.50E 5956576.36 55426741 0.75 3451.87 8620.18 91.92 185.57 364~ 354245 3991.958 4342.80E 5956476.82 554258.38 0.75 3551.83 8720.18 92.67 185.57 3637.45 353845 409140S 4333.11E 5956377.32 554249.35 0.75 3651.75 8811.11 93.35 185.57 3632.68 3533.68 4181.788 4324.30E 5956286.89 55424114 0.75 3742.56 End of Build 8900.00 93.35 185.57 3627.49 352849 4270.108 4315.69E 5956198.52 554233.12 0.00 3831.30 9000.00 93.35 185.57 3621.65 3522.65 436946S 4306.01E 5956099.11 554224.09 0.00 3931.13 9006.57 93.35 185.57 3621.27 3522.27 4375.998 4305.37E 5956092.58 554223.50 000 3937.68 End of Hold 9106.57 92.60 185.57 3616.09 3517.09 4475.388 4295.68E 5955993.13 55421447 0.75 4037.55 ,- ~57 91.85 185.57 3612.21 3513.21 4574.83S 4285.99E 5955893.63 55420544 0.75 413747 9306.57 91.10 185.57 3609.64 3510.64 ,4674.338 4276.29E 5955794.08 55419641 0.75 423744 9397.50 90.41 185.57 3608.44 350944 4764.828 426747E 5955703.54 554188.19 0.75 4328.36 End of Droo 9497.50 89.66 185.57 3608.37 3509.37 4864.358 4257.77E 5955603.96 554179.15 0.75 442836 -~ 9597.50 88.91 185.57 3609.61 3510.61 4963.878 4248.07E 5955504.39 554170.11 0.75 4528.36 9697.50 88.16 185.57 3612.16 351316 5063.378 4238.37E 5955404.84 554161.07 0.75 4628.32 9731.50 87.91 185.57 3613.32 3514.32 5097.198 4235.07E 5955371.00 55415800 0.75 4662.30 End of Dron 9800.00 87.91 185.57 3615.82 3516.82 5165.328 422843E 5955302.84 554151.82 0.00 4730.75 9900.00 87.91 185.57 3619.47 352047 5264.78S 421874E 5955203.32 554142.78 0.00 4830.69 9987.95 87.91 185.57 3622.67 3523.67 5352.258 4210.21E 595511580 55413484 0.00 4918.58 End of Hold 10087.95 88.66 185.57 3625.67 3526.67 5451.738 4200.52E 5955016.27 554125.80 0.75 5018.53 10187.95 8941 18557 3627.35 3528.35 5551.258 4190.82E 5954916.70 554116.77 0.75 5118.52 10287.95 90.16 185.57 3627.73 3528.73 5650.ns.~1.12E 5954817.12 554107.73 0.75 5218.51 10374.08 90.81 185.57 3627.00 3528.00 5736".Qilli 4172.76E 5954731.35 554099.94 0.75 5304.64 End of Build 10400.00 91.00 185.54 3626.59 3527.59 5762.298 4170.25E 5954705.54 554097.61 075 5330.56 10500.00 91.74 18541 3624.20 3525.21 5861.818 4160.72E 5954605.98 554088.73 0.75 5430.53 ,----~ 10600.00 92.48 185.29 3620.53 3521.53 5961.318 415140E 5954506.43 554080.07 0.75 553046 10700.00 93~~f-185.17 3615.56 3516.56 6060.778 4142.30E 5954406.92 554071.64 0.75 5630.34 10770.36 93.74 185.08 3611.29 3512,29 6130.728 4136.02E 5954336.94 554065.83 0.75 5700.56 End of Build/Turn 10800.00 93.74 185.08 3609.36 3510.36 6160.188 413341E 5954307.47 55406341 0.00 5730.14 10900.00 93.74 185.08 3602.84 3503.84 6259.578 4124.57E 595420802 554055.23 0.00 5829.92 11000.00 93.74 185.08 3596.32 3497.32 6358.97S 4115.73E 5954108.58 554047.06 0.00 5929.71 11066.08 93.74 185.08 3592.01 3493.01 6424.658 4109.90E 5954042.87 554041.65 000 5995.65 End of Hold 11166.08 92.99 185.08 3586.15 3487.15 6524.088 4101.06E 5953943.39 55403348 0.75 609547 ._~ 11266.08 92.24 185.0IL~59 3482.59 6623.598 4092.21E 5953843.84 554025.29 075 6195.36 11354.35 91.58 185.08 3578.65 3479.65 6711468 408440E 5953755.92 554018.07 0.75 6283.58 End of DroD 11454.35 90.83 185.08 3576.55 3477.55 6811.048 4075.55E 5953656.29 554009.88 0.75 6383.55 11554.35 90.08 185.08 3575.77 3476.77 6910.658 4066.69E 5953556.,64 554001.68 0.75 6483.54 11654.35 - 89.33 185.08 3576.29 3477.29 7010.25S 4057.84E 5953456.99 55399349 0.75 6583.54 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8869.10 Feet on azimuth 153.36 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . e ~llips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 5 Well bore: 126 Well path: 126 Ver#4 Date Printed: 30-Jun-2004 ... 'I8.ø INTEQ -.... ..... ... ....... .< .... ..< .... ... .... .... ...... < ....< ...... ..... ........ i/ MDfftT> InC[ôøs} .;" liTVD[ttl IËà$~ftl St~*()n. Stlltíon $t~.i~n ....... .... c·,- ~"".. verncal·..·.··. II\C>rtI)lTt 'Y'".",'" ... 1J"f!'.'I<;>V / ... Northì Bàst\. .... !Qftl .... tl ..... ...... ..... ...... ........ < ..... 11745.28 88.64 185.08 3577.90 3478.90 7100.81S 4049.79E 5953366.39 553986.04 0.75 6674.45 End of-º,"ºº--, -- 11800.00 88.64 185.08 3579.19 3480.19 7155.30S 4044.94E 5953311.87 55398156 0.00 6729.15 11900.00 88.64 185.08 3581.56 3482.56 7254.88S 4036.09E 5953212.2!;1 ~53973.37 0.00 6829.12 11939.71 88.64 185.08 3582.50 3483.50 7294.42S 4032.58E 5953172.69 553970.12 0.00 6868.81 End of Hold 12039.71 89.39 185.08 3584.21 3485.21 7394.01S 4023.72E 5953073.05 553961.93 0.75 6968.79 12139.71 90.14 185.08 358462 3485.62 7493.61S 4014.87E 5952973.40 553953.74 0.75 7068.79 12239.71 90.89 185.08 3583.71 3484.71 7593.22S 4006.01E 5952873.75 553945.54 0.75 7168.78 -.. -- 12330.64 91.58 185.08 3581.75 3482.75 7683.77S 3997.97E 595278315 553938.10 0.75 7259.69 End of Build 12430.64 92.33 185.08 3578.35 3479.35 7783.32S 3989.11 E 595268356 553929.91 0.75 7359.63 12530.64 93.08 185.08 3573.63 3474.63 7882.82S 3980.27E 5952584.02 553921.73 0.75 7459.51 1257588 93.42 185.08 3571.07 3472.07 7927.81S 3976.27E 595253900 553918.03 0.75 7504.68 TD, 5 1/2 Liner Pt., 5 1/2in Liner, End of . Build I All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8869.10 Feet on azimuth 153.36 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated OR\G\NAL . . ConocÒPhillips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 6 Wellbore: 126 Wellpath: 126 Ver#4 Date Printed: 30-Jun-2004 ... awl. INTEQ -......... .< .... ...... ... ....... .... ......... ......... ...... > >i .. ../ » ...... >< > ...>. ....... ..... MÓrftÎ ... tvnrftl I¡::::is::tfffl .... .. .... ...... .... <. .......... ...... > > .... 300.00 300.00 O.OOE O.OON KOP 585.71 584.27 24.77E 2.178 Bldrrrn 4/100 837.57 827.24 89.14E 11.588 Bldrrrn 5/100 -- 1146.58 1100.00 229.52E 39.998 Bldrrrn 3/100 1405.16 1300.00 38902E 76.328 Bldrrrn 5/100 1746.64 1511.00 648.00E 140.818 Base Permafrost 1916.89 1584.37 796.38E 179.95S EOC 2356.28 1744.00 1191.79E 285.908 TOQ T-3 3223 33 2059.00 1972.08E 494.978 Too K-15 3886.69 2300.00 2569.06E 654.938 8l!rface Csq 4950.66 2686.54 3526.55E 911.498 Turn 4.5/100 ~266.56, 2805.00 3796.09E _~.72~ .lQQj,)Qn u C 5793.62 3004.49 4149.28E 1354.338 EOC 5906.07 3045.34 4208.12E 1441.028 8tart 200' Pump Tanqent 6001.47 3080.00 4258.04E 1514.568 Top Uqnu B 1--' 6106.07 311800 4312.77E 1595.198 End 200' Pump Tanqent Bldrrrn 4.5/100 6147.44 3133.00 4333.86E 1627.468 Ton Uonu A 6578.58 3282.00 4483.54E 2000.978 K-13 6954.45 3392.12 4502.02E 2358.45S EOC 7054.45 3418.00 4492.65E 2454.588 Top West 8ak D .-- 7133.41 3438.44 4485.25E 2530.49S Bid 3/100 7193.17 3453.00 447963E 2588.188 C 7300.01 3474.49 4469.47E 2692.32S EOC -- 7300.08 3474.50 4469.47E 2692.398 Too West 8ak B 7498.76 3509.00 4450.49E 2887.13S A-4 7752.14 3553.00 4426.28E 3135.498 A-3 8120.70 3617.00 4391.07E 3496.748 Top West 8ak A2 Int CSq. Pt. 8159.80 3623.79 4387.33E 3535.06S Bid 4/100 8420.18 - 3645.51 4362.20E 3792.948 EOC c......12~75.88 3571. 07 3976.2Z£_,_ -- 7927.818 TD 5 1/2 Liner Pt. 13 3/8in Casin 9 518in Casin 5 1/2in LineL........ 5 1/2in Liner 5 1/2in Liner All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8869.10 Feet on azimuth 153.36 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated RIGINAL . . C~ill.ips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 7 Wellbore: 126 Well path: 126 Ver#4 Date Printed: 30-Jun-2004 ... .... INTEQ WS 1 E 05 0 TOP 2454.58S 4492.65E 3418.00 N70 17 45.5482 W149 33 34.2752 554398.00 5958015.00 RVS0050504 WS 1E 05 A2 TOE 7927.81S 397624E 3575.00 N70 16 51.7222 W149 33 49.4111 553918.00 5952539.00 RVS0060704 WS 1 E 05 5097.19S 4235.07E 3636.00 N70 17 19.5598 W149 33 41.8262 55415800 5955371.00 A2-MOPT#2 RVSD050504 WS 1 E 05 6371.56S 4116.60E 3618.00 N70 17 7.0271 W149 33 45.2985 554048.00 5954096.00 A2-MOPT#3 RVS0050504 Planned ISCWSA MWD 647616 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig ( Oatum #1 99.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8869.10 Feet on azimuth 153.36 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL · e Conoc~illips ConocoPhillips Alaska, Inc. 126 Ver#4, 126 Slot #126, Pad 1 E CLEARANCE LISTING Page 1 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska B.. BAKER HUGHES INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertaintv data Only Depth and Maqnetic Reference Field error terms are correlated across tie points Proximities beyond ft with expansion rate of ft/1 OOOft are not reported Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/Casinqs are NOT included Hole size/Casinqs are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.58standard deviations. Closinq Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation IWeUbc>rè ~~ I~I 126 I ~~~~~t004 I ~~ Rev~d · un-2 4 I Govemment ID I Last Revised 4-Feb-2004 r mNm N AK-4 on NORTH AMERICAN DATUM 1927 datum True Clearance. SUmmarv .. Offset Offset Offset Offset Minimum MD[ft] Diverging Ellipse Ellipse Clearance WellName Wellbore Slot Structure Distance From[ft] Separation MD[ft] Factor MD[ft] Iftl Ilftl 168 168 D-Lateral Slot #168 Pad 1E 349.7 7054.4 7054.4 1ñR 11ñR R-I P",rl1F ~4q 7~ 70ii4 4 70!'i44! 168 168 Slot #168 Pad 1E 349.7 7054.4 7054.4 A2-Lateral 112 112L 1 ISlnt #112 P",rl1E Q7!'i.1 70!14.4 70M.4 112 112 1<::1", #112 Pad 1E 97!1.1 7054.4 70544 112 112L2 Slot #112 Pad 1E 975.1 7054.4 7054.4 2? 22 1"'#22 Pad 1E 101 ñ. 7 7969.01 79690( 10!1 10!'i D-L""Ar",1 1<::1", #10!'i P",rl1F 1116.2 70544 7054.4 105 105 B-Lateral Slot #105 Pad 1E 1120.9 7054.4 7054.4 105 105 Slot #1 05 Pad 1E 1153.4 7054.4 7054.4 A2-1 ;o¡tAr;o¡1 33 33 slot #33 Pad 1E 1224.2 7054.4 7054.4 ::\::\PR1 1::\::\ PR1 P",rl1F 1 ??4 ?~ 70!'i44 70!'i44! All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.00 above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of99.01 (10) oeR1 tJiN~sr~orporated . . Conoc6Phillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 2 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska .i. BAKER HUGHES INTEQ Reference Well bore ·Surve Planned All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) crt< rGTfJÄI[rporated . . Conoc6'Phillips ConocoPhillips Alaska, Inc. 126 Ver#4 ,126 Slot #126, Pad 1E CLEARANCE LISTING Page 3 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska B.. BAKER HUGHES INTEQ Clearance.Data Reference Reference Reference Reference Offset Well Offset Offset Offs et Offset Angle Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation . Highside Distance [ft] Irdèal. Hll 7054.4 3418.0C 2454.58 4492.65E 168 6501.9 3288.3 2308.18~ 4202.63 72.E 349.7 71000( ~429.7~ 2498.37 4488.381 168 6478.0: 3280.4. ?3?Ç.38~ 41M.ÇÇE 70 37001 71 ~~.4 ~4~R.4 """" A'" 4485.25E 168 64582 3273.7 234679~ 4188.32 69.~ ~Rñ 0' 7200.0 3454.5! 2594.79 4478.98E 168 6419.5 3260.4 2380.36~ 4174.45 65.~ 419.9 7?~~.4 ~ñ1 7~ 2627 .26~ 447582E 168 6400.01 325361 23Ç7.0Ç~ 4167.02E 63.E 437.7 730001 ~74.4Ç ?RA2.~1 44ñA.4RF 1ñR 6360.01 3239.4 2430.84~ 41 '\0 A1 ñO.¡: 474.4 7300.0 3474.5C 2692.39 4469.47E 168 6360.0 3239.4 2430.84~ 4150.91 60.E 474.4 740001 34A1.R~ 27AO.~~~ 44'\A.A?F 1ñR 6300.9: 3217.9~ 2479.37~ 412'\.001 '\R.F '\~2.R~ 7500.01 3509.2 28RR34 4450.37F 1RR R2'\1.A ~1AA.R: ?'\1 R ?A~ 4101.R~1 '\7'J ,\Ç5.2 7600.0 3526.5 2986.36 4440.81 E 168 6200.0 3179.8 2558.34' 4075.061 56.C 661.2( 770001 3543Ç! ;[;[<),1 ?~~ 1RR ñ1'\A '\~ ~1ñ4 ?: ""00 A"" 40'\~ 101 ,\,\'J 7~0 1! 7ROO.01 ~'\ñ1.~· 3182.39~ 4421.71 E 168 61146~ 3146.5! 2620.1\1 4027.461 541' 801.7 7900.0 3578.6 3280.41 4412.15E 168 6074.0 3130.4 2649.06 4003.18E 54.1 875.6 8000.01 3596ûc 337843~ 4402.60F 168 RO~7 A, ~11'\.A! 2R7~.~R~ ~ARO.731 531' Ç51ô' R10001 ~ñ1 ~ 4r <),,,.,.'" A. 4~Q~ O'\F 168 6000 D( 31005! ?~QA O?' ~Q,\~ ~?I 53." 1 O?Q ~( 8159.8 3623.7 3535.06 4387.33E 168 5980.0 3092.4 2710.63 3943.11E 53.4 1076.7 R?OO.OI ~ñ~O.?· 3574.55~ 4383.48E 168 5Ç62.2 3085.1 2721.62 3931.15E 5H 1108.61 825Ç81 3637.7 4~77.7~F 1ñR 5942.8' 3077.2 2733.37 ~A17.A?1 4A.:< 11'\'\.R, 8300.0 3641.3 3673.44 4373.85E 168 5935.9 3074.4 2737.46 3913.19E 47.E 1187.3 835Ç.RI 3R44 RI ~7~2.Rñ~ 4~ñR.0'\F 168 5917.3: 3066.7 2748.42 3900.23E 45.E 1 ?~~ ñ 8400.01 36455: 3772.RR~ 4~R4.1'\F 1RR '\Aoo.or ~O'\A ñ' 27'\R.42 ~RRR.011 44.F 1?R4 '\! 8420.1 3645.5 3792.94 4362.20E 168 5898.7 3059.1 2759.11 3887.14E 44.C 1279.9 OffSé · WellboreSurve Well Well bore 168 168 D-Lateral ErrorModel MWD+SAG - ISCWSA - 28 Ja H All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.00 above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) PoaR bf tiel r,!~ðl.,n[Porated . . conoc~illips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1 E CLEARANCE LISTING Page 4 Date Printed: 1·Jul-2004 Kuparuk River Unit, North Slope, Alaska 8i. BAKER HUGHES INTEQ Clearance Data Reference Referehce Reference Reference Offset Well Offset Offset Offset Offset Angle Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Distance [ft] I In;;;,,! rm 7054.4 3418.0 2454.58 4492.65 168 6501.9 3288.3 2308.18 4202.631 72.f 349.7 7100.01 3429.7 24~R37' 4488.3RI 1ôR R47RO ??AI1 LL 2?2Q:~A( 41Q4.QQ¡ 711. ?'70.0f 71?,?,.4 <\4?'R.4, ?!'i?'04Q! 44A!'i2!'i1 1RA F;4&;A? ?'?7?'.7 2?,4R 7Q~ 41AA.?'21 R~. ~Ô.O! 7200.0 3454.5 2594.79 4478.98 168 6419.5 3260.4 2380.36 4174.45F 65.! 419.91 7??,?,.4 ?,4R171 2627 26~ 447&;.A2 1RA R4nl1.111 ?'?!'i?' F;, 2?'Q7.I1Q~ 41F;7.0?1 R?'} 4?'7.71 T\OO.OI <\474.4! ?ô~??'1 44R~.4AI 1RR R?,F;O.OI ?,nQ.4 24?'0.A4~ ~ f¡11.i 47.11.11. 7300.0 3474.5 2692.39 4469.47 168 6360.0 3239.4 2430.84 4150.911 60.1 474.41 7400.01 <\4~1.R! ?7QO 3?,! 44&;~.~2 1RR R?,OO Q: ?'?17.Q 247~.?'7~ ..,.,,, tV" £;A.I ~?A' 7500.01 3509.2: 28RR.34' 44!'i037 1ôR R?!'i1.~ 31~~.F;, ?1;1A.2ãC 4.¡n1 F;?'J &;7. &;Q&;.2! 7600.0 3526.5 2986.36 4440.81 168 6200.0 3179.8 2558.34 4075.06f 56.( 661.2( 770001 3!'i43~! '>"0 '>0' .IIA?1 ?¡:;I 1RR R1!'i~ &;~ ?,1R4 ?: nrnn .n' ~.¡;:;¡ &;&; , 7?111! 780001 3561.3' 31R?39~ 4421.71 F 1ôR ô114.R~ ~14F;.I;' 21';211.A1 41127 4m M.I R01.7 7900.0 3578.6 3280.41 4412.15E 168 6074.0 3130.4 2649.06 4003.18¡ 54.1 875.61 ROOO.OI 3596.0- 337R.43~ 440?ôOF 1ôR R037.~ 311!)~~' 2ô7?'~( , ?'QAn.7?' &;?,} Q&; 1 .6' A10001 ?,R1?, 41 .~n A,>a,> ""t 1F;R F;11,)11111 ?11111 &;, ,>a"" ,>'H ,,?' 1(),)Q ,>c 8159.8 3623.7! 3535.06 4387.33E 168 5980.0 3092.4 2710.63 3943.11 53. 1076.7 A?OO nl ?,R30 ?1 3574.55~ 4?'R?'.4A~ 1F;R :;;M2.2 ?,I1A&; 1: 27?1.F;?! ?,Q?'1.1&;¡ &;1 f 110R.RI R?!'i~.RI 3ô37 7( 4?,77 .7?'~ 1RR !'iQ.ll? .A· ?'077.? 2733.37 ~17!:J2 4Q 11-';i;~A. 8300.0 3641.3< 3673.44 4373.85E 168 5935.9 3074.4 2737.46 3913.191 47.E 1187.3 R3!'i~Rr 3R44 Ri 3732.RR! 4?'RR.0&;~ 1RR &;Q17.?': ?,ORR 71 274R.42 41;f 12??.¡:;: Moo.or 3645.5: 377? .RR~ 43R4.1 !'iF 1RR !'iQOO.OI 305~.R· 275R42 ~ 44.F 1?F;4.5! 8420.1 3645.5 3792.94 4362.201 168 5898.7 3059.1 2759.11 3887.14 44/ 1279.9 OffSèfWellbore Survev ToolProarams Well Wellbore Survev Name MDfftl Survey Tool Error Model 168 168 B-Lateral Planned 1 1591 .2 ISCWSA MWD MWD+SAG - ISCWSA - 28 Jan 03 OIH All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) oeRe1 bTNJ~rr:orporated . . Conoc<>Phillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 5 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska '&1. BAKER HUGHES INTEQ Clearan,ce Data '., Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Distance [ft] 'IrlAol Iftl 7054.4 3418.0C 2454.58 4492.65E 168 6501.9 3288.3¡ 2308.18~ 4202.631 72Æ 349.7 710001 ::\4?Ç.7~ ?4ÇR,:W 44RR ::\RÇ 1 fiR 6478.0: 3280.4 2::\?Ç.::\R~ 41Ç4.ÇÇ1 71'1. ::\7nnf 7133.4 34384~ 25::\04Ç~ 44R5.?5Ç 1 fiR fi45R.?· ::\27:'\.7 2::\4f'>.7Ç~ 41RR,::\21 6Ç. ::\86D! 7200.0 3454.5< 2594.79 4478.98E 168 6419.5 3260.4 2380.36( 4174.451 65.<; 419.9 72334 3461.7 4475.8?1 1 fiR Mon Ot ::\25::\.fil nç7.nç~ 4167.0?1 6:U 437.71 7::\1'11'1.1'11 ::1474.4 2692.31 4469.48E 168 6::\60.0( ::\23Ç.4 2430.84~ 4150.91 60J 474.4 7300.0 3474.5 2692.39 4469.47E 168 6360.0 3239.4 2430.84 4150.91E 60.t 474.41 741'11'1.1'11 ::\4Ç1.8! 2790.33~ 4459.92E 168 6::\00ç¡: ::\217.9: 2479.37 4125.0OE 58.f 532æ 751'10.1'11 ::\5nç.?: ?RRR.::\4 44<;1'1 ::\71 1 fiR 625191 3199.61 2518.29~ 4101.631 57. <;ç<; ?~ 7600.0 3526.5 2986.36 4440.81E 168 6200.0 3179.8 2558.34 4075.06 56.( 661.2( 771'11'1 I'll ::\<;4::\ Q' ""n "n, 44':\1 ?fil 168 61595~ ::\164.2: ""nn ,m 41'1<;':\ 101 <;<; 7':\1'1 l' 7800.01 ::\561.::\' ::\18?::\Ç~ 44?1.71 I 1 fiR fi114.fi~ ':\14fi.<;! ?fi2n R1 4n?7.4fil 54.f R01.7 7900.0 3578.6 3280.41 4412.15E 168 6074.0 3130.4 2649.06 4003.181 54.1 875.6 801'10.01 ::\59fi 0, '\::\7R4':\! 44n2.fiOl 1 fiR 6037.9' 3115.9: 2673.38~ ,:\QRn.7':\1 <;::\} Q<;1.fi' R11'1n I'll 36134( "'7~ , Ll,:\Q'>. I'Iq 1fi8 finnn nr ::\11'11'1 <;! '>.Q<;I; ':\?~ 5::\~ 11'129::\1 8159.8 3623.7 3535.06 4387.33E 168 5980.0 3092.4 2710.63 3943.111 53. 1076.7 8200.01 36302' ::\57455: 4::\8::\.481 1 fiR <;Qfi2.?' ':\nR51 ?721.fi2 ::\q::\1 151 51.f 111'18.61 R2<;q.RI 3637.7 4377.73E 168 5M? .8' ::\1'177 ?: 273::\.::\7 ::\91792 49. 1155.8< 8300.0 3641.3 3673.44 4373.85E 168 5935.9 30744 2737.46 3913.19E 4H 1187.3 R,:\<;q.RI 3644.61 3732.86: 4::\68.05E 168 5917.::\: ::\1'166.7 27 48.4?~ ,:\QI'II'I ?':\~ 45.1 1233.61 MnQ.nl ::\M5 5: ':\77?Rfi: 4364.15E 168 59000( 3059.6 2758.42 3888.01E 44.f 1?fi4 <;! 8420.1 3645.5 3792.94 4362.20E 168 5898.7 3059.1 2759.11 3887.14E 44.( 1279.9 set Well bore Surve Well Well bore 168 168 A2-Lateral MDftl SUrve Tool 11606.2 ISCWSAMWD Error Model MWD+SAG - ISCWSA - 28 Ja H All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) O~drGT~~~ trporated . . Conoc6Phillips ConocoPhi/lips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 6 Date Printed: 1·Jul-2004 Kuparuk River Unit, North Slope, Alaska .¡. BAKER HUGHES INTEQ ClearanêèData Reference Reference Reference Reference Offsét Well Offsét Offset Offset Offset Anglé Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From A.pproach Separation Highsidé Distance [ft] 1 [('1I;'n] 11ft] 7054.4 3418.0C 2454.58< 4492.65£ 112 5820.1 3406.7 2347.02 3523.47 89.E 975.1 7100.0t ~4?q.7' ?498.37~ 4488.38£ 112 5R64.4 3411.4 2390.82~ 3518.551 89. 975.9' 7133.4 343R.4 ?!=;~O.4q~ 44R!ï.2!ïF 11? 5897.0: 3413.7( 2423.13~ 3514.q~1 RR.f q7R,!';f 7200.0 3454.5~ 2594.79 4478.98£ 112 5960.0 3414.9 2485.69~ 3507.90 8H 978.0C 7?~3.4 34R1.71 ?R?7.?R! 447!ï.R?F 112 5991.4 3414.5( 2516.88~ ~<;04 ~ql R7.~ q7R.R~ 7300.0( 3474.4, 2R9?~1 44R94RF 11? RO<;!ï.2 ~12.~· 2<;RO}~0~ ~4q7.?71 RRJ qRO.R" 7300.0 3474.5C 2692.39 4469.47E 112 6055.3 3412.3 2580.38< 3497.26 86.E 980.6 7400.0( 3491 81 2790~31 44!=;Ç.92F 11? R1!ï? RI ~407.Ç1 ?R77 ?O~ ~4RR.~Rf R!ï ÇR~R~ 7!ï000( ~!ïOq.?~ 2888.34 4450.37£ '112 6252.41 34m.7 277611~ 3475.261 841 9871 7600.0 3526.51 2986.36 4440.81 £ 112 6354.6 3403.2 2877.59~ 3463.86 83.1 990.6 7700 Of ~<;<1~ Q' <\I1R<1 <\R' <1<1<\1 ?~~ 112 R4!=;~ ?, ~404 0: ?Q7&; &;7< <\<1&;? A~F R2 9943, 78000( ~!=;R1.~1 ~182.~q! 4421.71£ 112 65518! 3404.8: 3073.56~ 3441.84 8P 998.2 7900.0 3578.61 3280.41 4412.15£ 112 6650.4 3405.6 3171.55~ 3430.84 80.2 1002.3 ROOO.Of ~<;qR OL 3378.431 4402.6OE 112 6744 4 ~40!=;8( 3?64 Ç6~ 3420.34 794 10069: 81000( 3R1 ~ 4f ')A7" A. A~a~ ('I&;~ 11? RR<11 <;/ <\<10~ 7: ~<\R1 ~7~ 7R 101? ?I 8159.8 3623.7, 3535.06 4387.33£ 112 6900.1 3402.4 3419.63 3402.97 77.é 1015.5 R?OO.O( ~R~0.?1 ~!=;74.<;!=;! 4~R~.4RF 112 6939.6~ 3401.51 3458.90~ ~~qR.<;RF 77.~ 1017.7 8259.81 36~7.7( '>,,'>'> ,,('I' 4~77.7~F 11? Rqq8.8· ~400.?1 ~!=;17.RR~ ~~q1.qRF 7R. 10?0.!=;1 8300.0 3641.3.1 3673.44 4373.85£ 112 7038.7 3399.4 3557.34< 3387.51 764 1022.1 835Ç.81 3644.61 ~7::\? .86! 4::\R8.0!ïF 11? 70q8.~' ~~q8.1( ~R1 R.!=;R~ ~~RO.8RI 7R.1 10?4.1 R400.01 3645.5~ 3772.861 4364 15F 112 7n8.5· ::\~Ç7.2 ::\R56.46~ ::\::\76.::\81 76.C 1025.1 8420.1 3645.5 3792.94 4362.201 112 7158.6 3396.7 3676.49~ 3374.13 76.C 1025.5 R<;OO.O( 3644.5~ 3872.381 4354.45F 112 72~8.4 ::\::\Ç5.O: ::\755.79! ~~N- ~~, 75.~ 1026.8: 8520.1 ~R44 1 ~Rq2 .461 4352.501 112 7258.6~ 33Ç4.5i 3775.83! 3362.97 75.9 1027 1 8600.0 3642.m 3971 .88 4344.76£ 112 7338.4 3392.8 3855.13 3354.07 75.9 1028.2 RR20.1 3641 4 3991.951 434280F 11? 7::\586! ::\::\Ç2.::\! ~875.17 3351.82F 76.C 1028.4 870001 ~R~R ~I 4071 ~4! A~~&; ('I~~ 11? 7438.4/ 33Ç06. "roc:. A'" ~~A,) a1 7Rr 10?q?" 8720.1 3637.4 4091.40 4333.11 £ 112 7458.6 3390.2 3974.49 3340.66 76.1 1029.4- 8800 01 ~R~~.~: 4170.74 432537E 112 75::\8.4 3::\88.4 4053.76! ::\331.761 76. 1030.0' 8811 1 ::\6::\?RI 4181.7R! 4~?4.~OF 11? 7549.5' 3388.2 4064.79~ <\~~o !=;2F 7R 'J 1 mo O~ 8900.0 3627.4 4270.10 4315.69£ 112 7638.3 3386.2 4153.03~ 3320.61£ 764 1030.5 Ç00001 ::\621.6! 4~Rq 4R! 4~OR 01F 11? 7738.2! 3384.0' 4?!=;2 ~1~ ~~Oq.4RF 7R.F 1m11 9006.5' 3621.2~ 4::\75.Çql 4::\05.::\7F 112 7744.R· ~~R~ q: 4?!=;R.R::\~ ~::\OR7::\F 76 1m11 9100.0 3616.3 4468.85 4296.32£ 112 7838.1 3381.8 4351.60~ 3298.31£ 76.8 1031.8 9106.5' 3616.0! 4475.3R: 4?q!=; 6RF 11? 7R44.7 ~~R1.7 4~!=;R.1 ?! ~2q7.!=;RF 76,F 10~ 1 q: q?OO.OI 3612.4 4568.30~ 4286.62E 11? 7Ç38.1 337Ç.R! 4450.Ç3! 3287.161 77,( 1032.9( 9206.5 3612.2 4574.83 4285.99E 112 7944.7 3379.5< 4457.45 3286.43E 77.( 1032.9 Q'>,1111 01 3609.7~ 4hh { n·t: Ll ?7~ Q<\~ 11? RO'>,81. ~~77 !=;I Ll&;<;11 ?~, ~?7R OOF 77C 1m4?: q'>,OR!=;' <\ROq R< 4276.29E 112 8044.7: 3~77~! <1<;<;~7Q' ~27527E 77( 111<\4 <\: 9397.5 3608.4 4764.82 4267.47E 112 8135.6 3375.3 4647.12 3265.13E 77( 1035.8 9400.01 3608.4 476731 4267.23E 112 8B81. ~~75.~· 4R4Ç.RO! <\?MA<;~ 77C 10358, q4q7.51 '>,ROR ~ ~ 4RR4.~<;! 4257.77E 112 82350' 33731 4746.44~ 3253.97E 76., 10377 9500.0 3608.3 4866.84 4257.53£ 112 8238.1 3373.1 4748.92 3253.69 76'> 1037.7 q!=;q7 !ïl ~ROq R' 4963.87 4248.07 112 8335.5' 3370.Ç1 4845.72: 3242.82E 76.~ 1039.9' qROO.OI ~ROq Rf 4qRR ~R! 4?47.R~1 112 8338.0: 3370.9: 4848.2m 3242.55£ 7R,F 1 O~q q~ 9697.5 3612.1 5063.37 4238.37 112 8435.4 3368.7 4944.95 3231.68E 76.~ 1042.4 Ç700.01 ~61? ?, 4nR.nl 112 8437.9' 3368.7 4947.43~ ~n1 40F 7R F 104? !ït 9731.51 3613.3: 50q7.1Ç1 4n!=;.07F 11? R4Rq.~! ~~RR. 0: 4q7R.R7 ~?27.8qF 76F 1043.3~ 9800.0 3615.8 5165.32 4228.43E 112 8537.7 3366.5 5046.60 3220.26E 76. 1045.2 ÇÇ0001 361 Ç 4~ !=;?R4 7R~ Ll?1 A 7Ll~ 11? RR~7 !=;I ~~R4 ~I ~?Oq nF 7R ( 104R1' qql:q q: ~R??R~ 5352.251 4210.21 E 112 8723.1 3362.4 5230.76~ 3199.56E 75. 1 050.6~ 10000.0 3623.1 5364.24 4209.04E 112 8735.1 3362.0 5242.71 3198.21£ 75. 1051.0 10087.9 36256j 5451 73~ 4?00.52E 11? R8?2 Ç: 335q 7 31 RR.32E 75. 1053.6( All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) PorRlt;l~~~rorated . . Conoc6Phillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1 E CLEARANCE LISTING Page 7 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska .¡. BAKER HUGHES INTEQ Clèaranœ Data ," ,,' .. .,' , Reference Reference Reference Reference Offset Well Offset Offset Offset OffSèt Anglè Closest EllipSe MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Distance [ft] I Ideal Ilftl 10100.0 3625.9 5463.73 4199.35! 112 8834.9 3359.4 5341.88 3186.97 75. 1053.9 1 f11 R7.Ç) ::\fi?7.::\! 5551.25~ 41Ç)0.R2F 112 RÇ)22.R: ::\::\57.1 542Ç) 14 ::\177.071 75.~ 1051'1.2 1f12f1f1.f1 '>,R?74' 55fi::\.24 41AÇ).fi5E 112 R~.AI ::\::\5fi.A 544111 ::\175.721 75. 1051'1.5' 10287.9 3627.7 5650.77 4181.12! 112 9022.7 3354.4 5528.42 3165.821 75.( 1058.5 1 m;:m: f1 '>,R?7R, 5fifi2.77 417Ç)5J51 11? Qf1'>.LlR ::\::\54.1 554038: ::\1fi4.4fil 75.( 105R.7 1m74.f1 '>,ñ27 01 4172.761 112 Q1f1RF '>,'>,52.2 5ñ1'>,.Ç)5! 3156.131 75.( 10fiO.?: 10400.0 3626.5 5762.29 4170.25 112 9134.7 3351.5 5639.69 3153.211 75.( 1060.7 105nf1.f1 '>,ñ?4 ?, 58fi1 .81 ~ 4160.72 112 Q?~.7 '>,'>,4R.R' 57'>,Q OO! 3141.951 74.¡ 10fi?,4. 10fiOO.0 ::\fi20 .5: 5Ç)ñ1.::\1 4151.401 112 Ç)'>,'>.4.7 ::\'>.4ñ.2 '>. 1'>,0. RÇ)I 75.c 1 f1ñi f11 10700.0 3615.5 6060.77' 4142.30 112 9434.6 3343.6 5937.58 3119.441 75.1 1065.5 1077n '>,1 '>.R11 ?~ Ç)5()4 QI '>,'>,417' ~~~- '>,111 5?F 75 1f1¡:;¡:; <;' 1 f1RM f11 3609.::\f R1 fiO 1 A~ 41::1'>. 41F 11? Ç)5'>.4.RI ::\::\40 Ç)~ RO'>.R.82' ::\10R19E 75 1 f1ñR- Q' 10900.0 3602.8 6259.57~ 4124.57E 112 9634.5 3338.3 6136.04~ 3096.94E 75Æ 1068.2 11 f1nn:01 ::\59fi.::\~ R'>.5R.Ç)7' 4115.7'>.F 11? Ç)7'>,4.'>,' '>.'>.'>.5.ñ~ R2'>.5.?7~ '>.OA5. RÇ)F 75.F 1 f1¡:;Q~ñ' 11f1¡:;¡:; f1' '>,5Q? f1' ,,>A '> A ":c,, QRN1.11' ::\::\::\::\Ç)! ?,f17R ?ñF 76( 1 f17n ñ 11100.0 3589.8 6458.37~ 4106.9m 112 9834.2 3333.0 6334.5m 3074.441 76.( 1071.1 111¡:;¡:; f1: 358fi.1 R5?40A~ 41010fiF 11? 9Ç)00.'>.: ::\::\::\1.'>.' fi400.09~ ::\Ofi7.01F 7fi 10n 1 11 ?f1f1 (1¡ '>,5R4.4 fi557.83~ 2 QQ'>.Ll.?: 3330.4: fi4::\::\.76~ 3063,19E 76. 10n 7 11266.0 3581.5~ 6623.59 4092.21 ! 112 1 0000.2 3328.6 6499.37 3055.75 76.< 1074.0 11::1f1f1 f1 '>,5RO.'>" fifi57 .35~ 40A9.21E 112 1f1~1 '>,'>,?7.7 3051.931 76. 1074.7 11'>,54.'>, '>.57A R' ñ711.4ñ~ 4084.4m 112 1 Of1RR.5' '>,'>,2ñ.?'; ñ5R7 01 ~ '>,045.R?1 7R. 1076.0 11400.0 3577.5 6756.92 4080.361 112 10134.1 3325.1 6632.35' 3040.68 76.~ 1077.1 11454.'>, '>.57R 5' ñR11.04 4075.55E1112 101 RR.4 '>,'>.2'>..7 ññRñ.'>.1~ '>,m4.5RI 7R. 1078.4 11 "f1(\0 ::\57fi.0: RA5R51 4071.51 F 112 10?'>.4.1 ::\::\22.5, R7'>.1.fì.4: ::\02Ç),4?1 76. 1f17Ç) 7 11554.3 3575.7 6910.65 4066.691 112 10288.4 3321.0 6785.59 3023.301 76.~ 1081.2 11¡:;Mf1 ::\575.A. ñÇ)5ñ 12 4nñ2.R5F 11? 10'>,'>.4.0J '>.'>.1Ç) R¡ ñR'>.0.Ç)1 '>.01 A 171 7fi~ 1f1R? ¡:;, 11ñ<;.II ?, '>,"7ñ ?, 7f11 f1 ?<;, ::\::\1R4' ~~~ ,., A< 76.:: 1f1R4 '>,1 11700.0 3576.9 7055.72 4053.801 112 10433.9 3317.2 6930.14 3006.921 76. 1085.9 1174<; ? '>,"77.91 7100.A1 404Ç).79F 11? 1047Ç).1' ::\::\1fi.0 RÇ)75.05: ?,f1f11 R?,I 7fi 10R7 4 11Rf1f1 f1 '>,57Ç).1 7155.30~ 4044.941 112 1f1<;?,?, RI '>,'>,14.<; 7029.32 2995681 76.( 10AÇ) 4 11900.0 3581.5 7254.88 4036.09 112 10633.6 3311.9 7128.49 2984.431 75.1 1093.0 11Ç)'>,Q.7 '>.5R2."1 7?94.42' 40'>.2.581 112 10fi7::\.2 ::\::\10.Ç)¡ 71fi7.87 2979.971 75. 1 0Ç)4.4 12nno.0 '>.5R'>,.ñ! 7354 .46~ 4027.24 112 1f17'>,?'." '>,'>,0Ç).'>, 7??7 ñR! 2973.191 75.! 1 0Ç)6.5: 12039.7 3584.2 7394.01 4023.72 112 10773.1 3308.2 7267.08 2968.721 75.! 1097.8 121f1f1.f1 '>,5R4.ñ' 7454.07~ 4018.391 112 1 f1R?,?,.4 '>,'>,nñ.¡:; 7'>,?ñ.Ç)2 2961.94 75.' 10Ç)Ç).7 1?1'>,Ç).7 ::\5A4.R~ 74Ç)'>.R1~ 4n14.A71 111? 10R7'>,.0' '>.'>.05 ñ: 7'>,ññ.'>.::\~ 2Ç)5747F 75 < 11 nn Q' 12200.0 3584.2 7553.67' 4009.531 112 10933.3 3304.0 7426.19' 2950.68E 75. 1102.6 1??'>,Ç) 7 '>.5A'>. 71 7<;0'> ')'), 4nf1ñ f111 111? '^~-~ '>,'>,n? Q( 7A"'<; "'1 75 11n?'-71 ?,<;R? <;< 7"'<;?' ?¡:;, .IInf1f1¡:;RF 111? 11n,>,> '>' '>.'>.01 '>.~ 7<;?<;.IIR' ~,.,^,., '^' 75~ 11f1" ? 12330.& 3581.7 7683.77~ 3997.97E 112 11063.9 3300.5 7555.91~ 2935.98E 75. 1105.9 1?4f1f1.nl ::\579.5' 7752.A2~ '>,Ç)Ç)1.A'>.F 11? 111'>,'>, ?' '>.?Ç)R7 7R24.7A~ ?Ç)?A 17F 75 < 1107 <;' 1?4?,f1.¡:; '>,"7R '>,1 778::\.::\2 '>.Ç)AÇ).11F 112 111 ¡:;?'.Q' ::\2Ç)7.Ç)! 7R55.2m ?Ç)?4.72 75.: 110R.1 12500.0 3575.2 7852.34 3982.981 112 11199.7 3297.0( 7690.77~ 2920.69 75. 1109.9 12,,?'n.¡:; 357::\.6' 7AA? .8?: '>.Ç)AO.27F 11? 111 Ç)Ç).7 ::\2Ç)7.0( 76Ç)0 77' 2Ç)20.fiÇ)1 75. 1111 R 1257".R '>,571.f1' 792781 ::\97fi.27E 112 11HJÇ).7 3297.0( 7690.77~ 2920.691 75. 1111'10. 112 r 112L2 Offset Well bore Surve All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MO's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ORIGINAL . . Conoc6Phillips ConocoPhillips Alaska, Inc. 126 Ver#4 ,126 Slot #126, Pad 1 E CLEARANCE LISTING Page 8 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) (JaR r GI f~rÃn[POrated lB.. BAKER HUGHES INTEQ . . conoc6Phillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 9 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska .¡. BAKER MUGHU INTEQ ClearanCé Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft} East[ft] From Approach Separation Highside Distance [ft] Irrlp.nl ! rftl 70544 3418.0( 2454.58' 4492.65E 112 5821.3 3415.3 2346.38' 3523.55E 90.1 975.1 71000l ::\4297¡ 24ÇR ::\7~ 44RR.::\RF 112 5866.71 342fi.2 2::\qo.?2 ::\!'i1R.fi2F qOJ 97!'i.7 71334' 3438.4. 25::\049~ 44R5.25F 11? !'iQOo.::\: ::\4::\::\.fi! 2422.7?~ ::\514.Q7F R9J 9762! 7200.0 3454.5 2594.79~ 4478.98E 112 5966.5 3446.5 2487.27' 3507.72E 89. 977.2 723::\4 ::\461.71 2627.26~ 447!'i.R?F !112 !'iqqq.!'i, ::\4!'i?1 ?!'i1 q.!'iq~ ::\!'i04 OqF RQf Q77.7 7300.0( 34744¡ 26Q2.31c 446Q48E '11? fi065.2 ::\4fi01 2584.::\4~ ::\4Q6.82F 89. 978.7 7300.0 3474.5( 2692. 39~ 446947E 112 6065.2 3460.1 258441~ 3496.81 E 89.~ 978.7 7400.0( 3491 .81 27QO.3::\~ 445Q.Q2E 1112 fi16::\.1 34fi!'i.6( ?6R14R~ ::\4R!'iQ1 F RB.E 9804 7!'i00.Of ::\!'iOq.2 2RRR.::\4~ 4450.37E 112 6259.5- 3464.21 27772S~ 3475.14E 87.E qR? !'if 7600.0( 3526.5f 2986.36 4440.81 E 112 6357.9 3460.21 2874.98~ 3464.16E 86.4 985.2 7700 Of ::\!'i4::\ q. ::\OR4 ::\R' 44'>.1 ?RF 112 64!'iRB: 34!'iQ 7~ ?Q7<; ?m '>.4£;?Qm RS. QRR O~ 7ROOOC ::\!'ifì1.::\1 ::\1 R2.::\q~ 4421.71 F 11? 65574 3460.6~ ::\07::\ ?O~ ::\441.RqF 84. Qq10' 7900.0 3578.6f 328041 ' 4412.15E 112 6656.0 3461.5 3171.20' 3430.88E 83.~ 994.2 ROOO Of ::\!'iq6 0. ::\::\7R43~ 4402.6OE 112 67515: 3461.8: 3266.0S~ 3420.22E 82.~ qq7.RI 81000C ::\61::\4( ,)A7" AA' A'>.Q'>.fI<;F 11? RR4RR, ::\4!'iq R.c ::\::\fì? 74,' R1F 100?0' 8159.8 3623.n 3535.06' 4387.33E 112 6907.4 3458.6 3421.02' 3402.82E 80.E 1004.7 8200.0C ::\630.2 ::\!'i74.!'i!'i~ 4::\R::\4RF 11? Rq47.0: ::\4!'i77 ::\4fìo.::\m ::\::\QR41F ROA 1006.!'i1 8259.8( 3637.7( 4377.73E 11? 7006.1 ::\4!'ifì!'i! 351Q06~ ::\391.ROE 79.8 1008.9! 8300.0 3641.3< 367344 4373.85E 112 7046.1 3455.7 3558.75~ 3387.35 79.~ 1010.3 8359.8( 3644.61 '>.7'>.? RR' 4::\6ROiiE 112 7105.7 ::\4!'i44 ::\617.QR~ ::\3RO 701 79. 1012.0: R400.OC ::\R45.5~ 3772.86! 4364.1SE 112 7145B! 3453.6: 3657.RR~ 3376.22 79.1 1012.9! 8420.1 3645.5 3792.94 4362.20E 112 7166.0 3453.2 3677.92 3373.97 79.( 1013.3 R!'iOO.OC ::\R44 !'i~ 3872.38! 435445E 112 7245R~ 3451.5: 3757.21 3365.06E 79.( 101461 R5?0.1 3fì44.1 ~ ::\Rq? 4R~ 4::\!'i? !'iOF 112 7266.0! 3451.1 3777.26: 3362.81 7q( 1014.R' 8600.0 3642.0¡ 3971 .88 4344.76E 112 7345.8 34494 3856.55' 3353.91 79.( 1015.9 Rfì20.1 ::\R41 4' 3991.95~ 4342.8OE 112 7366.0: 344Q.D: 3876nm 3351.66E 79.( 1016.2 870001 3fì::\R3f 4071 34~ A'>.'>.<; fI~F 11? 744!'iR.c ::\447 ::\! '>.Q<;<; QQ' '>.'>.A,) 7<;F 7Q 1017 1, 8720.1 36374' 4091 40 4333.11E 112 7466.0 3446.9 3975.92' 3340.50 79. 1017.3 RROO.OI 3fì::\3.::\: 4170 74 4::\2!'i ::\7F 112 7545.7 3445.21 4055.18~ ::\::\::\1.Rm 7q ~ 1017.q! 8811 1 3632.61 41R1.7R~ 4324.::\OF 112 7!'i!'ifì RS ::\44!'i O~ 40fìfì ?1' ::\330.3fìF 7Q.3 101ROI 8900.0 36274 4270.10 4315.69E 112 7645.7 3443.1 415446' 332045 79'< 1018.7 9000.01 36?1.6! 436Q 46~ 430fì 01 F 112 774!'i.fì: 3441 Of 42!'i3 731 3::\Oq.3Of 7M" 1 01 Q}i: qOOR!'i' 3621.2~ 4375.99! 4305.:\7E 112 77!'i2.1 3440.Q.< 4260251 3308.57 79.8 1019S 9100.0 3616.3 4468.85 4296.32E 112 7845.5 3438.9 4353.02 3298.15 80.C 10204 9106S 3616.0~ 447!'i38~ 42Q!'i.6RE 11? 7R!'i2.1 ::\438,R! 43!'iQ.!'i!'i! 3?Q742F RO.C 10204 q?Oo.ol ::\R12.4: 4!'iRR ::\O! 428662E 112 7M5}): 3436.91 4452.351 80. 1021.5: 9206.5 3612.2 4574.83 4285.99E 112 7952.1 3436.7 4458.87 3286.27 80.1 1021.6 q::\ooOI ::\ROq 7~ 4bhf 'H: A?7R Q'>.F 112 R04!'i !'i: ::\434R' 4!'i!'i1 6q~ ::\?7!'iR4F RO.1 10?? R" q::\Ofì !'i' ::\Rnq fì.< 4?7R ?QF 11? R0520¡ 3434.6' 4558.21: '>.?7£; 11 RO 1O?? q' 9397.5 36084 4764.82 426747E 112 8143.0 3432.7 4648.55 3264.97E 80.1 10244 MOO.OI ::\ROR.4: 476731 426723E 112 R145.51 3432 7 4651.03~ ,)"~A ~m 80. 10244 q4Q7.51 ::\fìOR.::\~ 4Rfì4.::\!'i~ 4257.77E 112 8242.9~ 3430.6: 4747.87 ::\?!'i::\.R1 RO ( 1O?fì.1 9500.0 3608.3 4866.84 4257.53E 112 8245.4 3430.6 4750.35 3253.53E 80.C 1026.2 q!'iQ7 !'il ::\fìOq fì' 4qR::\.R7 4248.07E 112 8342.9' 3428.5: 4847.15~ ::\?4? RR¡ 79.8 1028.2 Q600.01 3609.6f 4247.R::\F 11? R::\4!'i4 ::\42R !'i: 4R4q.fì::\: ::\242.::\RF 7q¡; 10?R2 9697.5 3612.1 5063.37' 4238.37E 112 8442.7 34264 4946.39 3231.52E 79. 10304 9700.01 3612.2' <::r":",, 0<::' 42::\8. 1::\F 112 R44!'i ?¡ ::\42fì4 4q4R.R7~ ::\2::\1.24 7Q. 1030!'i! q7::\1 !'il 3613.3: 5097.19~ 4235.07E 112 R476.7 342!'i.7 4980.11' 3227 73E 79.6 1031.3: 9800.0 3615.8 5165.32 422843E 112 8545.1 3424.3 5048.05~ 3220.1OE 79.4 1033.0 QqOO nl 3619Æ 5264 78~ A?1R 7AF 112 Rfì44 q: ::\4222' !'i147 2::\~ '>.')nR QRF 7Q. 10355- qQR7 q! ::\fì2? fì~ !'i::\!'i?25! 4210.21 E 112 8731.3f 34204 5233.09! 3199.3OE 78.f 10::\7R' 10000.0 3623.1C 5364.24 4209.04E 112 8743.3 3420.1 5245.04 3197.94E 78.f 1038.1 100R7 q 3625.6~ 5451.73~ 4200.52E 112 RR31.2· 3418.1 !'i332.2R! 318805E 78} 1040.31 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) PLJr~b1 B~e1rJÄrorated . . Conoc<>Phillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 10 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska .¡. BAKER HUGHES INTEQ Clearance Data . . Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation . Highside Distance [ft] Irrl¿nl rft] 10100.0 3625.9 5463.73 4199.351 112 8843.2 3417.9 5344.24 3186.70 78.E 1040.6 1011'170' 3627.3t 5551 .25~ 4190.82E 112 89:\1.1 :\415.91 54:\1.53~ :\176.801 78.~ 1042.7 10200.01 :\R?7.4' !'i!'iR~24 4189.651 112 8943.1 3415.61 5443.50~ ~17!'i4!'iF 71'1 ~ 1042.0J 10287.9 3627.7 5650.77 4181.121 112 9031.0 3413.7 5530.82( 3165.55 78. 1044.7 :\R?7 RF !'iRR?77 4179.951 112 9043.1 34134 5542 79~ ~1R4.101 71'1') 104!'i.n: 10374.0: :\627 or <;7<\R <;I1C 4172.7RI 11? 0117 1 :\411 7 !'iR1 R :\7( :\111!'i8I1F 78. 1046.:\1 10400.0 3626.5f 5762.29 4170.251 112 9143.1 3411.2( 5642.11< 3152.93 78.1 1046.8 :\R24.?' 118R1.81 41RO.7?1 11? 0?4~ OJ ~40A.0¡ !'i741 4~~ ~141 R7 781 1048.4 3620.11, 11961.:\1 4111140F 11? 0:\4~ 01 :\40R 7 11f!40.7 4< :\1:\041 78. 1050.01 10700.0 3615.5f 6060.77 4142.3OE 112 9442.9 34044 5940.02~ 3119.16 78.2 1051.6 :\611?f 61:\07?! Ll1<\R 11?~ 11? 0!'i1~ ?I ~40? 0 RI1I1QR<;C ~111 ?4f 78.f 10112.7: 101'100 01 ~ROO. ~f 6160.18~ 4133411 112 9542.8! 3402.2. 6039.25~ 3107.91E 7A.F 10!'i~.1 10900.0 3602.8< 6259.57 4124.571 112 9642.7 3400.0 613847 3096.66 78.S 1054.7 1100001 3596.3~ 6358.97 4115.73E 112 974?6, :\:\97.7 62:\7.69~ 308541 79.1 1056.2 ~110? 01 A1na am 11? 9808.6! 3396.2f R'>.n'>. ')"'( '>.n77 QRI 70~ 10117 ~I 11100.0 3589.8E 6458.37 4106.901 112 9842.5 3395.5 6336.91 ~ 3074.17 79. 1057.8 111 RR 0 ~I1AR.1' 6524.08~ 4101.061 112 9908.5! :\394.0: 6402.50~ 3066.731 70.f 10!'i0.0' 11200.0 :\11f!4 4! RI1117.R~! 400A.ORI 11? 004?,4 ~~0~.2 R4~R 17( ~OR?}11 79f 101196! 11266.0 3581.5f 6623.59 4092.211 112 10008.5 3391.8 6501.78( 3055481 79.E 1060.9 11 :\00.01 :\I1AO.~< RRI17.:'\!'i! 401'10 ?11 11? 1 004? 4 ~~01.0: R!'i~!'i 4R~ ~0!'i1.RRI 7¡:¡ 10R171 11354.3 35786! 6711 ,46~ 4084 40E 11? 1 009R 7: ~:\80.8, 6118¡:¡.4:\~ :\04554E 79. 1062.9' 11400.0 3577.5 6756.92 4080.361 112 10142.3 3388.8 6634.77( 304040E 79.S 1063.9 11454.3 3576.5! 681104 40711.11111 11? 1019R.71 ~3A7.R( RRRA.74 <\11<\Ll ? R~ 79.1' 1065.3' 111100.0 3576.0: 685651 407151 E 112 10?423: :\386.5' 6734.07 3029.14 79.1' 10RR 4' 11554.3 3575.7 6910.65 4066.691 112 10296.6 3385.3 6788.04 3023.03 79. 1067.9 11600.0 3575.8' 6956.12 4062.611E 112 1m42.?1 ~:\R4 :\. 6R:\:\.:\6~ :\017.891 79. 1069.2, . ,&:c:, ., ~117R ?! An"7 RAI 112 10<\0/;<;( 33831 : /;1'11'17 ~1: ~011 771 70F 1070 A: 11700.0 3576.9 7055.72 4053.801 112 10442.2 3382.1 6932.62 3006.64 79.E 1072.2 117411 2 ~1177.0( 7100.81 4049.79E 112 10487.4: 3381.0: 6977.54~ 3001.541 79.5 1 07~.RI 118000 :\1179.H 71!'i!'i.~0! 4044.041 11? 10542.0~ 3379.81 7031.A~~ ?0011.~01 7a.~ 107114 11900.0 3581.5f 7254.88 4036.091 112 10641.9 3377.6 7131.03~ 2984.14 79.1 1078.6 1HHO.7 ~!'iA? 11( 7?04 42 4m?!'iAI 112 1 0681.51 3376.7 7170,42< ?070.RAF 70 r 1070 01 1?000.0 311R3.6f 7~54 46! 40?7.241 11? 10741.1'1' ~~7!'i.~! 7?~0.?4~ ?o72.oOF 7AP. 108181 12039.7 3584.2 7394.01 4023.721 112 107814 3374.5 7269.65 2968431 78.1' 1083.0 17100.0 3I1R4.6· 74!14.07 401A.~01 11? 10f!41.7 ~~7~.1 7~?0 !'i0~ ?061.RI1I 7AP 10R4.R: 12139.7 3584.6: 7493.61 4014.87E 112 10R814 :\372.21 7'>&:0 a,>, 2957.181 78. 1085.91 12200.0 3584.2 7553.67 4009.531 112 10941.6 3370.9 7428.80 2950.391 78. 1087.6 12239.7 35837- AI1I1RI1H 11? 111QR1 '>." ~~70 0: 7ARR ?<\( ?QA<; Q?~ 7R 108R6: 1 ?~OO 0, ~!'iA? !'i' AOOI1 /;R~ 112 11041RI :\:\6R 6' 7<;?R 111( 2939 131 78. 1090.01 12330.6 3581.7 7683.77 3997.97E 112 11072.2 3367.9 7558.53~ 2935.681 78. 1090.7 12400.0 3579.5: 7752.82~ :\991.8:\1 112 11141.R: ~~66 4: 767741 7927.871 78 10923' 124~0 R ~117A.~ 7783.32~ 3989.11E 112 11172.2 3:\65.7. 7657.83~ 2924431 71'1. 100? Oc 12500.0 3575.2 7852.34 3982.98E 112 112054 3365.0 7690.77 2920.691 78,f 1094.8 1 ?!'i~O.R ~!'i7~F 7882.82~ 3980.27E 112 11205.41 :\:\6501 7690.77 2920.691 78 1 096.8~ 1?!17!'i.R ~1171.0~ 70?7.A1 ~07R.?7~ 112 112054( 3365.01 7690.77 ')a')l1 "'01 71'1 1101.~: Offset Wellbore Surve rams MWD+SAG - ISCWSA - 28 Ja 112 112L 1 Planned All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MO's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) preOR r(jir~ Aotated . . Conocri'Phillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 11 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prept'1 hBlkr!t.~.K.. es InÅorRorated UI\ o"Jf\L Bi. BAKER HUGHES INTEQ . . conoc;pJ,illips ConocoPhil/ips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 12 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska Bi. BAKER HUGHES INTEQ ClearanCéData Reference Réference Reference Reference Offset Well OffSét Offset Offset Offset Anglé Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Distance [ft] IrciAol I rftl 7054.4 3418.0( 2454.58' 4492.651 112 5821.3 3415.3 2346.38 3523.55E 90.1 975.1 71nO.OI ~4?CI 7 24C1R.37~ 4488.381 1112 5866.7 3426.2 2390.22! 3518.62E 90.( 9757 71::1::1.4 ::I4::1R.4 ?I)~O.4C1! 44RI)?I)1 1112 I)ClOO.~' 3433.6: 2422.72 3514li7E 89.Ç Cl7R ?' 7200.0 3454.5 2594.79' 4478.98! 112 5966.5 3446.5 2487.27 3507.72E 89. 977.2 7?::I::I.4' ~4R1.7 2R27.?R! 4471).R2f 112 5999.7 3452.3~ 2519.78~ 3504i)7E 89.f Cl77.T 7':\00.01 3474.4 ?RCl2::11' 44nCl.4Rf 11? nOnn.::I, ::I4n::l.CI: ?5R4.Cl2 ::1496751 89.~ 97R.n! 7300.0 3474.5( 2692.39' 4469.471 112 6066.4 3463.9 2585.00 3496.75E 89.~ 978.6 7400.0( 3491.8! 2790.3::1~ 445C1.Cl21 112 n1nn::l: ::\4R1.2! 2nR2.78~ 3485 761 89.~ ClRO.1 71)on 0/ ~I)OCl.?~ 2888.34~ 4450.371 112 6266.3: 3498.61 2780.64! 3474.77E 89.~ ClR1.51 7600.0 3526.5 2986.36~ 4440.811 112 6366.3 3516.0 2878.49! 3463.78E 89.~ 983.0 770001 ':\<;4':\ Q' ':\I1Rll ':\R! 44::11261 1112 ß4n6 ::II ::15::1::13: ?Q71; q¿[ .54~, Hit 89.~ ClR441 7ROOOI ~I)n1.~ ':\1R?::ICI! 44?1.71! 112 6566.2~ 3550.7: 3074.20: 3441.8OE 89} ClR5.9: 7900.0 3578.61 3280.41 ' 4412.151 112 6666.2 3568.1 3172.05 3430.8OE 89.~ 987.3 ROOO.OI ~I)ClR.O, ::I~7R.4~! 4402.601 112 6766.2 3585.4: 3269.91 3419.81 89} ClRR.R: A1111111J ::In1~4( ':Ill71; M' II ':10':1 11&;1 111? nRnn ?I ~n02 R. ':1':11;771;' 89.f OQO ?I 8159.8 3623.7! 3535.06·' 4387.33! 112 6925.9 3613.1 3426.14~ 3402.26 89.~ 991.1 R200.01 ~n::lO.?' ~<;74.I)I)! 4~R~.4Rf 112 6965.9 3619.4! ':\4n<;.40! "-Y;:JI.o.; R9} OQ1.7 8259.81 ::I6::17.7( ::In~::I.nO: 4::1777::11 112 7025 1 ::In?n.ClI ~5n 79~ 3::191.301 89.~ QQ2.<;! 8300.0 3641.3 3673.44 4373.851 112 7065.1 3630.4 3563.39' 3386.84 89.< 993.1 R,:\<;Q AI ::Iß44 nl ::IB2.Rn 4::1nR.05f 111? 71?4.51 ::In::l::l 7 ::In22.3::1! ::1::180.231 89. QQ40! R400.11/ ,:\1;4<;.<;~ ::177286 43ß4.15E 112 71 ß4::1¡ 3634.S. ::I661.89~ 3375.781 89.~ QQ4.R, 8420.1 3645.5 3792.94 4362.2m 112 7184.5 3634.5- 3681.97! 3373.53 89.~ 994.9 R<;OO.111 ':\R44.5: 3872.38 4354 451 112 7264.Q¡ 3632.R. 3760.93~ 3364.661 89. QQR.1 RI)?O 1 ::IR44.1 ::IRQ? .4R: 4::1<;?<;nI 112 7284.2 3632.2· 3780.96~ 3362.41 89..~ ClQ64 8600.0 3642.m 3971.88 4344.761 112 7363.8 3629.3 3860.07~ 3353.53 89.~ 997.61 RR?O.1 ~R41 4' ~QQ1 Q<;: 4342.801 1112 7384.0 3628.5 ':\RRO OCl! 3351.281 89. ClCI7R! R7000 ~n::lR ~I 4071 ~4 A':I':I&; 111;1 111? 7 4R~ R' ~R?4 R ::IQI)Q 14! ::1::142401 RCI ~ oaQ 11, 8720.1 3637.4' 4091 .40 4333.111 112 7483.8 3623.5 3979.15 3340.151 89. 999.3 RROO.O ~n~~.::I' 4170.74 4~?I).::I7f 112 7563.51 3618.5 4058.14 3331.281 89.. 1000.51 8R11.1 ::In::l2.6: 41R1 m 4::124.::101 1112 7574.6 3617.8 4069.15: ::1::130.051 R9. 10110.7 8900.0 3627.4 4270.10 4315.691 112 7663.3 3611.5 4157.15 3320.16 89,( 1002.0 9000 n ::In21 n: 4~RCI.4R: 4::10R.01f 11? 7763.31 3604.4 4256.26: ':\':\I1Q 11':\1 RCI,( 1M':\,'i' QI1I1I; <; ::In212 4::175.99: 4::105.::I7f 112 776C1C1: ::I6m.CI 4262.77~ ':\':\OR ':\01 89.( 11111::1.R' 9100.0 3616.3 4468.85 4296.321 112 7863.5 3597.7 4355.62! 3297.871 88.£ 1005.0 9106.5 ::IR16.0~ 4475::1R 42C15.RRf 112 7R70.1 ::II)Cl7.::I 4::162.1::\! ::1297.141 8R.~ 100<;.1 Q?OO 11 ,:\1;1? 4 4286.62E 112 796::18' 3592.2 4455.07 3286.7OE 88.f 100R.I)· 9206.5 3612.2 4574.83 4285.99E 112 7970.3 3591.9 4461.59 3285.9ZE 88.f 1006.6 Q':\I1I1I1J ,:\I;I1Q 7~ 4hhll~: II ?71; Q,:\~ 112 R064 01 ::I5RRO! '~~A ~. ':\?7<; <;::IF 88.f 100R O' CI~OR<;' ~RnQ fu ll?71; ?Q~ 112 8070.6: 3587.8: 4561.13~ ~?74 791 88. 100R 1 9397.5 3608.4 4764.82 4267.47 112 8161.8 3585.2 4651.71 3264.62E 88. 1 009.4 Q400.01 ~ROR.4 4767.31 4267.231 112 8164.3' 3585.1 4654.19~ 3264.34E 88. 1 OOCl,5- Cl4C17.I)1 ~ROR.::I~ AoeA ')<=, 42<;7.77 112 8262.1 3583.6· 4751.36~ 3253.43E 8RE 1010.91 9500.0 3608.3 4866.84 4257.53 112 8264.6 3583.6 4753.84 3253.15E 88Æ 1011.0 91)Cl7 I)' ~ROQ R' llQI;':\.R7! 4248.07 112 8362.4' 3583.3: 4851.04 3242 23E 88} 1012.4 9600.01 ~ROCl RI 4C1RR ::IR! 4?47 R~f 112 8364.9' ~I)R::I ~. llA<;':I.<;?' 324 L96E RR.~ 101?S 9697.5 3612.1 5063.37 4238.37 112 8462.7 3584.4 4950.74 3231.04E 88.~ 1013.9 9700.01 ::IR12 ?, 4nR.nl 11? 8465.2' 3584 4 4953.22~ ::InO.7nE 8R~ 1014.0' Q7':\1.<;1 ':\1;1 ':\. ':\~ 50Cl719! 11? R49R.8( ::158501 4Q84.58~ 3227.24E 88. 1014 1)( 9800.0 3615.8 5165.32' 4228.43 112 8565.5 3586.8 5052.89 3219.57J 88.~ 1015.5 Q90001 ::IR1 Q 4 ~ &;?I;A 7A' ll')1A 7111 11? 8Rnl) 1)1 ::II)R99: ':\?I1R ll1l 88. 1017 O' QQR7.Q' ~I;??K <;':\<;2.25! 4210.21 112 87535: 3592.6: 5239.61 3198.6m 88. 1018.::1' 10000.0 3623.1( 5364.24~ 4209.041 112 8765.6( 3592.9 5251.58 3197.25E 88. 1018.4 100R7.Q ,:\I;?<; I;~ 5451.73~ 4200.521 112 8854.21 ::1594.8: 3187.42E 88. 101 CI.7 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ORt GINAL . . conoccrPhillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 13 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska Ri. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference OffsetWeU Offset Offset Offset Offset :~ngle . Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Distance [ft] ¡rdeal rftl 10100.0 3625.9 5463.73' 4199.351 112 8866.3 3595.0 5351.65~ 3186.09E 88.~ 1019.9 101R7.Ç ::\fì?7.::\! SSS1.?S~ 41ÇO.l'Ø 112 RÇS4.7 ::\SÇS.7 S4::\Ç};?: ::\176.::\61 R8.~ 1n?1.0: 1 ()?n()~o 3627 4 SS6::\.24 41RÇ.6SI 112 AÇ6R .7 ::\5ÇS.7 5451.50: ::\175.04E 88. 1021.2 10287.9 3627.7 5650.77 4181.121 112 9055.1 3595.3 5539.38 3165.38E 88.~ 1022.3 10::\00.0 ::\627.61 5nn?77 417Ç.ÇSI 112 ÇOn7.?' ::\5ÇS.1 5S51.::\6: ::\164.07 88. 10??,4 1m74.n 3627.0( 57::\6.50: 4172761 112 Ç141B <\<;a<\ al 3156.01 88.1 10?::\.::\ 10400.0 3626.5! 5762.29 4170.251 112 9167.3 3593.2 5650.90~ 3153.23 88.1 1023.6 1 n!'inn.n <\R?4.2· 5Rn1.81 41/ì0 721 112 Q?AA.a <\<;an n: 5749.81' 3142.491 88.1 10?4.Ç, 10nOO.0 ::\n?O S~ SaR1 <\1 4151.401 112 Ç<\nR4 <\SRS S! SR4R.nn~ ::\1::\1 7nl R8( 1n2R.4 10700.0 3615.5 6060.77 4142.30 112 9465.9 3579.8 5947.44' 3121.03E 88.C 1028.1 1077n <\ <\R11 ?! R1<\n 7?' a!'i<\R ?' <\S74 al "'< <'" A7[ R7P 1('\?Q.Il( 101'100 0 ::\/ì09.::\1 n1nO 1R~ 41::\<\ 411 112 ÇSnS 71 ::\S7?7 n04n.::\2! ::\110.::\Of 8n 1n<\o OJ 10900.0 3602.8 6259.57 4124.57E 112 9665.6 3565.2 6145.43 3099.53! 8n 1032.0 110000 ::\SÇn.<\~ n<\!'iR Ç7 411573E 112 Ç7nS.7 <\SS7.RI n?44 n2 ::\ORR.7nl 87J 1n<\4.n' 11(,\RR ('\ ::\5Ç?0' ~.Il').Il ~<;, QQ"!') 11 ::\S5::\ ::\1 ::\081.61 E 8n 1 n<\!'i <\~ 11100.0 3589.8 6458.37 4106.90 112 9866.2 3551.3 6344.30 3077.94E 8n 1035.9 111 n6.0 ::\586.1 nS24.0A~ 4101.0nl 11? ÇÇ::\? n! ::\S47.6i /ì410.?5! ::\070.7AE 8n 1n<\7.?1 1pnn.n <\!'iA44 /ì557.83~ 409A.061 112 aaRR:7 3546.0' 6444.07! 3067 1 H 8n 10::\7.9: 11266.0 3581.5 6623.59 4092.21 112 10033.1 3543.3 6510.05 3059.94E 8n 1039.2 11 <\nn. n ::\580.::\, n657.::\5~ 40AÇ.?1 112 1 00/ì7 1 ::\542.1 /ì54::\.A7 ::\05/ì27E 8n 10::\Ç.AI 11<\!'i4.<\ <\S7A.R' /ì711.46~ 4084.401 112 1 n1?1 ~A' <\!'i4ns· n!'iaA.21 <\OSO.<\71 8n 1040.9' 11400.0 3577.5 6756.92 4080.36 112 10167.6 3539.5 6643.70 3045.43E 87.E 1041.8 114!'i4.<\ <\S7n.!'i' /ì811.04~ 4075.551 112 1n2?2.?· <\!'i<\A.71 nRaA.n7 87.E 104?A! 11 SOO.O ::\S7n 0: nASn.S1 4071.51 112 ::\S::\A.?' n74::\.SA! ::\0::\4 5Ç1 8H 1n4<\ 7 11554.3 3575.7 6910.65' 4066.69 112 10322.7 3538.1 6797.96 3028.68E 8n 1044.7 11nOO 0 <\S7S.A, RÇ!'iR.12~ 4062./ì51 112 1mnAF <\S<\A.<\. nR4<\.4n! ::\0?::\.741 AA ( 104!'iF 11R<;.Il "! ::\576?! 7('\1('\ ')<;, 11? < "A"'''' ." ::\S::\A Ç ~QQ7 A.Il' :~('II M41 8RC 1 n4n 7: 11700.0 3576.91 7055.72' 4053.80 112 10469.0 3539.7 6943.33 3012.901 88.C 1047.6 1174S.2 ::\S77 ç¡ 7100 I'll 4049.791 112 10S14.R ::\S40.7 nÇAA.n6~ ::\007.ÇAI 8AC 1n4A .Il 11800 0 ::\579.1! 7155.::\0! 4044 Ç4 112 105nÇ.::\ ::\542.2 704::\08~ 3002.071 88.C 104Ç.S 11900.0 3581.51 7254.88' 4036.091 112 10669.3 3544.9 7142.44~ 2991.28E 88.C 1051.4 11Ç::\Ç7 ::\58?51 7?Ç4.42 40::\? .SAI 1112 1070Ç.0 ::\546.0: 71A1.R9~ 88,( 1nS2.? pnnn.n <\SA<\.R! 7354.4/ì: 40?7.241 1112 1 n7,:¡a:ii, <\!'i47.51 7241.50~ 2980.52 88.C 10S::\ 4 12039.7 3584.2 7394.01 4023.721 112 10808.7 3548.1 7280.96 2976.24 88.C 1054.1 121nii.n 3584/ì' 745407 401 A.::\ÇI 11? 3541'1.9 7::\40.50: 2969 77 88.1 10SS.::\ 121 <\a. 7 <\SA4 n: 7493.61 4014.87E 112 1 nanA.2 <\S4a.n n7a.Rç~ 88.1 1 05/ì 1 12200.0 3584.2 7553.67 4009.53E 112 1 0968.2 3549.0 7439.47' 2959.02 88.1 1057.2 <\<;A<\ 71 7<;a<\ ??' .IlnnR nH 112 <\!'i.llA R¡ 7;170 Q')' ?aS47SI 88.1 10SR O! <\SR? S: 7"'''''> ')~, 4nnn nAF 112 110R7 R, <\S47 A: 7<;,>Q "!'), ,)Q;lQ ')QI AR 1n<;a ? 12330.6 3581.7 7683.77 3997.97E 112 11098.2 3547.1 7568.77 2944.99 88.1 1059.8 <\S7ÇS 7752.82 3991.83E 112 111R7.1 <\S4S.<\· 7n<\7.?S! ?Ç<\7.SSI AA. 1M1.1 1 ?4::\0.n ::\S7A.::\! 77R::\.::\? <\ÇRÇ.1H 112 111Ç7.R' ::\!'i44.::\1 7Rn7.6Ç~ ?9::\4.251 RA. 1nR1.7 12500.0 3575.2 7852.34 3982.98E 112 11266.7 3541.5 7736.13 2926.81 88.1 1063.0 12S::\0.n ::\S7::\ n: 7AA2.A2 3980.27E 1112 112a7 <\' <\S40.1 77nn.5S~ ?çn.S1 RR1 inR?' R' 1 ?S75 A ::\571.0~ 7Ç?7.A1 ::\Ç7n 271 11? 11::\4?::\· ::\5::\7.R: 7A11 19~ 291R./ì/ì1 88.1 1nR4.s, 112 112 r Gyro Single Shot 29-Sep-03 TH MWD+SAG - ISCWSA - 28 Ja 03 OJH Offset Well bore Surve 112 112 Planned 3169.6 ISCWSA MWD AU data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ORIGINAL . . Conoc~illips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 14 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska .¡. BAKER HUGHES INTEQ 112 112 I 6913.2 ISCWSA MWD 112 112 Planned 11358.0 ISCWSA MWD All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of99.01 (10) Prepared by Baker Hughes Incorporated ORIGINAL . . conocåPhillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 15 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska ... BAKER HUGHES INTEQ Clearance Data Reference Réference Reference Reference Offset Well Offsét Offset Offset Offset Anglé Closest Ellipsé MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Distance {ft] rdp.nl I rftl 70544 3418.0 2454.58' 4492.65 22 5889.7 4062.0 2872.18 3478.8OE 116.E 1271.6 7100.0! ~4?Çj.7! ?4ÇjR.~7~ AAAA <!A¡ I'J'J 5914.0: 4076.2! 2885.45: 3493.28E 117. 1248.2 7133,4' 34384< ?!'i~0 4Çj~ 44R!'i.2!'iF I?? !'iÇj:\4 .7 4088.5< 2896.77: 111U 12"11.4 7200.0 3454.5 2594.79' 4478.98! 22 5973.5 4111.4 2917.91 3528.71E 120.~ 1199.5 72334 ~4ñ1 .71 2ñ?7.2ñ~ 447!'i.R2F 2? !'iÇjÇj~.ñ, 4123.3~ 2928.84: 3540.64£ 1221 1184.51 7"1nonl 34744 2ñÇj2.31, 44ñÇj,4RF 22 ñmoñ 414!'i.? 2Çj4R.9ñ~ 124. 11!'iñ.R, 7300.0 3474.5( 2692.39: 4469.471 22 6030.6 4145.3 2948.99 3562.59E 124.~ 1156.8 74nonl 3491.R! 2790.33~ 44!'i!::¡'ÇØ 22 ñORññl 417RS ?Çj7Ç49~ ~595. 75E 126,E 111q.R' 7!'innn( 'I!'inq.?~ 2AAA.34: 4450.371 22 6142.3' 4211.7 3009.83: 3628.64E 129, 1nR7.ç 7600.0 3526.51 2986.36 4440.81 ! 22 6197.7 4244.8 3039.93~ 3661.27E 131.E 1061.3 77nOn! '1<;4'1 ql 'InA4 'IR! 44'11 ?ñJ I?? 6251.41 4277.1 'IOñq Oñ~ 'Iñq? R?I 134.( 104n7' 7ROOO! ~!'iñ1.'I 'I1R?'IÇ! 4421 71 J I?? ñ'lnñ.ñ! 4310.3: 3099.01 ~ 'I7?!'i.1RI 136.1 1 n?ñ. 7900.0 3578.6 3280.41 4412.151 22 6361.1 4343.2 3128.5m 3756.99 139.( 1018.3 7ÇñÇ.n! 'I!'içn.ñf 'I:\4R.n4 4405.561 122 6400D 436681 3149.52~ 3779.631 140.E 101 R. 7 AnOOOI 3!'iÇñ n, <!"I7A A"I' AAI1'J ~111 I'J'J ñ41!'i'l 4'17ñ ?! 'I1!'i7 7Ç~ 141f 1 n17 () 8100.0 36134( 3476.44 4393.051 22 6469.4 4409.2 3186.99: 3819,86 144.( 1022.5 81!'i9.H 3ñ23.7! "r~~ n~ 4'1R7.'I'I1 I?2 ñ!'inn nl 4427.91 3203.5m 3837.531 14~¡j 10290: R2on.n 36~0.2· 3!'i74.55~ 43R34RI 2? ñ!'i22 ñ! 4441 Ç: 321!'i.74~ 3850.57 14ñ.:: 10'1<;.1 8259.8 3637.7 3633.60 4377.731 22 6550.9 4459.3 3230.97~ 3866.74 147. 1048.0 A'InO n 3ñ41.3. 'Iñ73.44. 4'173.R!'i1 2? ñ!'iñ7.!'i' 44ñÇ.6 "I'J<!qq'l' 387ñ.24 14H 10<;q 1 R'I<;qR, 'Iñ44.ñ: 3732.86~ 4368.051 22 6!'i9R3' 448R.80 325ñ52' 3893.711 148.~ 1 n7ç.1 8400.0 3645.5 3772.86 4364.151 22 6614.2 4498.7 3265.13~ 3902.59 149.:: 1094.9 R42n.1 'Iñ4<;.<; 3792.94! 4362.201 22 6ñ24.0 4!'i049 327046~ '>OrlA I1AI 149.E 11n'l !'i, R!'inO ()o 'Iñ44S 'IR7? .'IR~ 4'1<;4451 122 6658.01 4526.3 3289.34: 'Iq?ñ ñn 151.1 11404 8520.1 3644 .1 389246 4352.5OE 22 6668.0 4532.6 3294.97: 3931.951 15H 1150.3 Rñnn n 'Iñ4? nl 3971.88~ 4344.761 22 6703.9 4555.3 331543! 3950.681 153.( 11 Ç1 7: Rñ?01 'Iñ414, 'IÇq1 Ç!'i! A<!A'J AI1' I'J'J 6714.1 4561.8 'I'I?1 'I7! 'IÇ!'i!'i RÇj 1!'i'l 1?n? 7' 8700.0 3638.3 4071.34 4335.06 22 6750.0 4584.7 3342.38 3973.741 154.1 1248.0 R720.1 'Iñ'l74 4nq1 4n! 4'1'1'1.11 I?? 6759 4 4590.8 3348.04 3978.281 155. 1 ?5Ç9, 8800.0 3ñ333: 4170.74 43?!'i.'I7F I?? ñ79R ñ! 4616.1 33n63; 399.£.Z21 1!'iñ 1 308.6 8811.1 3632.6 4181.78' 4324.301 22 6806.8 4621 4 3376.61 4000431 157.( 1315.6 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated n. ; R ~ G..) ~\IA, ......." :' " .. -.,. . . conoc~illips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 16 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska .¡. BAKER HUGHES INTEQ ClearanceData .. Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle I Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Distance [ft] Irdeal Irftl 7054.4 3418.0( 2454.58 4492.651 105 8565.5 3543.1 2434.04~ 5606.43 -9H 1120.9 7100.01 ::\4?Ç.7! ?4ÇR.::\7 44RR.::\RI 10"i 8608.9: 3542.0' 2477.41~ 56DU5J -Ç7.< 11 ?4. 7 7133.4' 343R4< ?"i::\04Ç! 44R5.251 110"i Rô40,? 354 1 .2 2509?2 ~"'^n ^,H -96.E 11?7.fì· 7200.0 3454.5! 2594.79 4478.981 105 8704.4 3539.7( 2572.93~ 5609.37 -95. 1133.8 723::\4 34fì1.7i ?fì?7.?fì~ 447"i.R21 10"i R7::\fì.fì! ::\"i::\R.Ç' ?fìO"i.12! 5610051 -95.~ 1137 O' 7::\OO.()¡ 3474.4f 2n9?31 44n9.4RI 105 R801 2 3537.3; 26n9.66~ 5611.421 -94. 1143.Ç1 7300.0 3474.5( 2692.39 4469.471 105 8801.3 3537.3 2669.74~ 5611 .42 -94.~ 1143.9 7400.Q¡ 3491 .R! 2790.33~ 4459.921 10"i RA9A.nl 35~.9/ ?7n6.95~ 5613.481 -93. 11"i4.fìl 7"i00.()¡ ::\"iOÇ. ?~ ?AAR.34~ 4450.371 1105 8997.3: 3532.6- 2865.61 ~ 5615.551 -92,:' 11 n5.n. 7600.0 3526.5/ 2986.36 4440.811 105 9096.0 3531.5 2964.27~ 5617.41 -91.~ 1176.8 77000 ::\"i4::\ Q' ::\OA4 ::\A' 44::\1 ?fU 1105 9193.6: 3530.5 ::\OR 1 AR~ -90.~ 11AR?: 7AOOO ::\"ifì1 ::\' ::\1A23Ç! 44?1 71 I 110"i 9291.21 ::\5?Q "i 3159.4ill 5n21.091 -R9. 1 ?OO.O' 7900.0 3578.6/ 3280.41 4412.151 105 9388.9 3528.5 3257.10~ 5622.93 -88.E 1212.0 Rooo.n ::\"iQIi.o.. ::\::\7A.4::\! 440?fìOF 10"i 9486.5: 3527.4 3354.71~ 5624.761 -88J: 12?43 A1000 ::\n134( <>A7'" AA ,1::\a::\ O<;¡ 110"i 95M1 3"i?fì 4 ::\4<;? ::\?' <:"'')'" "'AI -87. ~ 1?::\1i A 8159.8 3623.7f 3535.06 4387.331 105 9642.5 3525.8- 3510.69~ 5627.701 -86./ 1244.4 R?OO Oi 3n30.?' 3574Hi~ 43R::\.4RI 10"i 9681.8! 3525.4 3"i50.o?! 5n2R 441 -A6.~ 124Q iii A?"iQAI 3637.7l 4377.731 10"i 9740.7 3524.R, 360R.85~ "iR?Q "iA.1 -85.~ 1?"i71 8300.0 3641.3-' 3673.44 4373.851 105 9780A 3524.3 3648.57~ 5630.291 -85. 1262.1 83598, 3n44.nl ::\732.Rn~ 43nR05F 105 9R39 7: 3"i23.7 3707.R2~ 5n31.411 -84. 1?fìQ.::\· R400 ()¡ ::\1i4"iS 3772.R6: 4364151 105 9879.6: 3523.~ 3747.72~ 5632.161 -84.~ 12741 8420.1 3645.5 3792.94 4362.201 105 9899.6 3523.1 3767.75~ 5632.531 -84.~ 1276.4 R"iOnO 3n44.5: 3A72.38 4354A51 105 9978.9: 3522 ~ 3A47.02: 5634.021 -84, 12R"in. R"i?0.1 ::\fì44.1 ::\RQ? .4fì 4::\"i?"iOF 105 9998.9~ 3522.0 3867.05: 5634.401 -84. 12R7.9 8600.0 3642.0 3971.88 4344.761 105 10078.2 3521 .2 3946.32 5635.891 -84. 1297.0 Rfì?O 1 ::\R414 ::\QQ1 Q"i! 4342.801 1105 10098.3 3521.0 ::\QfìR::\"i: 5636.271 -84. 1299.3 R70n 0 31i3R 31 4071 34. ,1::\::\<:1\1=:1 110"i 10177 "i' 3520.2 ,11\,1<; <;Q' <;1=:::\77RI -R4. 1::\OA ::\, 8720.1 3637A 4091 AO 4333.111 105 10197.5 3520.0 4065.61 5638.141 -84.~ 1310.5 RROO.O 3fì33 3' 4170 74 43?"i 371 11n"i 10276.8 3519.1 4144.81 5639.631 -84.1 1::\1Q.4 Offset.WellboreSurve W 105 105 B-Lateral MWD+SAG - ISCWSA - 28 Ja 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) prepÖ t<rGr1\JIÄr~ted . . ¥ ConocoPhillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 17 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska '&1. BAKER HUGHES INTEQ Clearance.Data . Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Ang/ø Closest Ellipsé MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Séparation Highside Distance [ft] Irneal rm 7054.4 3418.0C 2454.58 4492.65E 105 8561.3 3489.0 2432.88' 5606.40 -95. 1116.2 71000( 34?97~ 249A.~7 44AA.~Af 10!i AR04.6! ~4A7 9- 247R.?2~ !iR07.~?f -94.F 11 ?O 1>' 7133.4' 3438.4 2530.49! 44A5.?!if 1O!i AI>~I>.!i1 ~4A7 01 2!iOA.01' !i1>07.99f -94. 1124.0: 7200.0 3454.5 2594.79 4478.98E 105 8700.2 3485.3 2571.67' 5609.34 -93.( 1131.0 72334 341>1.7f 26?7.21>! 447!i.A?f 1O!i A7~? ~! ~4A4.!iC ?l>m.A4' !i1>10.0?f -92.F 11341>1 7~00 or ~474.AJ 2692.31 4469.48E 105 8791>.9: 34B2.7 26I>B.34~ 5611.391 -91.f 1142.21 7300.0 3474.5C 2692.39 446947E 105 8797.0 3482.7 2668.42~ 5611.39 -91.f 1142.2 74000C ~491 R' 2790.33! 445992E 105 8A94.2: 34BO 1 271>5.5B~ 5613.45E -90.f 1153.8: 7!i00.or :I!i09 ?~ ?AAR.~: 44!i0.~7f 10!i 8993.2 3477.6: 2RM !iR~ 5615.53E -R9 F 11R!i.A. 7600.0 3526.5~ 2986.36 4440.81 E 105 90924 3476.6 2963.76' 561741 -88.S 1177.8 7700 OC ~!i4~ 9! ':I('\QA ':IQ( 44'\1 ?Rf 1n!i 9190.1 34757e '\nR 1 ,\Q~ "R1Q ?!iF _R7 ç 11901 7BOO.Oe 351>1.31 31A23q! 44?1.71 f 10!'i q?A7 7 ~474.7¡ ~1!iQ.0?~ !iR?1.0~1F -A71 120?7 7900.0C 3578.6~ 328041 4412.15E 105 9385.4 3473.81 3256.65' 5622.92 -86.3 1215.5 Aooooe 3591>.0< ~~7A4~: 440?ROf 10!'i 9483.01 3472.9' ~'\!i4.?R~ !iR24.7RF -A!i.F 1 ??8,!'i1 R1no oc '\R1 <\ ;1( "A"'~ ;1<\Q':I n"f 10!'i 9!i80 7, ~47? 0: 34!'i191 ~ "R?R R()f -84. 1241 B: 8159.8 3623.7~ 3535.06 4387.33E 105 9639.1 34714 3510.29' 5627.69 -84.~ 1249.9 8200.01 3630.2 357455! 438~.4Af 10!'i qR7A4 ~71.1 ~!i4q.R4' !iR2A.43f -A3. 12553: R?!iq.RI ~R:l7.7( 4377. 73E 105 9737.3' 3470.!'i1 31>0A.47~ 562954 -83.1 1263.1 8300.0 3641.3 3673.44 4373.85E 105 9777.0 3470.1 3648.20~ 5630.29 -82. 1268.3 R:I!iqRI 3644.61 3732.81> 4368,05 105 9A3R.3: :l4R9.R: 3707 45: 51>31 .401 -82.3 12756: MOO 01 :lR4!iS :l77?RR 4364.15 105 9876.2! 3469.2~ 374735: 5632.15E -82 12804 8420.1 3645.5 3792.94 4362.20 105 9896.2 3469.0 3767.39 5632.53E -82.C 1282.7 A!iOOOI :lR44.!i~ 43544" 105 9975.5~ 346B.3: 3846.66: 5634.02E -82.C 1291 QI A570.11 31>44 1 < 3Aq? 4R 4~!i2 !i0 10!i 9995.6' 3468.1 :lRRR.RQ: !iR:l4.40f -82.r: 1 ?Q4.1 8600.0 3642.0~ 3971.88 4344.76E 105 10074.8 3467.3 3945.95~ 5635.891 -82.C 1303.1 A1>20.1 :1M 1 4! :lQQ1 Q!i! 4342.8OE 105 10094.9: 3467.2 <\QR" QR' 5636.27E -R?1 1:10!'i,4 A70001 31>3A.3f 4071 34! ;1':1':1" ('\¡:;f 1O!i 101741: :l4RR 4' .11('\.11" ??' "¡:;':I77¡:;f -A? ? 1:\14?! 8720.1 36374' 4091 40 4333.11E 105 10194.2 3466.2 4065.24' 5638.13E -82. 1316.4 OffsetWellbore Sauve Well WeIlboré 105 105 D-Lateral MDft SUrvéV Tool 13599.9 ISCWSA MWD Error Model MWD+SAG - ISCWSA - 28 Ja All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) 6RrGrÑ~Ae(ncorporated . . ConocJPhillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 18 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska Ri. BAKER HUGHES INTEQ Clearance.Data Reference Reference Reference Reference Offset Well Offsét Offset Offset Offset Angle Closést Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] from Approach Separation Highside Distance [ft] Ifdèal . fftl 7054.4 3418.0C 2454.58 4492.651 105 8580.7 3717.0 2437.55~ 5606.50 -106.~ 1153.4 7100.0( 3429.7( 2498.::\7 4481URI 105 Rn?4.1 ::\71ñO! ?4RO.95~ 5fi07.4:::>¡ -105f 1155.2 71::\::\,4 ::\4::\R 4 ?S::\O .4A~ AAQ<; ')<;~ 105 8656.0: 371531 2512.79~ <;<=:{)Q {)m -105.1 11SR.R: 7200.0 3454.51 2594.79 4478.981 105 8719.8 3713.9 2576.54~ 5609.44 -104.1 1159.9 72::\::\.4 ~4R1 .7f ?R?7 ?R~ 4475.821 105 8752.0, ::\71::\2, 2608.75~ 5610.131 -103.E 11R?01 noo.o( ::\474 4~ ?RA2.::\1 44RA.4RF 10S AA1R R' 3711.8: 2R7::\ ~::\~ SR11.4AF -10? 11RR 5J 7300.0 3474.5( 2692.39 4469.471 105 8816.7 3711.8 2673.41 ( 5611.50 -102. 1166.5 74000( ::\4A1.R! ?7AO.~::\~ 44SA.921 105 89140: 3709.6, 2770.67~ 5613.561 -101. 11741 75000( 3509.?: 2RRR.::\4 4450.::\7F 10S A012 0: ::\707.R! ?ARR.R1 ~ SR1S.R1f -100 11R21 7600.0( 3526.5E 2986.36 4440.811 105 9109.6 3706.51 2966.21 ( 5617.441 -99. 1190.4 77000( ::\54::\ A! <>'{)QLl <>'Q' LlLl<>'1 ')<=:~ 10S A?07 ?I ::\70S4: 'IOR'I A1 ~ <;<=:1a ')Q~ -AR P 11 AA 1 7AOO.nr 'ISR1 '11 3182.391 4421.711 105 A::\04.RI '1704.4 ::\161.41 5621 12 -97.9 1208.1 7900.0 3578.6E 3280.41 4412.151 105 9402.5 3703.3 3259.00 5622.95 -97.C 1217.3 8000.01 3596.0L ::\378.431 440?nOF 105 ASOO.1 ::\702.?' ::\::\!in.RO! 5n?4 7AI -An.1 1?2n9! R10001 ::\R1'14( '>A7<O A. 4'>.a'>.OSF 10S 95977, 370111 '>.4<;4 ?O' <;R?R R'>.I _A<; ~ 1?'IR al 8159.8 3623.7~ 3535.06 4387.331 105 9656.1 3700.5 3512.56~ 5627.73 -94. 1242.9 A?OO.OI '>.R::\O.?1 'IS74.551 4383.481 105 9n95A 3700.0' 35!i1.R9~ 5n28.471 -94. 1247.1 R259.RI ::\n::\77( 4'177.7'1F 10S 9754.3( 3699.4 3610 72~ SR2a S7 _A::\.!' 12S'>..!i1 8300.0 3641.3 3673.44 4373.851 105 9794.0 3698.9 3650.43~ 5630.321 -93.1 1258.0 R359.RI ::\n44Rf 'I7'1? .AR~ 4'1RA.OSF 10S 9853.2! 3698.3: 3709.68~ 5631 .44F _A? 12R4.T 8400.01 3645.5: ::\77?.Rn~ 4::\n4.15F 10!i AAA'I.1: 'IRA7.A: ::\74A SR~ SR3?1AF -A2 12nA.::\: 8420.1 3645.5 3792.94 4362.201 105 9913.2 3697.6 3769.61 5632.56 -92. 1271.6 8500.01 ::\644.5: ::\R7? .::\A~ 4'1!i4 45F 10!'i 9992.5: 3696.7 'IA4A.AA! SR'I4.0RF -A2 1?AO A! 8520.1 3644.1: 389? .4n~ 43!i250F 105 10012 !il ::\RAR SI 'IARA,A1 5n::\4.4::\F -9? 1?A::\.:::>; 8600.0 3642.0 3971 .88 4344.76E 105 10091.8 3695.6 3948.18 5635.931 -92. 1292.5 8620.11 3641 .4 ::\9A1.AS: 4::\42.AOF 10S 1 0111.A~ 'IRAS.4 ::\ARA ?1 <;<=:<>.<=:<>.m -A2. 1 ?A4.R! A700 01 'II)'IA'II 4071.34: 4'>.<>'<;ORI 105 101911 ::\nA451 ,11'\,17,1<;< <;R<>.77aF -92. 1304.1, 8720.1 3637.4 4091 .40 4333.11 105 10211.1 3694.3 4067.47 5638.17E -92.~ 1306.5 RAOO.OI '>.I)'I'I.'I~ 4170.74 4325.37 105 10?AO.'I1 ::\nA::\A 414n.n71 5n39.nnl -92. 1315.RI AA11 1 ::\n::\?RI 41A1.7A: 4'>.?4 '101 105 10301 4 3693.31 4157.691 5639.871 -92. 1317 1 rams All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ORIGINAL . ConocJ'Phillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E Clearance.· Data Reference Reference Reference MD[ft] TVD[ft] North[ft] Reference East[ft] Offset Well . CLEARANCE LISTING Page 19 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska Bi. BAKER HUGHES INTEQ Offset MD[ft] Offset TVD[ft] Angle Closest From Approach Highside Distance Ellipse Separation [ft] Offset North[ft] Offset East[ft] MD ftl Survev Toöl 10951.0 ISCWSA MWD All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.00 above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Orn¡ ~1kr\,ru~e1Incorporated 1"') ~;~ \':.:~,p ~ 8'+! ,";~', " . . Conocò'Phillips ConocoPhillips Alaska, Inc. 126 Ver#4 , 126 Slot #126, Pad 1E CLEARANCE LISTING Page 20 Date Printed: 1-Jul-2004 Kuparuk River Unit, North Slope, Alaska .¡. BAKER HUGHES INTEQ ClearanceData Reference Reference Reference MD[ft] TVD[ft] North[ft] Reference Eélst[ft] Offset Well Offset MD[ft] Offset TVD[ft] Offset North[ft] Offset East[ft ] Angle From Highside Closest Approach Distance Ellipse Separation [ft] Survev Tool 9505.0 ISCWSA MWD All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ORIS ~JALc ~aker Hughes Incorporalt Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 0.00 to 12575.84 ft Maximum Radius: 1457.58 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive Wellpath Date: 12/10/2003 Validated: No Planned From To Survey ft ft 0.00 12575.84 Planned: 1E-126 Vers#4 V29 Version: 2 Toolcode Tool Name MWD+SAG MWD + Sag correction Summary Pad 1 E 102 102 B-Lateral VO Plan: 1647.09 1450.00 172.57 131.10 Pass: Major Risk Pad 1 E 102 102 D-Lateral VO Plan: 1647.09 1450.00 172.57 131.10 Pass: Major Risk Pad 1 E 103 103 VO Plan: 1E-103 VE 1932.47 1675.00 130.25 68.28 Pass: Major Risk Pad 1 E 104 104 VO Plan: 1E-104 VE 2464.40 2200.00 134.24 40.78 Pass: Major Risk Pad 1 E 105 105 A2-Lateral VO Plan 3095.62 2700.00 275.99 147.30 Pass: Major Risk Pad 1 E 105 105 B-Lateral VO Plan: 3095.62 2700.00 275.99 147.29 Pass: Major Risk Pad 1 E 105 105 D-Lateral VO Plan: 3095.62 2700.00 275.99 147.29 Pass: Major Risk Pad 1 E 11 1E-11VO 322.49 325.00 190.88 186.88 Pass: Major Risk Pad 1 E 112 1E-112V1 4356.50 4050.00 451.61 216.40 Pass: Major Risk Pad 1 E 112 1E-112L1 VO Plan: 1E-1 4009.09 3675.00 384.18 148.95 Pass: Major Risk Pad 1 E 112 1 E-112L2 VO Plan: 1 E-1 4009.09 3675.00 384.18 148.95 Pass: Major Risk Pad 1 E 114 114 A2-Lateral VO Plan ..49ê9.6.!5 4450.00 319.60 109.84 Pass: Major Risk Pad 1 E 114 114 B-Lateral VO Plan: ~9.65 . ,4450.00 319.60 109.82 Pass: Major Risk Pad 1 E 114 114 D-Lateral VOiPlan: // 4 69.65 450.00 319.60 109.83 Pass: Major Risk Pad 1 E 121 121 B-Lateral va Planl 4.06 25.00 121.1 114.63 Pass: Major Risk Pad 1 E 121 121 D-Lateral VO Pit: 424.06 25.00 121.1 114.63 Pass: Major Risk Pad 1 E 12 1E-12 VO 322.60 325.00 184. 6 ¡ 180.55 Pass: Major Risk Pad 1 E 123 1E-123L1V2 \ 770.82 775.00 44. 1 28.43 Pass: Major Risk Pad 1 E 123 1E-123 V18 770.82 775.00 44. 1 28.43 Pass: Major Risk Pad 1 E 123 1E-123PB1 V1 775.00 44. 1 28.43 Pass: Major Risk Pad 1 E 168 168 A2-Lateral V3 Plan 6725.00 25'0. 19.65 Pass: Major Risk Pad 1E 168 168 B-Lateral VO Plan: 6725.00 250.6 19.66 Pass: Major Risk Pad 1E 168 168 D-Lateral VO Plan: 6725.00 250.65 19.66 Pass: Major Risk Pad 1 E 18 1E-18 VO 1425.00 225.68 180.60 Pass: Major Risk Pad 1 E 19 1E-19 VO 1525.00 260.83 212.50 Pass: Major Risk Pad 1 E 20 1 E-20 VO 1675.00 191.43 130.15 Pass: Major Risk Pad 1 E 22 1 E-22 VO 1700.00 625.33 541.21 Pass: Major Risk Pad 1 E 3 1 E-03 V1 1225.00 413.80 383.49 Pass: Major Risk Pad 1 E 33 1 E-33 VO 1775.00 650.80 557.64 Pass: Major Risk Pad 1 E 33 1E-33PB1 VO 1775.00 650.80 557.64 Pass: Major Risk Pad 1 E 34 1 E-34 VO 675.00 220.68 208.65 Pass: Major Risk Pad 1 E 35 1 E-35 VO 250.00 816.08 813.42 Pass: Major Risk Pad 1 E 35 35A VO Plan: 35A ST Ve 250.00 816.08 813.42 Pass: Major Risk Pad 1E 5 1 E-05 VO 1200.00 144. 119.31 Pass: Major Risk Pad 1 E 6 1 E-06 VO 550.00 .96 68.52 Pass: Major Risk Pad 1 E 7 1E-07 VO 450.00 41.71 35.31 Pass: Major Risk Pad 1 E 8 1E-08 V1 525.00 158 150.86 Pass: Major Risk Pad 1J 1 J-DU 1J-L3 A Lateral V1 Pia Out of range OR'Gl~'AL --~- . ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #126 Well: 126 Wellbore: 126 conocdJí,illips ~-~~- Created by: Planner Date plotted: 30,Jun-2004 Plot reference is 126. Ref wel/path is 126 Ver#4 . Coordinates are in feet reference Slot #126. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 fl. Plot North is aligned to TRUE North. Seale 1 em = 300 ft -2400 -1800 -1200 -600 o 600 East (feet) -> 1200 1800 2400 3000 3600 4200 4800 5400 6000 SURFACE LOCATION: 852' FSL. 631' FEL SEC. 16, T11N. R10E ~~,\~()f:) S.... 'f.,0« "'~~~~ ~ ,?,\"~,,,()~~~o ~~Ò~0~~ çe~ ~ ~\I~" 'ô'ð~OC"".o<~ "".- ,,~ pp~ 't-: C'ð "".o'Q ,,:>\<fP ",,:> -------.,j ~ Start 200' Pump Tangent End 200' Pump Tangent, BldfTrn 4.5/100 EOC Top Ugnu B Top U9nu A 1E-126 TOP WEST SA!< D LOCATION: 1603' FNL. 1424' FEL SEC. 22, T11N, R10E K-13 EOC Top West Sak D Bid 3/100 C EOC Top West Sak B A-4 A-3 Top West Sak A2, Int Csg. Pt. j L 9 5/8in Casing 1 E,126 TOP WEST SAK B LOCATION: 1841' FNL. 1448' FEL SEC. 22, T11N, R10E 1E,126 TOP WEST SA!< A2 LOCATION: 2634' FSL, 1528' FEL SEC. 22 T11N. R10E 1E-126L1 & 1E,126L2 TO LOCATIONS: 1636' FNL. 1961' FEL SEC. 27, T11N, R10E TD, 5 1/2 Liner PI. 1E,126 TO LOCATION: V 1796' FNL. 1952' FEL SEC. 27, T11N, R10E 600 0 -600 -1200 -1800 -2400 -3000 -3600 ^ . -4200 Z 0 ;:¡. ::r - -4800 ~ CD - - -5400 -6000 -6600 -7200 -7800 -8400 (j) o I) ëD -9000 0 3 II -9600 ~ o ;:! Scale icm 175ft 1750 2100 2450 2800 ConocoPhHlips 3150 Kllparllk Ríver Unit Pad 11: Slot: Well: Well bore: 126 3500 5950 3850 4900 5250 / 6300 6650 ,4050 ~8750 ,94õO ,9800 Seale 1 em == 20 ft -80 -40 o 40 80 120 I COIl()coPhiUips Alaska, Inc. Location: Nortl1f:llope, Alaska - '-, Slot Slot#i28 Field: Kuparuk River Unit Weli: 128 Installation: Pad is Wellbore: 128 ¿'" ConOcQPhilUps Ea$t (feet) -:> 160 200 240 280 320 360 400 440 480 520 560 600 640 680 720 760 900 800 700 300 1100 1200 100 1700 1000 1200 240 200 160 120 ^ . ConocoPhillips Alaska, Inc. ~/ ConocoPhillips Field: Kuparuk River Unit Installation: Pad 1E Well: 126 Well bore: 126 Ref wellpath is 126 Ver#4 in feet reference Slot #126. are reference reference Rig Scale 1 em ::: 20 ft 680 720 760 800 East (feet) -> 1080 1120 1160 840 880 920 960 1000 1040 1200 1240 1280 1320 1360 1400 1440 1480 1520 1500 1560 o -40 -80 -120 -160 -200 -240 -280 ConocoPhillips Alaska., Inc.. 'Þ:¿ ConocoPhillips Field: Kuparuk River Unit Installation: Well: 128 1,Jul,2004 is 126 Ver#4 in feet referençe Slot #126. $œ Rig Datum. Datum. Seale 1 em == 60 ft 1560 1680 1800 1920 East (feet) -> 2760 2660 3000 2040 2160 2280 2400 2640 3120 4200 3240 3360 3480 3600 3720 3840 3960 4080 o -120 -240 ConocoPhillips Alaska., Inc. I North Slope, Alaska Kuparuk River Unit Installation: Pad 11:: Scale 1 em'" 175 It 2100 2450 2800 3150 3500 3850 East (feet) --> 4200 4550 4900 Slot: Slot#126 Well: 126 Well bore: 126 5250 5600 5950 Date plotted' PIQt reference is 126, Ref wellpath is 126 Vel#4 . Coordinates are in feet reference 310t #126. True Vertical Depths. are- reference Rig Datum Measured Depths are reference Rig Datum. Datum: Datum #1 Datum to mean sea leveL 99.00 ft 6300 6650 7000 -700 ,1050 ,1400 ,1750 ,2100 ,2450 ~2800 -3150 ,3500 ,3850 -4200 ^ . -4550 ,4900 ,5250 -5600 -5950 ,6300 ,6650 ,7000 ,7350 ,7700 (f) (') '" 1ñ ,8050 (') 3 IJ ,8400 ~ ...., '" ::t> Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E ConocoPhillips Alaska, Inc. lot: We!!: Wellbore: Slot #126 126 126 mips Created by: Planner Date plotted: 1-Jul-2004 Plot reference is 126. is 126 Ver#4 . True Vertical Depths are reference Datum. Measured Depths are reference Rig Datum: Datum #1 sea level: 99.00 ft. North is aligned to TRUE North. TRUE NORTH o 10 40 50 60 70 80 90 100 1500 Normal Plane Travelling ~ -.. .... ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #126 Well: 126 Wellbore: 126 ConocJPt, ill ips reate y: Date plotted: 30-Jun-2004 Plot reference is 126. I Ref wellpath is 126 Ver#4 . I Coordinates are in feet reference Slot #126. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. <= o ~ -400 II 1::>] -0 " RKB Elevation: 99' I KOP 400 7.00 BldlTrn 5/100 BldlTrn 4/100 800 CI) 11:: Cõ I :ë 2000 . CI) > ~ 2400 ... t- BldlTrn 3/100 BldlTrn 5/100 Base Permafrost EOC Top T-3 Top K-15 -:--<7 ~ 13 3/8in Casing I V 2800 3200 j J 3600 ~ 4000 I -400 0 400 Scale 1 em = 200 ft Turn 4.5/100 67.95 Tog Ugnu C OLS: 4.50 deg/100ft 67.41 Start 200' Pump Tangen EOC Top Ugnu B End 200' Pump Tangent, BldlTrn 4.5/10 6936 Top Ugnu A DLS: 70.56 K-13 126L2 4.50 deg/100ft TD, 5 1/2in Liner 126L 1 TO, 51/2in Liner .----L1 .---.ç¡ TO, 5 112 Liner PI. ~ ~ 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 Vertical Section (feet) -> Azimuth 118.65 with reference 0.00 N, 0.00 E from Slot #126 Q) ñj .:. 3040 l t) ] ~ 3200 J c,0 'ò-cP 'f-O« .t:. ~ ~ 'I0'~ « ,,\0' 0« Õ. . p'>\q~~"ß~0~~ «'ò-cP«'ò-~e'~ ~ 3360 ~c.~CQ~~~'"_u92" 3520 CI) 3680 "\ o'V .~ 3840 'Is;:~z 1 ~~ 80 ~080 2240 2400 2560 2720 2880 n ~ _ 3040 t) .! :;;- 3200 +J Co CI) C 3360 II:< o a) 1\ E () ñi () :e 3520 ~ CI) ::s ... ~ I V 3840 .~. ..... ConocoPhillips Alaska, Inc. Slot: Slot#126 Well: 126 Wellbore: 126 ~ ConocoPhillips Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E reats y : anner Date plotted: 30-Jun,2004 lot re erence is 1 6. Ref well path is 126 Ver#4 . Coordinates are in feet reference Slot #126. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. 126L2 90.52 126L1 92.60 A-3 ---.¿J Bid 4/100 84.00 EOC ".~ 0r¿,YJ . ~~ \~\ 0'ò-~~ ~ ¡>-"I-~\~\~ '!,.S0' ~ ~e'" ,,\o'V I I 3040 3200 3360 3520 3680 3840 4000 4160 Vertical Section (feet) .> Azimuth 185.57 with reference 0.00 N, 0.00 E from Slot #126 4320 4480 4640 4800 4960 5120 5280 . 3680 TD, 5 1/2in Liner 126L2 126L 1 91.68 90.35 90..33.. TD, 5 1/2in Liner 92.99 .66 TO,S 112 Liner PI. --<;J ~ -1 I 4160 4320 4480 4640 4800 4960 Scale 1 em = 80 ft 5120 5280 5440 5600 5760 5920 6080 6240 6400 6560 6720 6880 7040 Vertical Section (feet) .> Azimuth 185.57 with reference 0.00 N, 0.00 E from Slot #126 7680 7200 7360 7520 KOP: 300' Build at 3-5 degrees/100' o ::::0 - Ú..., .~.-- :z » r- Note: Intermediate and bottom lateral to be drilled with rotary steerable, upper laterals with motor 16" Hole (Spud Mud) 13 318" Casing Hydraulics: Surface: 900-1000 gpm Intermediate: 700-800 gpm Laterals: 500-600 gpm Pore Pressure TVDss TVD MWE 1530 psi 3340 ft 3435 ft 8.8 ppg . Top of Ugnu --.. ,./' +/-4266 ' MD / , Window @ 7054' MD "D" Sand (Oil Base Mud) 8 1/2" Hole 5 1/2" Liner 12,434' MD 3335' TVD Top of Cement MD Tangent Angle: 69 degrees "B" Sand (Oil Base Mud) 8 1/2" Hole 5 1/2" Line 12,438' MD 3401 TVD . ~.--~ '"'~17;"S~~~t:~:f¡ff~~~~2/'\ 5 1/2" Liner e e JD£t -/ ~ 7-- ~~~~~~~H1t~\~~P-DRAKE ATO 1530 700 G STREET ANCHORAGE AK 99501 PAY TO THE ORDER OF -- o CHASE ~~::..~:h:ttan Bank US~ NA ~aJ·d _0 / ¡Ç ~ /2& .-. _.,.. ' -:0:1 . .00 . I.. 1..-: 2 .B I.. ? . ~ 0 ? ~ 2 ? b II' . 0 b B 3 ~ . ep laœ ~ dlAt, 1Þ . h>, trter Checll. fllr» t IJyT . pt "cas ''j. . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME )</eL( IE-/2./.0 PTD# 2() 4" I '2- ~ ./ Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS '~CLUE"· APPLJES (OPTIONS) MULTI The permit is for a new weHbore segment of LATERAL existing weD , Permit No, API No. . (If API number Production. should continue to be reported as last two (2) digits a function 'of the original API number. stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), an (PH) records, data and logs acquired for tbe pilot hole must be clearly differentiated in botb name (name on permit plus PH) " and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ,to fuD EXCEPTION compJiance with 20 AAC 25.0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:Jception. (Company Name) assumes the liabiJity of any protest to the spa dng e:J ception that may occur. DRY DITCH AU dry ditch sample sets submitted to the SAMPLE Commission must be in DO greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. PTD#: 2041220 Administration Well bore seg Annular Disposal Appr Date SFD 719/2004 Engineering Appr Date TEM 7/12/2004 k-~/r, Geology Appr SFD Date 71912004 Geologic Df~ssioner: Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1 E-126 Company CONOCOPHILLlPS ALASKA INC Initial ClassfType DEV I PEND GeoArea 890 Unit 11160 1 Pßrmitfe~ <!ttached, , . . . . . . , , , , , , , , , , , , Yes , , , , , , , , , , 2Le<!sßnumb~rappropriate , , , , , , Yß$ , . . Surface location <!n,dJQp, prod,uçtjve jnt~rv.aJ in AD,L,0256,51;. TD inAD,L025660 3 ,U,nique we'tn,arnß,a[ld lJlJ.mb,er , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , Yß$ , , , , , , , , , , , , , , , , , , ' , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , ' , ' , 4 W~IIJQc¡¡tßdln,a,d,efine,d,pool" .. Y,e$, . ,KßUWestSakOjIPool>goYer[l~d,byC.o[lserv.atiQnQrderNo,4Q6A", 5 W~IIJQc¡¡ted pr,op~r ,dista[lce, from driJling unitb.oUl1d,ary, , , . Yes . , , , , , , , , , , . . . . . . . . . . . . . , , , , 6 WeUJQc¡¡tßd prop~r,distance,fromQth~rwel]s . , , , , , , , . Yß$. . , , , , , , , , , , , , , , , , . . . . , , , 7 ,S,ufficiel1t .acre<!Q.e,ay<!ilab1e indJillilJQ.unjl. , , , , , , , . . . . . . . . . . . Yß$ , , . . . , . , . . . . . . . . , , , , , . . . , , , , , , . . . . , , , . . . , , , 8 Jf.dßviated, js weJlbQre platil1cJuded . . , , , , , , , ,. ,........ Yes , , , , , " '''........''' , , . , , , , , , , , . . . . . , . . . , , , , . 90,perator ol1l}' <!ffected party. , , , , , , , , , , . , . , . . . . . . . Yß$ , , . . , . , . . . . , , , , , . , , . . . . . . . . . , . . , . . , , , , . 10 ,O,per,ator bas,appropriate, Qond inJQrc~ , , , , , , , , , , , , , , , , , , , , , , , , , , , , , ,. ,Yß$""""""""""""""""""""""""""""""""""""", 11 Permit call be iS$lJ.ed wjtbQut con$~rv.atiOI1 Qrd~r , . . . . . . . . . . . Yß$ . , . . , . . . . , . . , , , , , , , , . . . , . . . , , , , . 12 Pßrmit call be iS$lJ.ed wjtbQut admil1istratil(e,approvaJ, """ . . Ye$, , , , , , , , . . . . . . . . . . , , . . , , , , , , . . . , , , , , , , . . . . . . . . , . . . . , , . 13 Can permit be approved before 15-day wait NA 14 W~IIJQc¡¡tßd withil1 <!rea an.d,strat¡¡autbQrized byllljectiolJ Ordßr# (PutlO# in,cornrnellts) (For NA 15 ,AJI welJs,wit)1tnJl4,llJile,ar~a,of reyiew jdßlltlfied (For servjcßwell Onl}'j, , , , , , , , , , , , , , , ,NA , , , , _ 16 PJ~-produ,ced i[ljector; ,dur.atiQnof pre-,produGtioo Ißss than 3. months (For,servtce well QnJy) . .NA 17 ACMPF.indjng.ofCQnststellcyha$ b~enjssued.for.!bis pr,olect NA , , Program DEV On/Off Shore On ~ - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - , . WelJ will be drHled frQm an exjstilJQ. pad. - - - - - - - - - - - - - - - - - - - - - - - - - 18 ,C.o[lductor stringpJQvided . . . . . . . . . . . . . , , , , , , , , , , , . . . . . . . . . , . . . . . . . Yß$ , , , , , . . . . . . , , , . . . , , , , , , , . , , , , , " "............"""" 19S,urf<!cß,casingpJQtec.ts alLknown USDWs , . , , , , , , , , , , , . NA , , , , . . ,A.ll aquif~rs exernptßd 40 CFß :147. 102(b)(3), . . , , , , , , , , , , , , , . . , , , , , , , 20CMT vol. adeQuate.!o circ,ulateon .cond,uctor, & SUJf.c.sg , , . . . , " '" Yes . , . , . . . . . . . . . , , , , , , , , . . . . . . , , , , , , , , , , , , , , , , , , , 21 ,CMT v,ol adeQlJ.ate.!o tie-tn JQngstrillg to surf csg , , , , , , , , , , . . . No, , , , , , , . . . . . . . . . , , . . . , , , , , , , . , , , , , , " ,...........,..,.""" 22 ,CMTwil] coyer aJl koown productiye bQrizQn,s, """,.......""."""" No"... .Slotte,dJin~r,completio[lptanned.lnteJmedjatecementplannedto,col(eranylaJI)1ydJQc.arboos,."" , 23C,asillg d~siglls <!d,eCluat~ for C,.T, B,&,perllJafro$t . , , , , , , . . , Yß$ . . , . , . , , , , , , , , . . . . . . . . . , , , , .. , . . . . . . . . . . , , , " """"""."....." 24 ,AdequateJan,kage,orreserye pit. . . . . , , , , , , , , , , , , , . . . . . . . . , , . . . , , , , Yß$ , , , , , . ßig js.equippe,dwith .stßeLpits. NQ reserv.e,pjt,p!alllJe,d, All w<lste to,an,apprOl(ed ,allnu]usor CI¡¡ss,ll w~lI. 25 Jf.aJe-drilt h<!s,a, 10:403 fOJ abandon.ment beßn apPJQved . . . , , , , , , , , . . . . . . . .NA , , , . . . . . . . . . , , , . . , , , , , , , , , , , , 26 ,Adequ.ate,\f(ellbor~ separatjo,n-Pfo.POsed, , , , , , , , , , , ' , , , _ , , _ , , , , , , , , , , , , , , ,Yß$ , _ _ , , , , I?rOJ$imit}' an.alysis p~rtorme,d. çjoJ>e <lPPJQache,s jd,entjfißd., TraveJioQ. c.ylin,de( plQt jn,clud~d" ,Gyro.s possib]e, , , , 27 Jf.djvert~r J~quiJ~d, dQeJ> jt meet reguJatioos, , , , , , , , , . . . . . . . . , , , , , , , , , , . , , , Yes , , , , , , , , , , , , . . . , . , , , , , , , , , , , , , , , , , , 28 ,DJiUilJg fJujd,prQgrallJ sc.hem<ltic& ~quipJistadequ¡¡te, , , , . . . , , , . , , Yes, . BHF' ex,pected betweeIl8.1-8.6EMW., I?laon.ed MW 9.0- 9.2ppg for intßrme,diate,a,nd We,st $a,k. , , 29 BOPEs, do they meetJeguJatioo , , , , , . , , , . . . . . . . . . . , , , , , , , , . . . . . . . . . , Y,e$ , , , . , , , , , , , , , , , , , , . . . . . . . . . . . . , . , , , , , , , , , 30 ,BOPE,PJ~sS rating <!p,propriate;t~stto(pu,t psig in,commeots), . . . . , , , , . , , , Yß$. , . . . . MASF' calc.uJate,d,at 11.54 psi. 35QO,p,stappr,opriate,.CP,AJ pl<lns.!o teJ>tto 50QO,pJ>t , , , , , , , , , , , , . 31 ,C.hoke,llJanjfold cQmpJies w/APt ßF'-53 (May ß4L ' , . . , , , , , , YßS . . . . . , . , . . . . . . . . . . . , , , , , , . . . . . . . . . . , , , , , , , , 32 WQrk will occur withoutoper<ltjonsbutdown, , , , , , , . . . . . . . . . , , , , , , , , , , . . . . . Yßs . , , . , . . . . . , , , , , , , . , , , , , , , , , , , , , , , , , . . . , , , , 33 Jspresence,QfH2Sg<!s,prQb,able..""" ".........""", ,... No.",,' ,H2SiJ>uolikeIY.Mud,shouJdprecJu,deH2SootheJig.ßigjs~quipp~d,with.sen.sor,s,a[ldalarm,s., , 34 Mecbanic<lLcoodjtiollOf w~lIs wi.thin ,ð.Oß yerified (for,s,ervice wel! onJy) , , . . . . . . . , . , , , NA , , . , , , , , , , , , , , - - - - - - - - 35 Permitcallbeis$lJ.edW!Qhyd(og~nsu!fideme<!suœs"....,. ....... Yß$", ,.KßUWestSakwel]s,1j2miJe,toeastrnß<lsuredJ~sJ>th,all,10pPIlJH2Sln,2003.and2002.."".."", , 36D,atapr~seoted Qn, pote,ntial overpressure ,zOl1eJ>, , , , , , , Yß$. , Expected.re$e.rv.ojr ,pre,s$uJ~ i.s8.1, - ,8,6,p,pg EMW; wjllbedrilled wjtb 9.0,·9.2 ppg mud., , , , , , , , , , , . , . . , 37 ,Seismic,analysjs,QfJ>haJlowgas,zooe.s". ..".....,."", ,....... NA", ,.l:IydJat~sandJ>baJlowgas,aJ~oo,texpected.,. """,..........."",.""" 38 Seabed ,col1djtiOIJ surv.ey(if Qff-shoœ) , , . , , , , , , , ,. ........,. . . . .NA . . . , , , , , , . . . . . . . , , , , . . . . . . . , , , , , , , , , , , , , , , 39 ,Conta,ct namelp)1on.efor,weelsly progress reports [explQr<ltory .only] , . , . . , . . . , . . , , , , ,NA , . . . . . . . . . , , , , , , , , , , . . , , , , , , , , , - - - - - - - - - Date: Engineering Commissioner: Date Public Commissioner Date 7 ( 14 ~ o o . e e e 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. **** REEL HEADER **** LDWG 05/02/03 AWS 01 **** TAPE HEADER **** LDWG 05/02/03 01 *** LIS COMMENT RECORD *** . !!!!!!! !!!!!!!!!!!! LDWG File Version 1.000 ! ! ! !! ! ! ! ! ! !! !! ! ! !!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 G. SUTING D. GLADDEN MWD RUN 4 7 S. TUFTON P. WILSON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE BIT SIZE (IN) 16.000 12.250 8.500 -* . O<oi-- j;¿2- DRILLERS DEPTH (FT) 120.0 3795.0 8094.0 12611.0 ~'\ ~-, ~)v lE-126 500292321500 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 03-Feb-05 MWD RUN 3 3 LABRECQUE D. GLADDEN MWD RUN PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE MWD RUN 2 2 S. TUFTON P. WILSON MWD RUN 5 C. WONG F. HERBERT 16 llN 10E 99.00 71.00 CASING SIZE (IN) 20.000 13.375 9.625 . . GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 18' 09.70" LONG: W149 DEG 35' 45.22" LOG MEASURED FROM D.F. AT 99.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) Baker Hughes INTEQ run 1 utilized a directional tool with Gamma Ray to drill from 108 to 3802 feet MD (108 to 2306 feet TVD) completing the 16 inch hole section. 2) Baker Hughes INTEQ run 2 utilized an Autotrak G1.5 tool along with RNT (Reservoir Navigation Tool) Resistivity, and Gamma Ray services to drill from 3802 to 5151 feet MD (2306 to 2773 feet TVD). 3) Baker Hughes INTEQ run 3 utilized a directional tool with a Multiple Propagation Resistivity (MPR) and Gamma Ray to drill from 5151 to 5850 feet MD (2773 to 3034 feet TVD) . 4) Baker Hughes INTEQ run 4 utilized an Autotrak G1.5 tool along with RNT Resistivity, and Gamma Ray to drill from 5850 to 8094 feet MD (3034 to 3606 feet TVD) . 5) Baker Hughes INTEQ run 5 utilized an Autotrak G2.5 tool along with RNT Resistivity, and Gamma Ray to drill from 8094 to 12611 feet MD (3606 to 3572 feet TVD). REMARKS : 1) Depth of 13 3/8" Casing Shoe - Driller: 3795 feet MD (2303 feet TVD) . Depth of 13 3/8" Casing Shoe - Logger: 3798 feet MD (2304 feet TVD). 2) Due to the change in Resistivity tool type on Run 3, the presentation goes from 2 curves (RPD & RPS) to 4 curves (RPD, RPM, RPS, & RPX). 3) Depth of 9 5/8" Casing Shoe - Driller: 8094 feet MD (3606 feet TVD) . Depth of 9 5/8" Casing Shoe - Logger: 8094 feet MD (3606 feet TVD). The interval from 8076 to 8094 feet MD (3603 to 3606 feet TVD) was not logged due to 9 5/8" casing. 4) The interval from 12580 to 12611 feet (3572 to 3572 feet TVD) was not logged due to sensor offsets at TD. $ Tape Subfile: 1 91 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 . . # FILE SUMMARY PBU TOOL CODE MWD $ START DEPTH 234.0 STOP DEPTH 12611.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 5 MERGE TOP 234.0 3752.0 5134.0 5802.0 8077.0 MERGE BASE 3752.0 5134.0 5802.0 8077.0 12611. 0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT le-126 5.xtf 150 ConocoPhillips Alaska, Inc. lE-126 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPCLM 0.0 RPM RPM RPCSLM 0.0 RPS RPS RPCHM 0.0 RPX RPX RPCSHM 0.0 ROP ROP ROPA 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: (F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F . 7 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 ------- 28 Total Data Records: 799 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 234.000000 12611.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 844 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 . log header data for each bit run in separate files. 1 .2500 START DEPTH 234.0 STOP DEPTH 3752.0 # 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 BOTTOM) 03-AUG-04 MSB 18704 8.5 GAM MEMORY 3802.0 234.0 3752.0 o 0.0 70.8 . VENDOR TOOL CODE DIR GRAM $ TOOL TYPE DIRECTIONAL GAMMA RAY # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: BIT RUN 1 (MWD Run 1). GR/Dir. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-126.xtf 150 ConocoPhillips Alaska, I lE-126 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAM ROPA ---------------------------------------------------- GRAM ROPA GRAM ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 . TOOL NUMBER DHA 6437 SRIG 58017 16.000 120.0 SPUD 9.10 .0 .0 200 .0 .000 .000 .000 .000 80.0 .0 .0 .0 .00 .000 .0 o . . FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRAM MWD ROPA MWD 68 68 1 1 GAPI FPHR 4 4 4 4 ------- 8 Total Data Records: 168 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 234.000000 3752.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 241 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 2 .2500 START DEPTH 3752.0 STOP DEPTH 5134.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 06-AUG-04 MSB 18704 8.5 ATK MEMORY 5151. 0 3752.0 5134.0 o 67.8 70.4 # . TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL GAMMA RAY # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . TOOL NUMBER ATK 08 20067 20067 12.250 3795.0 LSND 9.25 .0 .0 200 .0 .000 .000 .000 .000 76.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 2). GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN le-126.xtf LCC 150 CN ConocoPhillips Alaska, I WN lE-126 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes . . Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 1D: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP1 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 ROPA MWD 68 1 FPHR 4 4 5 RPTH MWD 68 1 M1NS 4 4 ------- 20 Total Data Records: 132 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3752.000000 5134.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 212 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 log header data for each bit run in separate files. 3 .2500 START DEPTH 5134.0 STOP DEPTH 5802.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 07-AUG-04 . 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 DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RES. # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . MSB 18704 8.5 MPR MEMORY 5850.0 5134.0 5802.0 o 66.2 70.8 TOOL NUMBER 6437 23579 58017 12.250 3031. 0 LSND 9.20 .0 .0 200 .0 .000 .000 .000 .000 90.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3 (MWD Run 3). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN le-126.xtf LCC 150 CN ConocoPhillips Alaska, I WN lE-126 FN Kuparuk River COUN North Slope STAT Alaska \ . . *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 87 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5134.000000 5802.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 171 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** , . !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE014.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 5 . log header data for each bit run in separate files. 4 .2500 START DEPTH 5802.0 STOP DEPTH 8077.0 # 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 DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL GAMMA RAY # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 09-AUG-04 MSB 18704 8.5 ATK MEMORY 8094.0 5802.0 8077.0 o 68.2 80.1 TOOL NUMBER ATK 23702 2058 2058 12.250 3795.0 LSND 9.25 .0 .0 200 .0 .000 .000 .000 .000 96.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2RR (MWD Run 4). GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # . . . *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1e-126.xtf 150 ConocoPhi1lips Alaska, I 1E-126 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 ROPA MWD 68 1 FPHR 4 4 5 RPTH MWD 68 1 MINS 4 4 ------- 20 Total Data Records: 217 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5802.000000 8077.000000 0.250000 feet **** FILE TRAILER **** Tape Subfi1e: 6 297 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** 't . " LDWG .006 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! !! !! ! ! ! !! ! ! ! ! ! !! Extract File: FILE015.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 6 . log header data for each bit run in separate files. 5 .2500 START DEPTH 8077.0 STOP DEPTH 12611. 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 DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL GAMMA RAY # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: if NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): if 14-AUG-04 MSB 18704 6.75 ATK MEMORY 12611. 0 8077.0 12611.0 o 80.2 94.1 TOOL NUMBER ATK 17834 20105 20105 8.500 8094.0 Oil Based 9.05 .0 .0 30000 .0 .000 .000 .000 .000 135.0 .0 .0 .0 .00 .000 .0 o " .. . . REMARKS: BIT RUN 4 (MWD Run 5). GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-126.xtf 150 ConocoPhillips Alaska, I lE-126 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 ROPA MWD 68 1 FPHR 4 4 5 RPTH MWD 68 1 MINS 4 4 ------- 20 Total Data Records: 432 Tape File Start Depth Tape File End Depth Tape File Level Spacing 8077.000000 12611.000000 0.250000 ,., . . **** FILE TRAILER **** Tape File Depth Units feet Tape Subfile: 7 512 records... Minimum record length: Maximum record length: **** TAPE TRAILER **** LDWG 05/02/03 01 **** REEL TRAILER **** LDWG 05/02/03 AWS 01 Tape Subfile: 8 Minimum record length: Maximum record length: 8 bytes 4124 bytes 2 records... 132 bytes 132 bytes