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Home My WebLink About204-091New Plugback Esets 8/13/2024 Well Name API Number PTD Number ESet Number Date 1E-28A 50-029-20832-01-00 213-095 T39403 5-15-2014 1E-112 50-029-23211-70-00 204-091 T39404 10-19-2004 3N-14APB1 50-029-21589-70-00 207-119 T39405 2-3-2009 Nikaitchuq 3 PB1 50-629-23242-70-00 205-001 T39406 5-23-2005 Nikaitchuq 3 PB2 50-629-23242-71-00 205-001 T39407 5-23-2005 Nikaitchuq 3 PB3 50-629-23242-72-00 205-001 T39408 5-23-2005 ODSK-41 PB1 50-703-20585-70-00 208-147 T39409 2-27-2009 ODSN-26 PB1 50-703-20642-70-00 211-121 T39410 2-1-2012 ODSN-26 PB2 50-703-20642-71-00 211-121 T39411 2-1-2012 ODSN-29 PB1 50-703-20661-70-00 212-106 T39412 6-12-2013 ODSN-29 PB2 50-703-20661-71-00 212-106 T39413 6-12-2013 Z-05APB1 50-029-22056-70-00 190-078 T39414 10-13-2013 1E-112 50-029-23211-70-00 204-091 T39404 10-19-2004 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-112 KUPARUK RIV U WSAK 1E-112 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-112 50-029-23211-00-00 204-091-0 W SPT 3583 2040910 1500 608 608 608 608 67 167 165 163 4YRTST P Austin McLeod 6/5/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1E-112 Inspection Date: Tubing OA Packer Depth 1030 1790 1760 1750IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605190754 BBL Pumped:1.3 BBL Returned:1.2 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:47:55 -08'00' • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 12,2018 TO: Jim R / 5/$ P.I.Super visor < <" SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1E-112 FROM: Adam Earl KUPARUK RIV U WSAK 1E-112 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK IE-112 API Well Number 50-029-23211-00-00 Inspector Name: Adam Earl Permit Number: 204-091-0 Inspection Date: 6/9/2018 Insp Num: mitAGE180611085548 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-112 Type Inj ! W TVD 3583 Tubing 340 340 340 - 340 2040910 [Type Test SPT Test psi PTD - ---- �---- p 1500 IA 1360 2200 2165 - 2160 BBL Pumped: 1.5 BBL Returned: 1.4 OA 85 193 - 191 ' 191 Interval ] 4YRTST P/F P Notes: MIT-IA SCAM JUN ,2 2 ZUR Tuesday,June 12,2018 Page 1 of 1 Fri) Z-6401tc Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> ,2¢�C� ZI Z6:f 6 Sent: Saturday, February 17, 2018 8:08 AM I ( t To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney; Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: LPP/SSV Returned to.Service on CPAI Well 1E-112 - 2/16/18 Jim, The low pressure pilot (LPP) on well 1E-112 (PTD# 204-091, 204-092, 204-093) was returned to service and removed from the "Facility Defeated Safety Device Log" on 2/16/2018. The well is currently injecting at approximately 1000 BWPD with a wellhead injection pressure of 230 psi. The LPP had been defeated on 11/12/2017 after the well was returned to service. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Sydney Autry on behalf of Mitch Autrey / Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SCANNED 1 tikt;EIVED STATE OF ALASKA DEC 1 1 2017 , ALAI OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: RPPG D MBE Trtmt U 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory ❑ 204-091 3.Address: P. O. Box 100360,Anchorage, Alaska Stratigraphic❑ Service 111 6.API Number: 99510 50-029-23211-00 7.Property Designation(Lease Number): 8.Well Name and Number: KfZU 1 E-112L2 ADL 25651.ADL 25660 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,273 feet Plugs measured 9184 feet true vertical 3,337 feet Junk measured None feet Effective Depth measured 6,200 feet Packer measured 5780,6038,6777 feet true vertical 3,485 feet true vertical 3395,3457,3582 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 20 " 108' MD 108 TVD SURFACE 3,001 feet 13 3/8" 3,031' MD 2311 TVD INTERMEDIATE 6,896 feet 9 5/8" 6,926' MD 3606 TVD LINER 5,403 feet 5 1/2" 11,242' MD 3338 TVD Perforation depth Measured depth 5902-5980,6536-11240,6834-6839,8800-8805,8997-9002 feet True Vertical depth 3424-3437,3420-3338,3403-3403,3373-3373,3370-3370 feet Tubing(size,grade,measured and true vertical depth) 4.5" L-80 5,792' MD 3,398'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=SLZXP Liner Top Packer 5,780' MD 3,395'TVD PACKER=ZXP Liner Top Packer 6,038' MD 3,457'TVD PACKER=HRD ZXP Liner Top Packer 6,777' MD 3,582'TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 2.6. a 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: - - 1063 - 65 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service U Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-403 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr.Wells Engineer Authorized Signature: tW ' • ', ,,,,L__". Date: I2/fi 1 n Contact Phone: (907)265-6471 Fnrm 10-404 Ravica7017Submit Original Only dewey KEDr �� Ev ��l'7 TL < ZL • • IE- 112L2 RPPG D MBE TREATMENT DTTMSTE JOBTYP SUMMARYOPS 11/3/17 MISC. RIH WITH 2" E-COIL GR/CCL, E-FIRE AND 5' POWERFLOW HSD CAPACITY GUN (6SPF) BHA. LOG 8849' -8400', CORRECT DEPTH TO SUSTAINMENT 8840.7' RKB. PICK UP TO 8796.7' RKB, PERFORATE FROM 8800' -8805' RKB. POOH, CONFIRM SHOTS FIRED. RDMO. JOB . 11/9/17 MISC. Performed full-bore RPPG treatment pumping 144.3 bbls of—0.75 CAPACITY ppg RPPG placing 5016#of RPPG followed by 330 lb of 0.25 ppg SUSTAINMENT crystal seal. Displaced into liner/MBE with 125 seawater and 36 bbl freeze protect. Note: Well to remain shut in until CTU cleanout. 11/11/17 PUMPING INJECTIVITY TEST TRACKING 0.5 BPM FOR 30 MIN ONLY 0.75 BPM FOR 30 MIN (JOB COMPLETE) KUP . 1 E-112 Con©caPhilhhps Well Attribu Max Angle D TD .Alaska.IncWellbore APIUWI Field Name Wellbore Status incl(°) MD(ftKB) Act Btm(ftKB) Canoco6hpgps ' 500292321100 WEST SAK INJ 93.83 7,537.96 11,425.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-112 12/7/2017 3.02 35 PM SSSV:NIPPLE 28 12/9/2004 Last WO: 31.19 7/31/2004 Vertical schemaSO(aclpall Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason:RESET ISO SLEEVE AND pproven 4/5/2017 HANGER,22.3--F"{ r 1 DIVERTER,SET IBP 8 PERF Casing Strings ii Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread t,,,,,,,.,,o,o,o,o,,0n„ai,n"'"'"oo: `II z q5 uut,CONDUCTOR _ 20 19.124 30.0 108.0 108.0 94.00 K-55 WELDED I, j ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)... Wt/Len(I...Grade Top Thread �I I SURFACE 13 3/8 12.415 29.9 3,031.0 2,310.6 68.00 L-80 BTC .q Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I.. Grade Top Thread INTERMEDIATE 9 5/8 8.697 30.0 6,926.3 3,605.6 40.00 L-80 BTC-M �n- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR;30.0-108.0 TUBING;76.3 L2 Window 9 5/8 8.000 5,844.0 5,860.0 3,415.3 40.00 L-80 NIPPLE;507.9 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread lit L1 Window 95/8 8.000 6,096.0 6,112.0 3,470.2 40.00 L-80 ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread A-SAND LINER 51/2 4.950 6,776.6 11,297.5 3,602.1 15.50 L-80 DWC Liner Details SURFACE,29.8-3,031.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) GAS LIFT;3,218.6 .16 6,776.6 3,581.6 80.46 PACKER HRD ZXP LINER TOP PACKER 6.278 � 6,795.2 3,584.6 80.53 NIPPLE 'RS'PACKOFF SEAL NIPPLE 5.963 I6,798.3 3,585.1 80.54 HANGER FLEXLOCK LINER HANGER 6.276 li 6,808.3 3,586.8 80.58 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 GAS LIFT;5,320.1 . 6,827.6 3,589.9 80.65 XO BUSHING 5.500 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)... WOLen(1...Grade Top Thread L1 LINER LEM ( 41/21 3.9581 5,780.11 6,066.91 3,462 12.601 L-80 IBT Liner Details SLEEVE;5,369.7 - Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc)(') Hem Des Com (in) 5.780.1 3,395.3 75.57 LEM L2 SLZXP LINER TOP PACKER 6.230 PACKER 1i 5,801.2 3,400.6 75.56.SBE SEAL BORE EXTENSION ASSEMBLY 4.750 LOCATOR;5,792.4 I1.1 I ii 5,830.1 3,407.8 75.54 HANGER LEM ABOVE HOOK HANGER 4.020 SEAL ASSY;5,793.5 5,837.5 3,409.7 75.54 HANGER LEM INSIDE HOOK HANGER 4.020 V6,063.6 3,461.5 79.15 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 DIVERTER;5,830.0 :°f--(r 1 Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread D-SAND LINER;5,639.4 L2 LINER LEM 41/2 3.958 6,038.4 6,822.4 3,589.1 12.60 L-80 IBT 11.241.9 l 11 Iti Liner Details Nominal ID Top(ftKB) Top(NO)(ftKB) Top Incl(°) Item Des Com (in) L2 Window,5,1344.0-5,860.06,038.4 3,456.6 78.64 LEM L1 ZXP LINER TOP PACKER 6.230 I PACKER 657.0 3,40.2 79.02 E SBE ASSEMBLY 4.750 6026.5 3,472.6 80.42 NBPPLE CAMCO'OS'NIPPLE 3.562 6,819.1 3,588.6 80.61 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Tubing Strings L1 LINER LEM;5,780.1-3086.9 Y Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/rt) Grade Top Connection TUBING 4 1/2 3.958 22.3 5,810.5 3,402.9 12.60 L-80 IBTM i Completion Details ISO Sleeve,6,085.0 {I Nominal ID e-SAND LINER;6,094.0- -,. Top(ftKB) Top(ND)(kKB) Top Incl C) Item Des Com (in) 11,252.0 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 L1 Window;6,096.06,112.0 507.9 507.8 4.23 NIPPLE CAMCO'DB-6'NO GO NIPPLE 3.958 5,369.7 3,276.3 68.03 SLEEVE BAKER CMU SLIDING SLEEVE w/CAMCO 3.81"DB 3.810 PROFILE M. 5,792.4 3,398.4 75.56 LOCATOR BAKER LOCATOR 3.880 ■ 5.793.5 3 398.7 75 56 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) III 11 III Top(TVD( Top Incl 9l Top(ftKB) (ftKB( (°) Des Com Run Date ID(in) y� ; 6,038.4 3,456.6 78.64 PLUG DB PLUG 8 PRONG 7/19/2012 0.000 7,014.0 3,616.6 84.78 Constrictor -A-SAND LINER 10 CONSTRICTOR PACKERS set 7/9/2004 5.963 PKR TO ISOLATE SHALES FROM SAND,@ 7014', L2 LINER LEM;6,036.4-9,822.4 7538',7758',8368',9074',9584',9950',10370', 10648',11215' Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com INTERMEDIATE;30.0-6,926.3 7013.0 7,514.0 3,616.6 3,610.8 WS A2,1E- 7/9/2004 40.0 SLOTS ALL PERFS IN 112 WELLBORE:Alternating solid/slotted pipe- 0.125"x2.5"@ 4 Constrictor PKR;7,014.0 - circumferential adjacent SLOTS,7,013.5-7,514.0 rows,3"centers staggered 18 deg,3'non -slotted ends 7,759.0 8,340.0 3,594.9 3,592.3 WS A2,1E- 7/9/2004 40.0 SLOTS SLOTS;7,759.0-9,340.0 112 9,074.0 9,551.0 3,581.1 3,573.5 WS A2,1E- 7/9/2004 40.0 SLOTS 112 SLOTS;9,074.0-9,551.0 9,953.0 10,346.0 3,574.8 3,586.5 WS A2,1E- '7/9/2004 40.0 SLOTS 112 10,658.0 11202.0 3,602.2 3,603.4 WS A2,1E- 7/9/2004 40.0 SLOTS 112 SLOTS;9,953.010,346.0 J L Mandrel Inserts St ati 1 r- on Top(ND) Valve Latch Port Size TRO Run SLOTS;10,658.5-71,202.0 J - N Top(ftKB) (ORB) Make Model OD(in) Sen., Type Type (in) (psi) Run Date Corn 1 3,218.6 2,400.5 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 1/6/2005 A-SAND LINER;6,776.6- 11,297.5 KUP 1E-112 , Con© Phillips 4 .Alaska,Inc, Corwica tlillips ...•• 1 E-112,12/7/2017 3:02:36 PM Velma]so0Om7Oc.Iactual) HANGER;22.3 ,,,=." ��il -Mandrel Inserts I st • C �I4 ub ua.ani II + Top(TVD) Valve Latch Port size TRO Run I NL Top(ftKB) (RKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Corn 2 5,320.1 3,257.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 8/30/2005 Notes:General&Safety -A-ti CONDUCTOR,30.0108.0 ` ~ End Date Annotation TUBING;78.3 7/30/2004 NOTE:TRI-LATERAL WELL-1E-112(UNDULATING A-SAND)1E-112L1(B-SAND)1E-112L2(D-SAND) NIPPLE;507,9 3/1/2009 NOTE:View Schematic w/Alaska Schematic9.0 II 7/28/2012 NOTE:PROFILE MODIFICATION-PUMPED 2145LBS(4MM)CRYSTAL SEAL TO D'MBE@6839 SURFACE;29.8-3,031.0 L • it GAS LIFT,3,218.8 _ . lit ft GAS LIFT,5,320.1 II SLEEVE,5,3 .7 I IitEr'.I, LOCATOR;5,792.4 I SEAL ASSY;5,793.5 is ,.x1 'AIL :IA DIVERTER;5,830.0 'I'°——j g D-SAND LINER;5,839.4 ii 7-!rf,, 11,241.9 L2 Window;5,844.05,880.0 S 1± -i Lt LINER LEM;5,780.18,088.9 14 ITB ISO Sleeve,6,085.0 B-BAND LINER;8,094.0 , 11,252.0 I LI Window;6,096.08,112.0 II 'II 11' i I as 11 L2 LINER LEM;8,038.4-6,822.4 I I INTERMEDIATE;30.08,928.3 Constrictor PKR;7,014.0 _ SLOTS;7,013.07,514.0 SLOTS;7,759.08,340.0 SLOTS;9,074.09,551.0 SLOTS;9,953.010,346.0 SLOTS;10,658.0-11,202.0 A-SAND LINER;8,778.6- 1i,297.5 ,776.6- 11,297.5 KUP 0 1E-112L2 , C_onocoPhillips 4' Well Attribu Max Angle&MD TD Alaska.,Inc, - -'.;. Wellbore APIAUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CorwcOPhdlps 500292321161 WEST SAK INJ 95.96 6,415.94 11,273.0 L ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-1122 12/020173.10.24 PMSSSV:NIPPLE 28 12/9/2004 Last WO: 31.19 7/31/2004 YerAaalwthem.7G{. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,223 m -saw Last Tag Rev Reason:PERF(8,800'-8,805') pproven 12/4/2017 . �R`i')1 . y'yaR I. ; Casing Strings CONDUCTOR'30.0-108.0 !�r� �1 Casing Description I OD(in) IID(in) I Top(ftKB) ISet Depth(ftKB) ISet Depth(ND)...IW t/Len(I...I Grade I Top Thread Jam, A9ISSI TUBING;783-� Illr D-SAND LINER 51/2 4.950 5839.4 112420 3,338.0 15.50 L-80 DWC NIPPLE;507.9 Liner Details ' - Nominal ID SURFACE;29.8-3,031.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 5,839.4 3,410.2 75.53 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.000 GAS LIFT;3,218.6 _ 7. 5,866.7 3,416.7 76.83 XO CROSSOVER 7"x 5.5" 5.000 GAS LIFT;5,320.1 �: Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl SLEEVE;5,369.7ell II Top(ftKB) (ftKB) (°I Des Com Run Date ID(in) 5,830.0 3,407.8 UMDIVERTER TYPE 2 DIVERTER IN D-LEM 2/8/2017 3.000 I ••BAKER IBP(INFLATABLE RETRIEVABLE 2/9/2017 1111 LOCATOR;5,792.4 BRIDGE PLUG) SEAL ASSY;5,830.5 DIVASST;5,733.5 I' < L1 LINER LEM;5,780.1-6,066.9 it t= t Perforations&Slots INTERMEDIATE;30.06,926.3 — 111 Shot 4&".T Dens Top ) Btm(ftKB) (ftKB) (ftKB) Zone ate ft) Type Com SLOTS;5,902.0-5,980.0 ° 1 :1 1 • 7/26/2004r 40.0 1SLOTS ALL PERFS IN 112L2 WELLBORE:Alternating lid/slotted pipe- 1• circumferential adjacent rows,3"centers staggered 18 deg,3'non RPERF;6,834.06,839.0 -slotted ends GEL SOZ;6,834.019(B 6,536 1 11,240.0 • 1E- 7/26/2004 •1 1 SLOTS 11212 WELLBORE:Alternating solid/slotted pipe- 1 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends 6,834 1 6,839 1 3,402 9 3,402.71 '11 RPERF ALL PERFS IN 112 WELLBORE:Alternating lid/slotted pipe- 1• circumferential adjacent rows,3"centers ' staggered 18 deg,3'non -slotted ends 800 0 8,805 1 3,373.1 3,373.1 WS A2,1E- 11/3/2017 •1 POWERFLOW 112 •2006FP, 1/ ti r H 9,002.0 1 1 •1 •• • (2506FP 1 a 1 I- Cement Squeezes Top(ftKB) Btin(ftKB) (ftKB) (f0(13) Des Start Date Com 1 6,8391 3,402 9 3,402 • 7/28/2012 APERF;8,800.0-8,805.0 r Notes:General&Safety SLOTS;6,536.0-11,240.0 '" e- End Date Annotation 7/30/2004 NOTE:TRI-LATERAL WELL-1E-112(UNDULATING A-SAND)1E-112L1(B-SAND)1E-112L2(D-SAND) APERF;8,997.0.9,002.0 - 11• • •1 7/28/2012 NOTE:PROFILE MODIFICATION-PUMPED 2145LBS(4MM)CRYSTAL SEAL TO'D'MBE@6839 PLUG;9,164.0 H I- t J r- 4 t- -4 [ D-SAND LINER;i,,241 11,241 4- .9\ • • hats e- (lv Regg, James B (DOA) }�t 2640910 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, November 12, 2017 11:35 AM To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt; Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI well 1E-112 on 11/12/2017 Jim, The low pressure pilot (LPP) on well 1E-112 (PTD#204-091,204-092, 204-093)was defeated today, 11/12/2017, after the well was returned to service after an extended shut-in period.The well is currently injecting at a wellhead injection pressure of 45 psi and rate of 1010 BWPD.The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Marina Krysinski / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 %AWEDaFi l.'15P v^ (N 1 P76 leo Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> �ii (17 Sent: Sunday,April 23, 2017 8:41 AM �e( I To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Jensen, Marc D; Stanley, Scott M; Sullivan, Michael; Krysinski, Marina L;Targac, Gary; Effiong, Michael Subject: LPP/SSV returned to service on well 1E-112 on 04/22/17 Jim, The low pressure pilot (LPP) on well 1E-112 (PTD# 2040910, 2040920, 2040930) was returned to service and removed from the safety defeat log on 04/22/17, after the well was shut-in following an injection profile log. The LPP had originally been defeated on 04/21/2017 when the well was restarted in preparation to log the well. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Kind Regards, Scott Stanley/ Michael Effiong West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000#497 n1638@conocophillips.com . 1 16e6t tc-I(z • )04(o'1 o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> f Sent: Saturday,April 22, 2017 5:41 PM �� 41 1 t To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr;CPF1&2 Ops Supt;Jensen, Marc D; Stanley, Scott M; Sullivan, Michael; Krysinski, Marina L;Targac, Gary; Effiong, Michael Subject: Defeated LPP/SSV on CPAI well 1E-112 on 04/21/2017 Jim, The low pressure pilot(LPP) on well 1E-112 (PTD#2040910, 2040920, 2040930) was defeated yesterday, 4/21/2017, after the well was put on water injection service in preparation for and injection profile log. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best Regards, Scott Stanley/ Michael Effiong West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000#497 n1638@conocophillips.com 1 204 oo► k • • x-15 WELL LOG TRANSMITTAL#903008383 To: Chevron January 29, 2016 Attn.: Glenn Fredrick 310 K Street, Suite 406RECEIVED Anchorage, Alaska 99501 M.K LOGGED 1 FEB 02 201b M.K.BENDER AOG O RE: Injection Profile : 1E-112 Run Date: 12/23/2015 and 12/26/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1E-112 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-23211-00 • Injection Profile LogSCOW 1 Color Log- each 50-029-23211-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ,,ct 247-4 u. e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J. 0 y.. - 0 ff 1 Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 1111111111111111111 RESCAN ~or Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: D Other:: BY: ~ Date:cr J (P / 00 Dale q J ~ I c> ro '-+ x 30 = J ~ () Date: c¡ I ~ / 0 ~ /s/ mP Project Proofing 11111111I111111111I BY: (M;;J /s/ (Y1f BY: ~ + (<6 = TOTAL PAGES /3 8' (Count does not include cover sheet) I1A P /s/ I VI- 111111111111111111I Scanning Preparation Production Scanning Stage 1 Page Count from Scanned File: I 3 Cf (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES Date: q / (PI D to NO BY: ~ /5/ MP NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: /5/ 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111I1111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page. doc K2ck l& -I( z_ Prb c,o Regg, James B (DOA) From: Patterson, Amanda [ Amanda .Patterson @conocophillips.com] Sent: Thursday, January 31, 2013 2:04 PM lI�I /l3 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; Patterson, Amanda; NSK Prod Engr Specialist Subject: FW: LPP /SSV defeated on 1E-112 on 11/14/12 Jim, The low pressure pilot (LPP) on injector 1E -112 (PTD# 204 -0910, 204 -0920, and 204 -0930) was returned to service yesterday, 1/30/2013, after a choke was installed on the well. The injection pressure is currently 923 psi and the injection rate is 625 BWPD. Please let me know if you have any questions. Thanks, Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 265 -6782 SCANNED APR 1 1 2013 Cell: (281) 796 -5044 Suzanne C On Behalf Of CPF1 Prod Engr day, November 14, 2012 11:45 AM mes B (DOA)' Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; Patterson, Amanda; NSK Prod Engr Specialist PP /SSV defeated on 1E-112 on 11/14/12 Jim: The low pressure pilot (LPP) on injector 1E -112 (PTD# 204 -0910, 204 -0920, and 204 -0930) was defeated on 11/14/2012 when the well was returned to injection service after completing a coil tubing job to remediate a matrix bypass event. The current wellhead injection pressure is 13 psi and the injection rate is 1011 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. thanks, Dana Glessner /David Lagerlef ConocoPhillips Alaska, Inc Kuparuk CPF1 Production Engineer office (907) 659 -7493 Dana.Glessner@ conocophillips.com 1 I4cut (t- /(Z. • • (�'i E.640 t'ro Regg, James B (DOA) From: Patterson, Amanda [ Amanda .Patterson @conocophillips.com] Sent: Wednesday, October 24, 2012 5:03 PM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; CPF1 Prod Engr Subject: 1E-112 Removed from SDL Jim, West injects 1E -112 (PTD 204 -091, 04 -092, 204 -093) was shut -in and removed from the safety defeat log on Oct. 24, 2012. �, The AOGCC will be notified when the injector return to service. Please let me know if you have any questions. Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 265 -6782 Cell: (281) 796 -5044 SCANNED APR 0 9 2013 • • • (e-feu 1 E- /( Regg, James B (DOA) From: Patterson, Amanda [ Amanda .Patterson @conocophillips.com] Sent: Tuesday, October 23, 2012 4:43 PM 2 � To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; CPF1 Prod Engr Subject: LPP /SSV defeated on 1E-112 Jim, The low pressure pilots (LPPs) on injector E -112 (PTD 204 -091 04 -092, 204 -093) was defeated on Oct. 13, 2012 when the well was returned to injection service to - - ua e a brea through event. Current wellhead pressure is 155 psi at an injection rate of 2228 BWPD. The LPP and SSV has been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure of each well has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO4Q6B.001." Please let me know if you have any questions. Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 265-6782 SCANNED APR 0 9 2ry � 3 Cell: (281) 798 -5044 1 ®/t Regg, James B (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Saturday, October 13, 2012 4:42 PM a l obsi I To: Regg, James B (DOA) (( Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Patterson, Amanda; Jensen, Marc D Subject: LPP /SSV Defeated for 1E-112 on 10/13/2012 Jim, The low pressure pilot (LPP) on injecto 13153=1 204 -092 L1, 204 -093 L2) was defeated on 10/13/2012 when the injection pressure ell •e ow 500 PSI after putting the well back on injection. Prior to bringing the well online, it had been shut in since 09/13/12 when another attempt to flow the producer that it communicates with had to be SI due to a process upset at CPF1. Well 1E-112 was treated in July 2012 to remediate a rapid water breakthrough to the producer. The wellhead injection pressure is currently near 0 psi and the injection rate is 1900 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. David Lagerlef /Dana Glessner CPF1 Production Engineers n1269(a�conocophillips.com 659 -7493 pager 659 -7000 765 SCANNED APR 1 7 2013 • ��1 -I�z James B DOA pm �t Regg, (DOA) From: Patterson, Amanda [ Amanda .Patterson ©conocophillips.comi r Sent: Monday, September 10, 2012 4:31 PM ' r l h I ( To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Short, Suzanne C; Hutcherson, Mark R; CPF1 Prod Engr Subject: LPP /SSV defeated on 1D-112: Sept 10, 2012 Jim, The low pressure pilot (LPP) on West Sak injector 1E -112 (PTD 204 -091, 204 -092 L1, 204 -093 L2) was defeated on 9/10/2012 when the well was brought online in water injection service. The well was shut in after a drop in WH pressure to prevent a breakthrough event. Current wellhead injection pressure is 14 psi and injection rate is 2526 bwpd. The AOGCC will be notified when the injection pressure has increased and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001 ". Please let me know if you have any questions. Thanks, Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. 0 1 Office: (907) 265 -6782 NQ L. {�4 Cell: (281) 796 -5044 1 • KZA tC - itZ PO) Z-040cito Regg, James B (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Thursday, September 06, 2012 10:18 AM To: Regg, James B (DOA) Cc: NSK West Sak Prod Engr; Patterson, Amanda; CPF1 Ops Supv; CPF1 DS Lead Techs; CPF1 &2 Ops Supt; NSK Prod Engr & Optimization Supv; NSK Problem Well Supv; NSK Prod Engr Specialist; Seitz, Brian; CPF1 Prod Engr; Jensen, Marc D Subject: LPP /SSV defeated on 1E-112, 9/6/2012 Jim, L/ / The low pressure pilot (LPP) on West Sak injector 1E -112( PTD 204 -091, 204-0921-1, 204 -093 L2) was defeated on 9/6/2012 when the well was broug in in wa injection service. The well was shut in to complete well work in an attempt to remediate rapid water breakthrough to a nearby producer. Current wellhead injection pressure is nearly 0 psi and injection rate is 2100 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log ". The AOGCC will be notified when the injection pressure has increased and the LPP /SSV function is i returned to normal, in accordance with "Administrative Approval No. CO 406B.001". Please let me know if you have any questions. thanks, Dana Glessner /David Lagerlef ConocoPhillips Alaska, Inc Kuparuk CPF1 Production Engineer SCANNER MAY 0 7 2013 office (907) 659 -7493 pager 765 Dana .Glessner(aconocophillips.com 1 • STATE OF ALASKA ALP OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r' Repair w ell r Plug Perforations r Perforate r Other l;+ MBE Seal Treatment Alter Casing r Rill Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204 - 091 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 f 50 - 029 - 23211 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651, 25660 ` 1E 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 11425 feet Plugs (measured) 6038 true vertical 3598 feet Junk (measured) None Effective Depth measured 6200 feet Packer (measured) 6777 true vertical 3485 feet (true vertucal) 3582 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108 108 SURFACE 3001 13.375 3031 2309 INTERMEDIATE 6896 9.625 6926 3606 A -SAND LINER 4521 5.5 11298 3602 5LANNIED SEP ` 8 ZW12. RECEIVED Perforation depth: Measured depth: 7013 -7514, 7759 -8340, 9074 -9551, 9953 - 10346, 10658 -11202 AUG 2 2 2012 True Vertical Depth: 3616 -3611, 3595 -3592, 3582 -3574, 3575 -3587, 3602 -3603 AOGCC Tubing (size, grade, MD, and TVD) 4.5, L -80, 5810 MD, 3403 TVD Packers & SSSV (type, MD, and TVD) PACKER - HRD ZXP LINER TOP PACKER @ 6777 MD and 3582 TVD NIPPLE - NIPPLE @ 476 MD and 476 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 6834' -6839' Treatment descriptions including volumes used and final pressure: 2145# of 4MM Mesh Crystal Seal 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service F Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ P WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -359 Contact John Peirce 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date If:. /2_111. e, -sue � 1 ` _ / RBDMS AUG 2 3 2012 . J17 /q‘(.1-/ ( Form 10 -404 Revised 11/2011 - 2,,/t_ V.2- ( t-- Submit Original Only E KUP • 1E-112 ConocoPhillips °s Well Attributes Max Angle & MD TD Alaska. Inc Wellbore API /UWI Field Name Well Status 1861 (1 MD (ftKB) Act Btm (kKB) y � 500292321100 WESTSAK INJ 93.83 7,537.96 11,4250 ` - "' Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date ••• SSSV: NIPPLE Last WO: 31.19 7/31/2004 Well ConBA: -1 E -112, 7/242012 10:10:38 AM - Schematic - Actual ° Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag Rev Reason: Set Plug, 'so Sleeve, & Diverter ninam 7/24/2012 Casin. Strings HANGER, 22 "'� Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 K - 55 WELDED ,- IP - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 133/8 12.415 29.9 3,031.0 2,303.7 68.00 L BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 95/8 8.697 30.0 6,926.3 3,603.3 40.00 L - 80 BTC - M Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd L2 Window 95/8 8.000 5,844.0 5,860.0 3,412.5 40.00 L - 80 CONDUCTOR, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 30-108 TUBING, ]fi L1 Window 95/8 8.000 6,096.0 6,112.0 3,470.2 40.00 L - 80 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd Wt A -SAND LINER 5 1/2 4.950 6,776.6 11,297.5 3,602.2 15.50 L -80 DWC M Liner Details GAS LIFT, Top Depth 2,480 (TVD) Top Inc! Noml... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 6,776.6 3,581.6 80.67 PACKER HRD ZXP LINER TOP PACKER 6.278 SURFACE, . i 6,795.2 3,584.7 80.69 NIPPLE 'RS' PACKOFF SEAL NIPPLE 5.963 30 - 3,031 GAS LIFT, 6,798.3 3,585.2 80.70 HANGER FLEXLOCK LINER HANGER 6.276 5.320 SLEEVE, 5,370 6,808.3 3,586.8 80.71 SBE 190 CASING SEAL BORE EXTENSION 4.750 LOCATOR, 5.782 6,827.6 3,589.9 80.74 XO BUSHING 5.500 SEAL ASSY, 5,793 l I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd L2 Window. L1 LEM 4 1/2 3.958 5,780.1 6,066.9 3,462.4 12.60 L-80 IBT 5,8445,860 Lt LEM, i Casing Description String 0... String ID ... Top MB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 5.7ao -6•°67 L2 LEM 4 1/2 3.958 6,038.4 6,822.4 3,589.1 12.60 L - 80 IBT L1 window, 6.0965.112 Tubing Strings L2 LEM, Tubing t Descri pi Strin 0... Strin To ID ... ftKB Set Depth f Set Depth (TVD) Strin Wt... Strin g Strin To Thrd NTERMEDATE. TUBING on I 41/2 3.958 I Top ) 22.3 5,810.5 I ) 3,402.9 12.60 L - 80 I IBTM 305,926 illli Constrictor Completion Details PKR, 7,014 Top Depth SLOTS, 7,013 -7,514 FA (TVD) ^�, (TVD) Top Intl Nomi... SLOTS, ,' Top (ftKB) (ftK(3) (1 Item Description Comment ID (in) 7.7sS � SLOTS, y ' 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 SLOTS, 9.074-9.551 SLOT , i SLOTS, ' �j 475.9 475.8 3.25 NIPPLE 3.958 9,953 - 10,346 SLIDING • 1' P • 1 SLOTS, 10858 11,202 • •' LOCATOR .:/ D -SAND LINER, 5,839-11,242 SBE • 1 Other I Top Depth 1I •/ •: PLUG 8 PRONG 1 0.000 7,014 3,616.0 84.78 Constrictor A-SAND LINER 10 CONSTRICTOR PACKERS set TO 7/9/2004 5.963 ®„ PKR • 95 1 SAND, 1 1 1 10370', 1g , Perforations & Slots B -SAND Shot LINER, Top (TVD) Btm (TVD) Dens 6,094- 11,252 �:. Top (ftKB) Btm (RKB) (ftKB) (ftKB) Zone Date (56... Type Comment 7,013 7,514 3,616.0 3,610.9 WS A2, 1E -112 7/9/2004 40.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential ( I f sr adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends _ 7,759 8,340 3,594.9 3,592.0 WS A2, 1E -112 7/9/2004 40.0 SLOTS ' = i 9,074 9,551 3,581.5 3,573.5 WS A2, 1E -112 7/9/2004 40.0 SLOTS 9,953 10,346 3,574.5 3,586.6 WS A2, 1E -112 7/9/2004 40.0 SLOTS - ! 1 - 10,658 11,202 3,602.0 3,603.4 WS A2, 1E -112 7/9/2004 40.0 SLOTS Notes: General & Safety -_ End Date Annotation 7/30/2004 NOTE: TRI- LATERAL WELL - 1E-112 (UNDULATING A -SAND) 1E -112L1 (B -SAND) 1E -112L2 (D-SAND) 3/1/2009 NOTE: View Schematic w/ Alaska Schematic9.0 li 1 II II Mandrel Details :M. _ Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run £ _ Stn Top (ftKB) (MKB) (1 Make Model (in) Sell Type Typo ON (psi) Run Date Com... 1 2,408.4 2,018.9 62.78 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0 1/6/2005 I 2 5,320.1 3,256.1 66.39 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 8/302005 I I 1 1 A -SAND LINER, 1 r 8,777 -1 LINER, TD (1E-112), 11.425 Well Work Summary DATE • SUMMARYOPS 7/17/12 Drive Coil Tubing Unit to 1 E -11 om Deadhorse and perform BOP test. • 7/18/12 Perform Fluff & Stuff down to 6,275' CTMD. Made second run to pull Type 2 Iso- Sleeve @5,826' MD (D -LEM). Freeze protected and secured well. Will return in am to set plug & Type 1 Iso- Sleeve (B- LEM) 7/19/12 Set plug in DB nipple @ 6,126' CTMD and complete second run to stab prong into plug. Will return in am to set Iso - Sleeve & Diverter. 7/20/12 Set Type 1 Iso - Sleeve @ 6,101 CTMD and set Type 2 Diverter in the D -LEM @ 5,845' CTMD. Successfully drifted back through Diverter into "D" Lateral. Well ready for Crystal Seal application. DSO notified well is ready to bring on -line. 7/28/12 PERFORATED LINER AT 6834' TO 6839' CTMD. OPENED CIRC SUB AND PUMPED 2145 POUNDS OF 4 MM MESH CRYSTAL SEAL INTO PERFORATIONS. WELL FREEZE PROTECTED. JOB COMPLETE. • • ulluE DI& AR.AsEA SEAN PARNELL, GOVERNOR y � ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Well Integrity Project Supervisor ,/b1+____________-" ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E-112 Sundry Number: 311-359 Dear Mr. Peirce: ` - ` ` ,I J I. 8 L (j j ; Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Fr Daniel T. Seamount, Jr. Chair DATED this/ day of November, 2011. Encl. TATS OF ALASKA RECEIVED ALASKA OIL ANTI S CONSERVATION COMMISSION 1 NOV 1 6 2011 APPLICATION FOR SUNDRY APPROVALSit-I 20 AAC 25.280 S. Gemaission 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r ange Approyed Program r r Suspend r Plug Perforations r Perforate r Pull Tubing r° ac 6 is ion r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing f Other:MBE Seal Treatment 17 . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Explorator r 204 -091 3. Address: 6. API Number: Stratigraphic r Service W • P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23211 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number where ownership or landownership changes: ° _ P P es: 9 Spacing Exception Required? Yes r No gro 1E • 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): 11425 . 3598 ' 6200' 3485' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108' 108' SURFACE 3001 13.375 3031' 2309' INTERMEDIATE 6896 9.625 6926' 3606' A -SAND LINER 4521 5.5 11298' 3602' Perforation Depth MD ( 7013 -7514, Perforation Depth TVD (ft): 3616 -3611, Tubing Size: Tubing Grade: Tubing MD (ft): 7759 -8340, 9074 -9551, 9953 - 10346, 10658 - 11202 3595 -3592, 3582 -3574, 3575 -3587, 3602 -3603 4.5 L -80 5811 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - HRD ZXP LINER TOP PACKER MD =6777 TVD =3582 NIPPLE MD =476 TVD =476 12. Attachments: Description Summary of Proposal l✓ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory Development J Service W 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/9/2011 Oil E Gas r WDSPL r Suspended I°` 16. Verbal Approval: Date: WINJ I v , t GINJ r WAG .�'t� Abandoned r Commission Representative: I ' GSTOR r / '� SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature Phone: 265 -6471 Date if lt 4i11 Commission Use Only Sundry Number:) k ei Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: /0 ` CI APPROVED BY ) /� Approved by: ■ mo. COMMISSIONER THE COMMISSION Date: ) , / Form 10 -403 Revise. few • NOV 17 !� (` S ubmit 'n Duplicate . i v ` O RIGINAL. 1/‘- if. .. .. -„ 4101P • 1 E -112 Conoc kp * 1 Well Attributes 1 Max Angle & MD TD Aia.s.fCa k ;e;.s ',":2S W libore API/UWI Field Name Well Status ilnel () MD (ftKB) Act Btm (ftKB( ,;',f 500292321100 J WEST SAK INJ 93.83 I l 7,537 96 11.425.0 ''' Comment H2S (ppm) (Date � Annotation End Date KB (R) Rig Release Date „ - SSSV NIPPLE 1 1 Last WO' 31.19 7/31/2004 WM cArt , Shce,neac ��I J.&:.?? 21� 2.'921 P M _ - Annotation Depth (ftKB) End Date (Annotation (Last Mod .. IEnd Date Last Tag Rev Reason Pull ISO SLV, set Type 2 ISO SLV Imosbor 1/27/2010 Casing Strings HANGER, 22-`-- _. --'" e."-• Casing Description String 0... String ID ._ Top (ftKB) Set Depth (f.. Set Depth (TVD) ... String Wt... String .. 'String Top Thrd CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 K -55 WELDED ► , Casi Desenplton String . String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ,.. String Wt... Siring - String Top Thrd - ''' ° ` - SUR FACE .. __ 133 O /8 _ 12415 299 3 2,303.7 L_80 BTC • It - Casing Deacripran String O -.. String ID .. Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt..- String ... String Top Thrd INTERME 9 5/8 8.697 30 0 6,926 3 3,603.3 40.00 L -80 BTC-M C ri De Strin 0... Stn g ID iii Top (ftKB) Set Depth ((ff...... f . Set Depth ((TVD) ...... TVD) .. String Wt... String ... String Top Thrd CONDUCTOR, :. L2 Window 9 5/8 8000 5,844.0 5860 0 3 412 -5 40.00 1.-SO 30 - 1081, C ing Description String 0... Stn g ID... Top (ftKB) Set Depth (f . Set D pth (TVD) ... String Wt... String ... String Top Thrd TUBING,75 - ' -` L7 W indow 95/8 8.000 6,096.0 6,112.0 3,470.2 40.00 L - . h( 1! Casing Description String 0... String ID .. Top (ftKB) S Depth (f... Set _ Depth (TVD) .. String Wt... String String Top Thrd lri A SAND LINER 5 1/2 4 950 6,776 6 11,297.5 3,602 2 15.50 L-80 DWC ilr Liner Details r < GAS LIFT, 2,406 IV - Top Depth (TVD) Top Intl Komi... Top (ft)(B) lam) C) Item Description Comment ID (in) 6,776.6 3,581.6 80.67 PACKER HRD ZXP LINER TOP PACKER 6.278 .. 6,795 2 3,584.7 80.69 NIPPLE 'RS' PACKOFF SEAL NIPPLE 5.963 SURFACE, ,, 6,798.3 3,585.2 80.70 HANGER FLEXLOCK LINER HANGER 6.276 30 - 3,031 - - 6,808.3 3,586 -8 80.71 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 6,827.6 3,589.9 80.74 XO BUSHING 5.500 GAS LIFT, - Casing Description String 0... String ID Top (ftKB) Set Depth (f... Set Depth (TVD) . g Wt... String String Top Thrd 5,320 L2 LEM 41/2 3958 5,738.4 6,822.4 3,589.1 4 Str 1260 L-80 IBT NW Casing Description String 0... String ID Top (ftKB) Set Depth (f Set Depth (ND) . (String Wt._ String ... String Top Thrd lir SLEEVE, 5.370 L1 LEM , 41/2 3958 5,7801 60669 34624 1260 I L80 IBT SLEEVE, OC AT82 L \ _ , Tubing Strings 7Description Tubing String O String ID ... Top (ftKB) Set Depth (f... S Depth (TVD) . (Str g Wt... String String Top Thrd SEAL A3Y, 5, SY, TUBING , 41/2 _ I 223 I 5,8105 ISO 34029 1 12.60 L-80 I IBTM L2 Wnaow I a ,,. Contpletion Details 5.8145.860 .y.. L1 LEM, Top Depth 5,780.6,067 (TVD) Top Inc' No i... L1 Window, Top (ftKB) (ftKB) (°I Item Description Comment ID (in) 5,oss - s, L2 LEEM, M. 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 _ 5,7388 ERMEDIATE.. ,822 k1 ; 475.9 475.8 3.25 NIPPLE - -- - 3.958 30 - 6,926 Constrictor 5 3 276.3 67 92 SLEEVE BAKER CMU SLIDING SLEEVE w /CAMCO 3.81" DB PROFILE 3.810 i SLOTS. 1 � 3,398 per TD ' 5,792.4 .4 LOCATOR BAKER LOCATOR 3.880 4I SLOTS, 7.013 -7,514 I 5,793.5 3,398.7 75.56 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 7,759 -8,340 -" SLOTS. Other In Hole [reline retrievable plugs, valves, pumps, fish, etc.) 9,074 -9,551 i Top De SLOTS, P th P 9,953- 10,346 ■ (TVD) Top Inc! SLOTS, Tg) (ftKB) (°) Description Comment Run Dote ID (M) 10,658 - 11,202 DSAND I 5,780 3,395.3 75.57 SLEEVE TYPE 2ISO INJECTION SLEEVE W/ SIDE PORTS 1/21/2010 2.590 LINER, : BLANKED (OAL 19') 5,839 - 11,242 __ I . 7,014 3,616.0 84.78 Constrictor A -SAND UNER 10 CONSTRICTOR PACKERS set TO 7/9/2004 5.963 PKR ISOLATE SHALES FROM SAND, @ 7014', 7538', 7758', 8368', 9074', 9584', 9950', 10370', 10648', 11215' perforations & Slots Shot Top (TVD) Bte, (TVD) Dens - n T_p_(RKB) B5979 ((ftKB) (ftKB) Zone Date (sh... Type Comment BAD LINER, 7,013 7,514 3,616.0 3,610.9 WSA2, 1E -112 7/9/2004 40.0 SLOTS ALLPERFS IN WELLBORE: 5,094 - 11,252 I .. solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends _.. ..._ .._. 7,759 8,340 3,594.9 3,592.0 WS A2, 1E -112 7/9/2004 40.0 SLOTS " " 9 074 9,551 3,581.5 3,573.5 WS A2 1E-112 7/92004 40.0 SLOTS 0953 10,346 3,574.5 3,586.6 WS A2 1E-112 7/9/2004 40.0 SLOTS • 10.658 11,202 3,602.0 3,603 4, WS A2, 1E-112 7/9/2004 40.0 SLOTS >II r _ Notes: General & Safety '------ End Date Annotation I 7/30/2004 NOTE: TRI- LATERAL WELL - 1E -112 (UNDULA I ING A -SAND) 1E -112L1 (B -SAND) 10 -112L2 (D -SAND) _ 3/1/2009 NOTE: VIEW SCHEMATIC W /Alaska Schema' c9 0 „, 11 1 Marlin. ? >G_'1:` i. 4.._, . -..r•. > . ; E�.<:,. ,,s _ I -,. Top Depth Top Pori , , _ (TVD) Ind OD Valve Latch Size TRO Run Stn - (ftKB) _ (°) Make Model fin) Sent Tyre Type (in) (pal) Run Date Can_.. 1 2,408.4 2,018.9 62.78 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 1/6/2005 I Top I =0 2 5,320.1 3,256.1 66.39 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 8/30/2005 r I - S I A-SAND ;11 . y ..., _. LINER, 6,777- 11,290 TO (1E112), - ' \.`� L m.,, 11,425 • 1E-112L2 to 1E-166L2 MBE Treatment A matrix bypass event (MBE) was identified in 1E-112L2 with an IPROF on 8/20/09 in the 'heel' / of the lateral at —7000' RKB behind 5.5" slotted liner. Most PWI appears to exiting the slotted liner at this MBE. Per this proposed procedure, the MBE will be sealed with Crystal Seal. CrystalSeal is a Halliburton product intended for treating injector wells to restore water flood sweep efficiency by remediating direct communication paths through formation to offset producers. CrystalSeal is water swellabie dehydrated crosslinked synthetic polymer gel available in various granular mesh sizes. CrystalSeal can swell to 400 times original size by absorbing water. Due to the swellability of CrystalSeal, it is used to fill highly conductive large voids or channels (MBE's) that dominate taking injection. Procedure: Coil Tubing 1) Pull Isolation Sleeve from the D LEM at 5780' MD. 2) Set a Diverter in the D LEM at 5780' MD to enable access to 1 E -112L2 lateral. r 3) RIH with BHA on 2 "coil tubing consisting from bottom to top of 5' OAL x 2.75" OD TCP Perf Gun, a 2 -1/8" OD closed Circ -Sub, and hydraulic disconnect. Park perf gun to fire 6 spf large hole charges at 6981 - 6986' RKB in the 5.5" slotted liner just above the MBE at —7000' MD. Drop ball to fire the gun, then RIH 5' with coil to spot the Circ -Sub over the perf interval. Drop ball #2 to shift Circ -Sub open, then pump Crystal Seal through the Circ -Sub and perfs to seal the MBE. Pump: a) Seawater Pad down coil. Maintain 2.0 bpm rate during treatment through Flush (step g) to monitor treating pressures at constant rate. Swap from Seawater to 2% KCI and pump, b) 2% KCI Water with 0.05 ppg CrystalSeal (will use 4 mm mesh for all stages) down coil. Each stage volume will be decided during pumping based on treating pressure seen during the stage. c) 2% KCI Water w /0.10 ppg CrystalSeal down CT, or Flush (step g) should we see screen out. d) 2% KCI Water w /0.15 ppg CrystalSeal down CT, or Flush should we see screen out. e) 2% KCI Water w /0.20 ppg CrystalSeal down CT, or Flush should we see screen out. f) 2% KCI Water w/0.25 ppg CrystalSeal down CT, or Flush should we see screen out. g) If screenout occurs, open CT x Tbg annulus to return tank, and pump 1 CT volume of Seawater Flush to displace Crystal Seal slurry from coil into well while POOH. If screenout has not been seen prior to Flush, leave CT x Tbg annulus shut -in and pump 1 full CT volume of Seawater Flush to displace Crystal Seal Slurry from coil to MBE while POOH with CT to D LEM, then swap to 53 bbls of Diesel FP down coil, followed by 1 CT volume of Diesel ( -40 bbls) to FP CT and displace Diesel FP to tubing, followed by SD. RD CTU. Wait 6 hrs before returning 1 E -112L2 to PWI for post- treatment injectivity evaluation. e Page 1 of 1 Maunder, Thomas E (DOA) From: Pierson, Chris R [Chris. R. Pierson@conocophillips.com] Sent: Tuesday, November 23, 2010 3:18 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt Subject: LPP /SSV No Longer Defeated On 1 E -112, 23- November -2010 Tom / Jim, The low pressure pilot (LPP) on IE412 (PTD 204 -091, 204 -092 L1, 204 -093 L2) is no longer defeated, as the well was shut -in at 15:06 hrs on November 23, 2010. Please let me know if you have any questions. Chris Pierson West Sak Production Engineer Conocophillips Alaska, Inc. Office: 265 -6112 Cell: 240 -5056 %A NOV 11/23/2010 MEMORANDUM To: Jim Regg ~ C5, 7,ZLli~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector Sate of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lE-1 ]2 KUPARUK RIV U WSAK 1E-112 Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 1E-112 API Well Number: 50-029-23211-00-00 Insp Num: mitRCN100628071806 permit Number: 204-091-0 Rel Insp Num: MITOP000003131 Inspector Name: Bob Noble Inspection Date: 6/24/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ ~ IE-112 , Type Inj. W TVD 3583 IA 850 1960 1960 1960 ~' P.T.D~ zoao9lo~ TypeTest SPT Test psi 1960 ~' OA ]ao zao zao zao IriteCVal Four Year Cycle p~ Pass ~ Tubing 28~ 280 280 280 Notes: Monday, July 26, 2010 Page 1 of 1 F • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~. operations Pertorrned: Abandon ^ Repair w ell ^ plug f~rforations ^ Stimulate ^ Other ,r Pull B sd Iso Slv Aker Casing ^ Pull Tubing ^ pfrrforate New Pbol Waiver Set D sd Iso Slv ^ ^ Time Extension ^ Change Approved Frogram ^ Operat Shutdown ^ Pbrforate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 204-091 3. Address: Stratigraphic ^ Service ~ .API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23211-00 7. Prope,~ty De~si~nation: ALK 25651 & 2 8. Well Name and N\mb RECEIVED 5660, ADL 469 & 470 1 E-112 9. Field/Pool(s): Dlt Kuparuk River Field /West Sak Oil Pool F E B 2 ~ Z Q 10 10. Present Well Condition Summary: Alaska Od 8 6aa Ctn. Commi Total Depth measured ~ 11425 feet Plugs (measured) None AtlChal'~~g9 true vertical ~ 3598 feet Junk (measured) None Effective Depth measured 6200 feet Packer (measured) 0 true vertical 3485 ~ feet (true vertucal) 0 Casing Length Size MD ND Burst Collapse CONDUCTOR 78 20 108 108 0 0 SURFACE 3001 13.375 3031 2309 0 0 INTERMEDIATE 6896 9.625 6926 3606 0 0 A-SAND LINER 4521 9.625 11298 3602 0 0 Perforation depth: Measured depth: 7014'-7514', 7759'-8340', 9074'-9551', 9953'-10346', 10658'-11202' True Vertical Depth: 3615'-3611', 3595'-3592', 3581'-3573', 3575'-3586', 3601'-3603' Tubing (size, grade, MD, and TVD) 4.5, L-80, 5811 MD, 3403 TVD `;~~~~~~~,~~~,~ ~~~ ~~, ~ (~~~ Packers &SSSV (type, MD, and TVD) Baker SBE Seal Assembly 5794 d, 3399' tvd SSSV= Nipple @ 476 md, 476 tvd 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1811 426 145 Subsequent to operation 1163 310 257 13. Attachments 4. Welt Class after proposed work: Copies of Logs and Surveys run Exploratory ^ Development ^ Service . Well Status after work: Oil ^ Gas ^ WDSPL Daily Report of Well Operations X GSTOR ^ WAG n GASINJ ^ WINJ C SPLUG __ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Bob Christensen/Darrell Humghrex Printed Name o D. Ch istensen Title Production Engineering Specialist Signature ~ Phone: 659-7535 Date ~~~ ~~ RBDMS FEB 2 3 ~~4Q %~ ~L . ~, ~f~ Form 10-404 Revised 7/2009 ~~ Submit Original Only lision i • 1 E-112 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/20/10 PULLED TYPE 1 ISO SLEEVE FROM B LEM @ 6086' RKB, IN PROGRESS. 01/21/10 SET TYPE 2 ISO SLEEVE @ 5780' RKB ISOLATING THE D LATERAL. TURNED WELL OVER TO DSO. JOB COMPLETE. SLEEVE INFO: (INJECTION SLEEVE W/SIDE PORTS BLANKED, 19' LONG, 3.688" OD, 2.59" ID) ,~ .-, ConocoPhillips AIaSk,l. II N~ ••• Wall ConA : -1E-tIT 127/ malic - HANGER, 22 GAS LIFT, 2.008 SURFACE, 30-3.031 GAS LIFT, 5.320 SLEEVE, 5,370 SLEEVE, 5.780 LOCATOR, 5,792 SEAL ASSY. 5,793 L2 Wintlow, 5,804-5,860 L1 LEM, . KUP 1 E-112 ell Attributes ax An le 8 MD TD Welltrora API/UWI 500292321100 Fieltl Nama WESTSAK Well Status Incl (°) MD (RKB) INJ 93.83 7,537.96 Act Btm (ftNB) 11,425.0 Comment SSSV: NIPPLE HTS (ppm) Dab Annotation End Date Last WO: KB13rtl (R) 31.19 Rig Release Deb 7/31/2004 Annotaton Last Tag Depth (ftKB) Entl Dare Annotation Rev Reason: Pull ISO SLV, set Type 2 ISO SLV Laat Mod ... Imosbor End Oats 1/27/2010 Casin Strin s Casing Deacriptlon CONDUCTOR String 0... 20 String ID .. 19.124 Top (ftNB) 30.0 Set Depth (1... 108.0 Set Depth (TVD) ... 108.0 String Wt... 94.00 String ... K-55 String Top Thrtl WELDED Casing Deacriptlon SURFACE String 0... 133/8 String ID ... 12.415 Top (RKB) 29.9 Set Depth (f... 3,031.0 Set Depth (TVD) ... 2,303.7 String Wt... 68.00 String ... L-80 String Top Thrd BTC Casing Deacriptlon INTERMEDIATE String 0... 95/8 String ID ... 8.697 Top (ftl(B) 30.0 Sat Depth (r... 6,926.3 Set Depth (TVD) ... 3,603.3 String Wt... 40.00 String ... L-80 String Top Thrd BTC-M Casing Deacriptlon L2 Window String 0... 95/8 String ID ... 8.000 Top (ffKB) 5,844.0 Set Depth (t... 5,860.0 Sel Depth (TVD) ... 3,412.5 String Wt... 40.00 Shang ... L-80 String Top Thrtl Cesing Deacriptlon L1 Window String 0... 95/8 String ID ... 8.000 Top (ttKB) 6,096.0 Set Dapm (f... 6,112.0 Set Oepm (TVD) _. 3,470.2 String Wt... 40.00 String ... L-80 String Top Thrd Caaing Deacriptlon ASAND LINER String 0... 51/2 String ID ... 4.950 Top (RKB) 6,776.6 Set Depm (r... 11,297.5 Set Depth (TVD) ... 3,602.2 String Wt... 15.50 String ... L-80 String Top Thrtl DWC Liner Details Too IrtNBI Top Depth (TVD) (RKB) ToP Incl (°) Ibm Deacriptlon Comment Nomi... ID (in) ...s~,ry uvv~opwn L2 LEM au,,,y ~... 4 1/2 uu,uy ,,... 3.958 . , vp 1,.nol 5,738.4 aa. acv.,, 1,... 6,822.4 ~~. vvy.,. I..,.r ... 3,589.1 .,.,,,,y ...... 12.60 .,.,,..y ... L-80 .......y ...r .,.... IBT Casing Deacriptlon String 0... String 10 .. . Top (ftKB) Set Depth (r... Set Depth (TVD) ... String Wt... S[ring ... String Top Thrtl L7 LEM 41/2 3.958 5,780.1 6,066.9 3,462.4 12.60 L-80 IBT Tubin Strin s Tubing Deacriptlon String 0... String ID .. . Top (ftKB) Sat Depth (t... Set Depth (TVD) ... String Wt... String ._ String Top ThrO TUBING 41/2 3.958 22.3 5.810.5 3.402.9 12.60 L-80 IBTM Top Incl LINER, 5,839-11 212 I I I A SAND I LINER, 6,]P~11,298 TD (1 E-112), 11 625 IPKR 18368' 9074H9584', 9950' S~0', 0648411215' 7758', Top (RKB) Bhn (RNB) (RKB( (RKB) Zona Dab len~~~ Type Comment 7,013 7,514 3,616.0 3,610.9 WS A2, 1E-112 7/9/2004 40.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - 0.125" 1Q.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends I. I (RKB) Incl I Op I I valve LaRh I Size TRO Run Rln Ton lftl(BI ( ) (') Make Model (Inl Serv Type Type (In) (psi) Run Deb Com... • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Saturday, January 23, 2010 3:04 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr; Pierson, Chris R; Hollar, Eric Andrew; CPF1 Ops Supv Subject: LPP/SSV defeated on 1 E-112, 23-Jan-2010 Tom /Jim, The low pressure pilot (LPP) on 1 E-112 (PTD 204-091, 204-092 L1, 204-093 L2) was defeated on 23-Jan-2010 when the well was returned to injection service. The well had been shut in since 09-Dec-2009. Current wellhead injection pressure is 334 psi; injection rate is 1275 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001 ". Please let me know if you have any questions. David Lloyd Lagerlef/Kenneth Lloyd Martin CPF1 Production Engineers n1269@conocophillips.com 659-7493 ~ ~ Ldp pager 659-7000 765 ~i~~~~ SAN 1 /25/2010 Page 1 of 1 Maunder, Thomas E (DOA) From: Hollar, Eric Andrew [Eric.A.Hollar@conocophillips.com] Sent: Wednesday, December 09, 2009 9:50 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; NSK West Sak Prod Engr; Pierson, Chris R; CPF1 Prod Engr Subject: LPP/SSV no longer defeated on 1 E-112, 09-Dec-2009 Tom /Jim, The low pressure pilot (LPP) on 1 ` -~FET2fT~f?~'f; q04-092 L1, 204-093 L2) is no longer defeated, as the well was shut in at 09:11 AM 09-Dec-2009. Please let me know if you have any questions. Eric Hollar West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-265-6525 Cell 907-748-0181 `~ ~~~1~ ~' ~ ~~ iC 12/9/2009 • ~ • s ~onoco~Phill~ps November 11, 2009 ~~~.~~~~~j' ~ ~~ `~ .~. ~ ~Q~~ Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~` Ave. Ste. 100 Anchorage, AK 99501 • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone:(907)659-7535 Faac: 659-7314 ~~~;~G~ V E~ N~V ~ ~ 2Q09 pisska Oil & Gas Cons. ~omm~~giar~ Anchorage ~`+-°~~ Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has pulled the "D" sand blanking sleeve and set a"B" sand blanking sleeve in the a Lateral Entry Module (LEM) of a West Sak multilateral injection well. Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. for 1 E-112 (PTD 204-091), 1 E-112L 1(PTD 204-092) and 1 E-112L2 (PTD 204-093). This report records the pulling of the D-LEM isolation in the L2lateral and setting of the B-LEM isolation sleeve in the L1 lateral water injection well. If you have any questions regarding this matter, please contact myself or Darrell Humphrey at 659-7535. Sincerely, ---_ 4 --- ~-~, --_----._ Robert D. Christensen Attachments ~ ~ • ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~. operations Performed: Abandon ^ Repair Well ^ Piug Perforations ~ Stimulate ^ Other ^/ Pulled D sand Iso Sieeve, Set B Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ sand Iso Steeve Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: `~5. Permit to Drill Number: ConocoPhillips Alaska, It1C. Development ^ Exploratory ^ 204-091 3. Address: Stratigraphic ^ Service Q API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23211-00 . KB Eleva 'o (ft): / Well Name and Number: ~ ,9s 1 E-112 Property Designation: . Field/Pool(s): ALK 25651 & 25660, ADL 469 & 470 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured `~ 11425' feet true vertical ~ 3598' feet Plugs (measured) B Iso Slv @ 6094' Effective Depth measured 62'00' feet Junk (measured) true vertical 3485' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2936' 13-3/8" 3031' 2309' INTERMEDIATE 6831' 9-5/8" 6926' 3606' A-SANOSLOTTEDLINER 4520' 5-1/2" 11297' 3602' ~~~~~~~ ~ov ~ ~ 2~a~ Perforation depth: Measured depth: 7014'-7514', 7759'-8340', 9074'-9551', 9953'-10346', 10658'-11202' 36Q3'~~~a ~~~ ~~$S ~OTIS. G0~I1(111$SIQn t rti l d th 3601' 3615' 3611' 3595' 2' 81' 3573' 357 3586' ' rue ve ca ep : - - , -359 , 35 - , , 5 - A~r~h~rap~ Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6822' MD. o ~ /i'iz.a y F ~al Packers & SSSV (type & measured depth) PKR = ZXP ~iner Top Packers KR= 5780' 6038', 6777', and 10 constrictor packers to isolate shales SSSV= NIP SSSV= 508' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1569 715 140 Subsequent to operation 1616 769 1 14. Attachments . Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ Daity Report of Well Operations _X 6. Well Status after proposed work: ~ il^ 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 / Darrell Humphrey Printed Name Robert D.christensen Title Production Engineering Specialist Signature Phone 659-7535 Date Form 10-404 Revised 04/20Q4 ~~+~+~ N~~ 1 3•20~9 ~ 7// `~/z ~~J Submit Original Only '!~~ ( . - ~ ~ ~ 1 E-112 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/25/09 ~i[~I~~~L~~] PULLED TYPE 2 ISO SLEEVE FROM D-LEM @ 5835 CTMD, PULLED TYPE 1 DIVERTOR FROM B-LEM @ 6105, ATTEMPT TO RUN TYPE 1 ISO SLEEVE FOR B-LEM, UNABLE TO PASS THROUGH D-LEM @ 5835 CTMD, SENT ISO BACK TO BAKER FOR FURTHER INSPECTIONS, RTN IN A.M. TO ISOLATE B-LATERAL. WELL IS FREEZE PROTECTED. SET TYPE 1 ISO SLEEVE tN B-LEM Cc~ 6125 CTMD, TURNED WELL OVER TO DSO, JOB COMPLETE. ~ ,! • • ~ ~ s Conocc~~iil~ps Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 '~~~~IVEQ October 13, 2009 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 ~'~,~~~~r I~v ~~ ~ ~ ~~~~ ~CT ~ 5 2QQ9 ~Ia~~a Qii ~ Gas Cnns. Corrr~nnission Anchorage , Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has set a blanking sleeve in the a Lateral Entry Module (LEM) of a West Sak multilateral injection well. Enclosed you wi find 10-404 Re ort of Sundry Well Operation for ConocoPhillips Alaska, Inc. fo 1E-112 (PTD 204-091) d 1E-112L2 (PTD 204-093). This report records the setting o t e D-LEM iso ation sleeve in the L2lateral water injection well. If you have any questions regarding this matter, please contact myself at 659-7535. Sincerely, Robert D. Christensen Attachments ~ ~ ~ ~~~G~ Y ~D ~ ~c~ ~ ~ zao~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~~ ~~~ ~~~~ ~a~S. CO(11(~11SSIOf1 REPORT OF SUNDRY WELL OPERATIONS Anchorag8 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other ~^ Set D sand Alter Casin Pull Tubin Perforate New Pool ~ Waiver ~ isolation Sleeve g ^ g ^ ^ Time Extension Change Approved Program ^ Operat. Shutdown^ PerForate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: ~Permit to Drill Number: ConocoPhillips Alaska, 111C. Development ^ Exploratory ^ 204-091 3. Address: Stratigraphic ^ Service ~^ "'~. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23211-00 7. KB Elevation (ft): `°~~ Well Name and Number: RKB 95' 1 E-112 ~roperty De~gnation: 10. Field/Pool(s): A K 25651 & 25660, ADL 469 & 470 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured ~~ 11425' feet ~ true vertical 3598' feet Plugs (measured) Effective Depth measured 6200' feet Junk (measured) true vertical 3485' feet Casing Length Size MD ND Burst Collapse Structuraf . CONDUCTOR 108' 20" 108' 108' SURFACE 2936' 13-3/8" 3031' 2309' INTERMEDIATE 6831' 9-5/8" 6926' 3606' A-SANDSLOTfEDLINER 4520~ rJ~~~2~~ 11297' 3602~ PerForation depth: Measured depth: 7014'-751~4', 7759'-8340', 9074'-9551', 9953'-10346', 10658'-11202' true vertical depth: 3615'-3611', 3595'-3592', 3581'-3573', 3575'-3586', 3601'-3603' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6822' MD. ?o~ PR'K Packers & SSSV (type & measured depth) PKR = ZXP Liner Top Packers KR= 5780' 6038', 6777', and 10 constrictor packers to isolate shales SSSV= NIP SSSV= 508' 12. Stimulation or cement squeeze summary: Intervais treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 117 734 Subsequent to operation 1370 574 1 14. Attachments . Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of m nowledge. Sundry Number or N/A if C.O. Exempt N/A contact Bob Christensen / DarreU Humphrey Printed Name o D.c ri nsen Title Production Engineering Specialist Signature Phone 659-7535 Date ~~ ~ ~" ~,~ ~ ~~-s ~~ ~ 1 ~~~ ~ ~ fa.~~.o~ Form 10-404 Revised 04/2004 ~ ~ Submit Original Only • ~ 1 E-112 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/28/09 PULLED TYPE 2 DIVERTOR FROM D-LEM @ 5847 CTMD, INSTALLED TYPE 2 ISO SLEEVE IN D-LEM @ 5847 CTMD, WELL IS FREEZE PROTECTED, TURNED OVER TO DSO. 3- ~ . Tubing SVing 4-1/2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 507' MD - DB Nipple, 3.875" Profile 13-3/8" \ Casing Shoe, 68#, L-80, BTC set @ 3,031' MD, 2,309' ND 5,780' MD - 7" X 9-5/8" ZXP Liner Top Packer 5,835' MD - 7" X 9-5/8" ~ 'B-1' HOOK Hanaer 6,038' MD - 7" X 9-5/8" Liner Top Packer A em I 7" X 95/8" ZXP Liner Top Patker with Hold Downs 7.500" Tieback Ext. ID 6.278" Tool Botly ID ~~ Casing Sealbore RecepSacle 6.75" ID, 5.75" OD 15' Length I~ Tubing Swivel, 47/2" ~ Orienting Profile Automatic Aliynment of LEM Positive Latchiny CoINt Indiwtes Corrett Location ~ Seal Bore tor Lateral ~ Isolation - 3.68" ID Access W intlow I, Positive Latenl Access va ~ Thru-Tubing Diverter Seal Bore for Lataral Isolation - 3.68" ID ~ IsoWtion Seal Asembly 4.75" Seal OD 3.875" Seal ID ~2' LenQth 2,400' MD - GLM, Camco 1" KBG-2 5,320' MD - GLM, Camco 1" KBG-2 5,369' MD - CMU Sliding Sleeve, wl 3.81" DB Profile 5,803' MD - Casing Sealbore Receptacle ConocoPhillips West Sak 9-5/8" Injector 1 E-112 Tri-Lateral Completion s,aso' MD - Lateral Entry Mctdule (LEM) 'D' Sand Lateral D-sand Casing Exit / at 5,841' MD , 5-1/2" 15.5#, L-80 Slotted Liner 6,058' MD - Casing Sealbore Receptacle 6,094' MD - 7" X 9-5/8" ~ 'B-1' HOOK Hanaer 5-1/2" Casing Shoe,15.5#, L-80 DWC Set ~ 11,238' MD 6,086' MD - Lateral Entry ' Module (LEM) Bsand Casing Exit at 6,095', 85 deg inclination 6,126' MD - 3.562" DB Nipple 5-112" Casing Shoe, 15.5#, L-80 DWC Set @ 11,253' MD r~ x ss~s~~ zxP ~ 'A' Sand Undulating Lateral Liner Top Packer 7" X 9-5/8" Liner Hanger / Packer Flex Lock 5-1/2" 15.5#, L-80 Assembly Liner Hanger Slotte Liner 5-1/2" CdSln ShOe, set ~ 6,776' MD 9 6,807' MD - Casing Sealbore 15.5#, L-80 DWC Receptacle Set @ 11,296' MD Confidential 9.~~8~~ Casing Shoe, e,~« Huon.c =oos. nu: a«~~i ~y oa n. r.Proa~w or a~:me~nea, i~ wnaa or io p~n, m,~y rorm o~ 40.0# L-80 BTC °xp T""` C e1Mrvnleormee~anlW,Ineludln MoCO p,orbyanylnlomutlonstoraq~ ~ 7E-11t-TflaalcrdCompl~Ilon-In~MOr ~~Y~~. ow~ P~~o.,KOb~~ Set ~ 6 926' MD a.,~,a.: M,..~~ a d Mrlwal systam now Imown or MrsaMr Inv~nlaA, wtt~out wrltten parmission frwn 9atar Huph~s Inc. ~ ~~ Marc D. Kuek 'B' Sand Lateral Final As Completed X~ ES Baker Oil Tools Lateral Ent W~h Divert ry Module (LEM) ers and Isolation Lateral Accros Diverter Lateral Isdation DiverOer GS Runnlnp Tool String Inst alletl Inshllad 'GS' Profile tw CoilConnecMr `Running/Retrievingti (1.00' Length) Snap In/Snap Out rBackPressureValve fP~~n~eLOCatlng~ (1.60' Length) Cdlet Lateral IaolaEOn ~' ~ Fbw-Thru Swivel ~ys ~1.25 Length~ J ~ral DiverOar Hydnulic Ramp Diuonnect ' IsolatlaJ Mainbore~ (7.50 Length) Dlvarter Sleave ~~ GS Spear ry.so~ Lenpm) ~~ umral ~sowtlon s ~ e.as n npPmz. ou• . . •Ja~a may be raquiretl in highly deviated or tleep applications (6' approx length). ~ 15.5#, L-80 Slotted Liner • • ~ .~ . .-, Cor~ocoPhillips Alaska, lix; ... we HANGER,22 - CONOUCTOR, ~.1 ~ NIPPLE,I6 SURFACE, 30-3 031 GAS LIFT. 3.319 SLEEVE, L2 KUP i 1 E-112 dlboreAPllUWI FIeltlName -- We1lShtu~ Incl~°) MD~ftKB~ ActBtm~ftl(B) 500292321100 WEST SAK INJ 93.83 7,537.96 11,425.0 menl N2S (ppm) Dam Mnotatbn EnG Data NBl3ra (ft) Rig Releasa DaD SV: NIPPLE Last WO: 37.19 7/31/2004 notatlon OepM (HKB) Entl DaOe Mnotatlon Last Motl ey End Date st Tag Rev Reason: Pull Diverter, Set ISO SLV in L2 Imosbor 9/30/2009 astn Strin s eing Oescripdon String 0... String ID . .. Top ~(tNB) Set Deptll (f... Set Depth ~TVD) ... String Wt... String ... String Top ThrE )NDUCTOR 20 19.124 30.0 108.0 108.0 94.00 K-55 WELDED sing Dascrlptlon IRFACE String 0... 133/8 String ID . 12.415 .. Top ~HKB) 29.8 Set Oepth (f... 3,031.0 Set Depth ~TVD) ... 2,303.7 5tring Wt.. 68.00 String ... L-80 String Top Thrd BTC sing Descriptlon String 0... String ID ... Top (ftKB) Sel Uep[h (f... Sat Oept~ ~TVD~ ... String Wt... String ... String Top Thrd ~ERMEDIATE 95~8 8.697 29.7 6,926.0 3,603.3 40.00 L-80 BTC-M ~Ing ~eecriptlon String 0... Strinp ID . .. Top (ftKB) Set ~epth (/... Set Oepth (TVD) ... String Wt... String ._ Strlnp Top T~rtl Wndow 95l8 8.000 5,844.0 5,860.0 3,412.5 40.00 L-80 ~Ing Oencrlptlon S[ring 0... String ID ... Top (W(B) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd Wndow 95~8 8.000 6,096.0 6,112.0 3,470.2 40.00 L-80 sing Descriptlon String 0... 5tring ID , .. T op (ttNB) Sat Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd >AND LINER 5 1/2 4.950 6,776.6 11,297.5 3,6022 15.50 L-80 DWC ner Details rop oePm a ~MKB) ~rvo~ (nNB) rop i~oi (°) ~~m Descriotion Comment lo tin Li LEM 4 1/2 3.958 5,738.4 6,822.4 3,589.1 12.60 L-80 IBT Casing De~eriptlon L2 LEM String 0... 4 1/2 String 10 ... T 3.958 op (FiKe) 5,780.1 Set DepM ~f.,. 6,066.9 Set Deplh ~TV~) ... 3,462.4 String Wt... 12.60 S[nng ... L-80 String Top T~rtl IBT Tubin Strin s Tubing Deacriptlon TUBING Slring 0... 4 7/2 String ID ... T 3.958 op (ftNB) 22.3 Set Daplh ~/... 5,810.5 Set Oepth (TVO) ... 3,402.9 Slring Wt... 12.60 String ... L-80 String Top ThrA IBTM Com letion Det alls 7op Oeptll ~TVO) Top Incl PKR ISOLATE SHALES FROM SAND, @ 7014', 7538', 7758', 8368', 9074', 9584', 9950', 10370', 10648', 11215' BLSNER Perforatlons & Slots 6,~9d-17 752 Shot Top ~TVD) 0im (TVO) Dens Top ((tNB) Btm I«KB~ (RNB) (RNB) Zona Date (a~~~~ Tvoe ID ing solid~slotted pipe- 2.5" @ 4 drcumferentlal t rows, 3" centers staggered 3' non-slotted eMs I I ^ A-SANO I I LINER, 8,777.71,299 ~ TOI1E-112). n ezs IStn ITop ~ttl(B) I I KBI I'1°) I Make I Motlel I O/ I Serv I Type I Typa I 1~^I ITR~ lun I Run D.ts I Com.._ I LPP/SSV defeated on 1E-112, 30-Sep-20Q9 Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) From: Hollar, Eric Andrew [Eric.A.Hollar@conocophillips.com] Sent: Wednesday, September 30, 2009 8:58 AM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr; Pierson, Chris R; CPF1 Prod Engr Subject: LPP/SSV defeated on 1 E-112, 30-Sep-2009 Tom / Jim, Th~ low pressure pilot (LPP) on 1E-112 (PTb 204-091, 204-092 L1, 204-093 L2) was defeated on 30-Sep-2009 when the welt was returned to injection senrice. The well had been shut in since 27-Aug-2009. Current wellhead injection pressure is 332 psi; injection rate is 466 bwpd. The LRP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The AOGCC will be notifred when the injection pressure has increased to above 50p psi and the LPP/SSV function is retumed to normal, in accordance with "Administrative Approval No. CO 406B.001 ". Please let me know if you have any questions. Eric Hollar West Sak Production Engineer CanocoPhillips Alaska, Inc. Phone 907-265-6525 Cell 907-748-0181 ~~ ~ ~` ~~os- 11 /1 Q/2009 ~:~+~~~~'.~ , :`~ ~ :~ ~ 2~w;:; LPP/SSV no longer defeated on 1E-112 - 28-AUG-09 Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Friday, August 28, 2009 4:15 PM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Welt Supv; Jenkins, Lubbie Allen; Gangt, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr; Pierson, Chris R Subject: LPP/SSV no longer defeated on 1 E-112 - 28-AUG-09 Tom ! Jim, The low pressure pilot (LPP) on 1E-112 (PTD 204-091) was returned to service on 8/28/2009 when the well was shut in for reservoir management purposes. Please !et me know if you have any questions. David Lloyd Lagerlef/Kenneth Lloyd Martin CPF1 Production Engineers n 1269@conocophillips.com 659-7493 pager 659-7000 765 ~~{~ 'ti i ,y ~~~; 5.`~r.brt'i .= ~~ f F ~.. °'~ t ~ `5 ~ K. 8/31 /2009 Conoco~illips August 21, 2008 Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-b9 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 AUG 2 6 20~~ Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, Alaska Oil & Gas Cons. lprnissiolr Anchorage a.~a~' ConocoPhillips Alaska, Inc. has removed a blanking sleeve in the Lateral Entry Module (LEM) of a West Sak multilateral injection well. Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. for 1 E-112, 1 E-112L 1. This report records the removal of the LEM isolation sleeve in the L1 lateral water injection well. If you have any questions regarding this matter, please contact myself at 659-7535. Sincerely, __~ ~Qi) ,~~ _.~ __ Robert D. Christensen Attachments ~~~~CL.J .~ au~ 2 s 2oa~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AldSICa (319 ~ CaS ~OI1S. CammiSSian REPORT OF SUNDRY WELL OPERATIONS AncnnranP 1.Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Remove 1- Isolation Sleeve Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ . Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Dri11 Number: COnOCOPhillips Alaska, InC. Development ^ Exploratory. ^ 204-091 i 3. Address: 8tratigraphic ^ Service^ 6. API Number: P. O. Box 100360, Anchorage, Alaska .99510 50-029-23211-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 95' 1 E-112 - 8. Property Designation: 10. Field/Pool(s): ALK 25651•& 25660, ADL 469 & 470 Kuparuk River Field /West Sak OiI Pool 11. Present Well Condition Summary: Total Depth measured 11425' ' feet true vertical 3598' feet ~ Plugs (measured) Effective Depth measured 6200' feet Junk (measured) true vertical 3485' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2936' 13-3/8" 3031' 2309' INTERMEDIATE 6831' 9-5/8" 6926' 3606' A-SAND SLOTTE 4520' S-1/2" 11297' 3602' Perforation depth: Measured depth: 7014'-7514', 7759'-8340', 9074'-9551', 9953'-10346', 10658'-11202' true vertical depth: 3615'-3611', 3595'-3592', 3581'-3573', 3575'-3586', 3601'-3603' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6822' MD. Packers &SSSV (type & measured depth) PKR = ZXP Liner Top Packers PKR= 5780', 6038', 6777', and 10 constrictor packers to isolate shales SSSV=NIP SSSV= 508' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ' Treatment descriptions including volumes used and final pre: 13. Representative Daily verage Producti nor Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 701 854 1529 Subsequent to operation 480 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ Sundry Number or N/A if C.O. Exempt: N/A Contact Bob"Christensen /Vacant Printed Name ,~ F~obert D.christensen ~, Title Production Engineering Technician Signature -,~ `~_ ,~~-<Lv'L-~....~... _.. _. Phone 659-7535 Date ~/Jv~ 1 ~~ ~"~~~~ Form 10-404 Revised 04/200 Submit Ori ' ~~~ 1 E-112 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/04/08 08/06/08 RIH WITH 2-3/8" CTC, CV, U/D JARS, DC & 4" G.S. LATCH ISO SLEEVE @ 6114' CTMD, POOH. LAY DOWN ISO SLEEVE & 4" GS, P/U 3.5" HYD. OVERSHOT FOR E-LINE STRING. RIH CHASING FISH DOWN TO 9245' TAGGED UP: P/U 200' RIH TAGGED UP @ 9225', SAT DOWN 5 K, POOH. FISH @ SURFACE, SPACE OUT -TRAP TOOL IN HANGING FLANGE & LOWER SWAB - CLOSE UPPER SWAB. WELL SECURE. NOTE: TOOL IS STRADDLE ACROSS LOWER SWAB & MASTER VALVE. E-LINE FISHING NECK LOOKING UP, TOTAL LENGHT 68.7' PULLED 68' E-LINE TOOLSTRING FISH. LEFT BOTTOM HALF OF CENTRALIZER CAGE IN HOLE. RAN 3.69" LIB TO 5798' SLM. NO INDICATION OF REMAINING FISH. WELL LEFT SHUT-IN PENDING PLAN FORWARD. • ConocoP h~~lips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 ~~N~~ AUG :~ 2D08 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: R~CE~~E~ AUG 2 5 2008 Alaska Oil & Gas Cons. Cam~;,.;,ion Anchor~ga q~ ~. Enclosed please find 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. ,r The corrosion inhibitor/sealant was pumped August 2-17, 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. Sincerely, Perry Kle ~ ~ Z ~r~ ~ ConocoPhillips We11 Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Dat e 8/17/2008 Well Name PTD # Initial top of cement ft Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant dat bbls ft 2H-05 185-168 SF / al 2H-17 200-019 6" N A SF N/A 5.10 8/2/2007 2K-27 201-169 10" N/A 6" " N/A 1.27 8/2/2007 2M-03 191-141 16" N/R 10 N/A 8.92 8/2/2007 1B-14 194-030 SF N/A 16" N/A 2.13 8/2/2007 1 B-18 194-061 9" N/A SF N/A 1.70 8/13/2008 18-19 194-064 SF N/A 9" N/A 8.07 8/13/2008 1 B-20 203-115 21" N/A SF " N/A 5.10 8/13/2008 1 B-101 203-133 3" N/A 21 N/A 5.95 8/13/2008 16-102 203-122 4" N/A 3" N/A 1.00 8/17/2008 1Y-05 183-087 6" N/A 4" " N/A 1.00 8/17/2008 1 Y-07 183-068 6" N/A 6 N/A 1.27 8/13/2008 1Y-17 193-068 SF N/A 6" N/A 1.27 8/13/2008 1Y-22 193-070 SF N/A SF N/A 1.27 8/13/2008 1Y-26a 188-116 SF N/A SF N/A 2.12 8/13/2008 1Y-30 188-090 SF N/A SF N/A 3.83 8/13/2008 1 E-112 1 E-119 204-091 204-031 14" 14" N/A N/A SF 14" N/A N/A 3.83 5.95 8/13/2008 8/17/2008 1 E-121 204-246 6" N/A 14" N/A 4.67 8/17/2008 1E-123 204-074 5" N/A 6" " N/A 1.00 8/17/2008 N/A 5 N/A 1.00 8/17/2008 FW: LPP/SSV defeated on 1E-112 - 28-JLTLY-0~ Page 1 of 1 ~ • Maunder, Thomas E (DQA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Tuesday, July 28, 2009 8:21 PM To: Regg, James B(DOAj; Maunder, Thomas E(DOA) Cc: CPF1 DS l.ead Techs; CPF1 Prod Supt; NSK Problem Well Supv; Jenkins, Lubbie Ailen; Gangl, Melissa A; NSK West Sak Prod Engr; NSK Prod Engr 8~ Optimization Supv Subject: FW: LPP/SSV defeated on 1 E-112 - 28-JULY-09 Tom / Jim, The low pressure pilot (LPP) on 1 E-112 (PTD 204-091) was defeated today, 7/28/2009 when the well was returned to service after being shut in a year ago, 7/27/08, for reservoir management. The well is currently injecting "on a vacuum", unable ta support a eolumn of water, and injection rate is 1000 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC witl be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001". Kenneth Uoyd Kenneth Lloyd Martin/David Lloyd Lagerlef Prod. Eng. Regional Advisor/Staff Engineer CPF1 Production Engineers Kuparuk River Unit Phone: (907j 659-7493 Voice Page: 659-7000 pager # 765 ~~~~~~' ~` ~' `' ~~ ~ ~~'~~, ~~ ... ~ ~~ ~~ 11/10/2009 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~ ~--. tip; ,~ AUu ~ ~. 200 Log Description N0.4803 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 08/06/08 1A-22 12097412 GLS 1 - ~ 07/22/08 1 1 2G-04 12096519 PROD PROFILE - 07/23!08 1 1 1A-22 12097413 PROD PROFILE - ~ 07!23/08 1 1 1A-28 11996647 PROD PROFILE - 07/24/08 1 1 1A-25 11996648 a PROD PROFILE % 07/25/08 1 1 2A-08 11996649 INJECTION PROFILE 07/26/08 1 1 1 E-112 12080408 INJECTION PROFILE 07/27/08 1 1 2W-05 12080409 INJECTION PROFILE ` 07/28/08 1 1 3J-10 12097408 SBHP SURVEY 07/20/08 1 1 3M-28 12097411 SBHP SURVEY L - Q ( 07/21/08 1 1 1 L-15 11982443 PROD PROFILE .a ~ 07/06/08 1 1 30-08A 12080407 SBHP SURVEY zC, iq'}- l93 ~ (p'~-(o 07/26/08 1 1 30-09 12080406 SBHP SURVEY /~°~-(~~ 07/26/08 1 1 1 L-24 11978468 PRODUCTION PROFILE f 07/26/08 1 1 1 F-17 12080410 PRODUCTION PROFILE 4( ~ (p 07/29/08 1 1 30-11 12100430 SBHP SURVEY -p~ 07/31/08 1 1 2M-06 12100433 INJECTION PROFILE 08/02/08 1 1 1 H-~+., Q`!f 12100434 INJECTION PROFILE v'S.C / '~ {0 08/03/08 1 1 UGNU DS2-OBI 11996650 TEMPERATURE LOG , 07/27/08 1 1 2X-14 12100432 LDL 6 08/01/08 1 1 i F-20 12100435 PRODUCTION P OFILE / 08!04/08 1 1 1H-09 12100436 INJECTION PROFILE U 08/05/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~ LPP/SSV returned to service on 1J-136 and 1E-112 • Fage 1 of 2 • AAaunder, Thomas E (DOA) From: NSK West Sak Prod Engr (n1638@conocophillips.com} Sent: Monday, Apri! 21, 2008 4:19 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Ce: NSK Prod Engr Tech; CPF1 Prod Supt; CPF1 DS Lead Techs; NSK West Sak Prod Engr; Pierson, Chris R; Jenkins, Lubbie Allen; Targac, Gary Subject: LPP/SSV retumed to service on 1J-136 and 1E-112 Tom/Jim, The LPP/SSV function was returned to normal on 1J-138 (PTD # 20&154, 206-155) on 4121/08. The welt is currently injecting 1525 bwpd at 623 psi wellhead pressure. Also, the LPP/SSV function was retumed to normal on 1E-112 (PTD 204-091204-092, 204-093) on 4121/08. The well is currently injecting 1772 bwpd at 552 psi wellhead pressure. Please let me know if you have any questions. Regards, ~(~~~y AF'R ~ ~ 200 Hai Hunt From: NSK West Sak Prod Engr Sent: Saturday, April 12, 2~8 9:29 AM To: NSK West Sak Prod Engr; tom.maunder@alaska.god; 'jim_regg~admin.state.ak.us' Cc: NSK Prod Engr Tech; Rodgers, James T; CPF3 Prod Supt; Allsup-Drake, Sharon K; CPF3 DS Lead Techs; NSK Problem Wett Supv; Pierson, Chris R Subject: LPP/SSV retvmed to service on 1J-156. LPP/SSV defeated on 1J-136. Tom 1 Jim, The LPP/SSV function was returned to normal on 1J-156 (PTD # 206-067, 206-068, 206-069) on 4/10/08. The well is currently injecting 17$2 bwpd at 554 psi wellhead pressure. The LPP/SSV on 1J-136 (PTD # 206-154, 206-155) was defeated 4/11/08 when the well was returned to production after a ~1 month shut in period (rig workover on an adjacent well). The LPP and SSV have been tagged and are recorded in the "Facility Defeated Safety Device Log." The well is currently injecting 1458 bwpd at 451 psi wellhead pressure. Judging by the current wellhead pressure trend, 1 expect we will be able to return the LPP/SSV to service in ~1 week. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Please let me know if you have any questions. Regards, Hai Hunt 4/21 /2008 LPP/SSV returned to service on 1J-136 and 1E-112 • Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com From: NSK West Sak Prod Engr Sent: Saturday, April 12, 2008 5:24 PM To: NSK West Sak Prod Engr, `Maunder, Thomas E (DOA); tiim.regg~alaska.gov' CC: ~Fi DS lead Techs; CPFi Prod Supt; Rodgers, James T Swbject: I.PP/SSV defeated on 1E-112 Tom /Jim, Page 2 of 2 I believe Eric or I sent you a note about 1 E-112 LPP/SSV being defeated on 1 /8!2008. Since that email, the well has been mostly offline (~13 injection days tots!). We brought the well bacfc online today and anticipate we will leave it on injection far a longer period of time. The purpose of this email is to let you know that we are back in the same boat we were in on 1/8/2008 and the LPP/SSV is again defeated. The low pressure pilot (LPP) on 1E-112 (PTD 204-091, 204-092, 204-093) was defeated on 4/12/2008 when the well was retumed to service after being shut in over a month. Current wellhead pressure is 41 psi; injection rate is 1793 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facitify Defeated Safety Device Log." It may be a few weeks before the wellhead pressure builds back up to the point that the LPPs can be retumed to service. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4(~BA01." Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 559-7749 Email: n1638@ConocoPhiilips.com ~/21/2oas Conoco~Phillips April 14, 2007 Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 ~EVEI Y ~~ Tom Maunder, P.E. APR 1 6 2Q0$ Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 AIB'S~a ~ & Gas Cons. Canmis~orl Anchorage Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has set blanking sleeves in the Lateral Entry Modules (LEM) of two West Sak multilateral injection wells. Enclosed you will find 10-404 Reports of Sundry Well Operation for ConocoPhillips Alaska, Inc. for 1 E-112, 1 E-112L 1, .These reports record the setting of an LEM isolation sleeve in the L1 lateral for each of these two water injection wells. If you have any questions regarding this matter, please contact myself or Robert Christensen at 659-7535. Sincerely, ~ ~~ Robert W. Buchholz ~~N~ APR ~ 5 2Da8 Attachments APR 1 6 2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI(~,~(a OtI & Gas COnS. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other a et l1- M , Isolation Sleeve Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 204-091 ' 3. Address: Strati ra hic g p ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23211-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 95' 1 E-112 8. Property Designation: 10. Field/Pool(s): ALK 25651 & 25660, ADL 469 & 470 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11425' feet true vertical 3598' - feet Plugs (measured) Effective Depth measured 6200' feet Junk (measured) true vertical 3485' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2936' 13-3/8" 3031' 2309' INTERMEDIATE 6831' 9-5/8" 6926' 3606' A-SAND SLOTTE 4520' 5-1/2" 11297' 3602' Perforation depth: Measured depth: 7014'-7514', 7759'-8340', 9074'-9551', 9953'-10346', 10658'-11202' true vertical depth: 3615'-3611', 3595'-3592', 3581'-3573', 3575'-3586', 3601'-3603' Tubing (size, grade, and measured depth) 4-112" , L-80, 6822' MD. Packers &SSSV (type & measured depth) PKR = ZXP Liner Top Packers PKR= 5780', 6038', 6777', and 10 constrictor packers to isolate shales SSSV= NIP SSSV= 508' 12. Stimulation or cement squeeze summary: Intervals treated (measured} ;~ ~ ~~~. ;~~(~ ,~ ~ 2ao~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oit-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1913 945 208 Subsequent to operation 1875 1136 145 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ ' Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buc hhol Title Production Engineering Technician ~ Signature ~G~r(_ , Phone 659-7535 Date `~~~~ Form 10-404 Revised 04/2004 ~~`' ~~- Submit OjgjAal O~I ~~ lj'~'C l ~ 1 E-112 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/11/08 Set Isolation Sleeve in B-Sand LEM @ 6086' RKB. { KRU 1 E-112 ConocoPhillips Alaska, Inc. ~ r"~ ~~ 03/12/08 ~~'~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth _____ NO. 4624 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk • Well Job # Log Description Date BL Color CD 1 A-12 11964583 LDL ~°~ (_- (~- 02/28/08 1 1 E-1128 SAND LATERAL 11978443 MEM INJECTION PROFILE 03/03/08 1 1R-04 11964585 USIT ~. - 03/02/08 1 2L-330 11837544 OH EDIT (SONIC SCANNER) ~}-. ~ 11/27/07 1 1 31-01 11994626 LDL 03/06/08 1 2N-327 11994628 PRODUCTION PROFILE ~(~~.. 03/08/08 1 1Y-28 11994629 PRODUCTION PROFILE .~ ~ 03/10/08 1 3S-08C 40016310 OH MWD EDIT VISION SERVICE '~' ~( 01/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ • .. _~_- ,,w' ~, ~` MICROFILMED 03/41 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ~~rrf+ ~tt ~~tt ,~ ~) rgp~~~~ Schlumberger -DCS a~~.~~::' 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ ~ ~ ~ ~Q~~ ~~~~~~ DEB Well Job # Log Description C.- NO. 4564 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 01 /25/08 26-13 11996584 PRODUCTION PROFILE ~~- - /p 01/10/08 1 1E-112 11994598 INJECTION PROFILE _ - q 01111/08 1 1J-164L1 12005203 MEMINJECTION•PROFILE ~('~~- ~ ~ ()~ 01122108 1 2M-20 11996596 PRODUCTION PROFILE - V~( 01122108 1 1 C-170 11970605 USIT -p 12/02/07 1 2G-06 11994596 PSP MULTI-FINGER CALIPER 01/10/08 1 3K-102 11994599 MDT ~ - 01114108 1 1J-127 11994603 INJECTION PROFILE (~1C. ~p(c-QL(~- 01121/08 1 2T-21 11839639 RST 1 ~ 08/02/07 1 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. lb West. Sak Injector 1E-112: N~eaton of Defeated Low Pressure Pilot (LPP) Page 1 of 1 • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophitlips.com] Sent: Tuesday, January 08, 2008 7:37 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK West Sak Prod Engr; NSK Prod Engr Tech; Rodgers, James T; CPF1 Prod Supt; Allsup- Drake, Sharon K; CPF1 DS Lead Techs; NSK Problem Wet! Supv Subject: West Sak Injector 1 E-112: Notification of Defeated Low Pressure Pilot (LPP) Tom /Jim, This email is to notify the AOGCC that the West Sak Injector 1 E-112 (PTD Na.s 204-091 / 204 - 092 L1 / 204-093 L2) Low Pressure Pilot (LPP) is defeated as of 1/7/2008. This is in accordance with "Administrative Approval No. CO 406B.001". The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log." The 1 E-112 was shut in on 12!30/2007, and restarted yesterday, 1 R/2008. It is anticipated that injection pressure wi{I increase above 500 psi within a few days. Current injection rate is 2500 BWPD, injection pressure at the wellhead is 320 psi. The AdGCC will be nat~ed when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Eric Hotlar / Hai Hunt West Sak Production Engineer CanocoPhiltips Alaska, Inc. Rhone 907-659-7061 Pager 907-659-7000 x836 :~;;{~ `l~~ JAN ~ ~ 2008 1/8!2008 ScblumblPgep NO. 4468 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 SCANNED 0 C1 3 1 2007 Field: Kuparuk Well Job # Log Description BL Color CD Date 2N-327 11839673 PERF/SBHP ~)()'?- - f){~q 10/24/07 1 2T-201 (REPLACES 11839656 INJECTION PROFILE tJ-¡:c...IG\~-/~~ 09/03/07 1 1A-23 11837520 PRODUCTION PROFILE lot (-oelì 10/04/07 1 2M-09A 11846446 WFL t):t..Q. ¡q{.. -(-p,Ò 10/04/07 1 31-08 11837517 LDL ,~(,¡, - cAr) 10/02/07 1 2M-24 11839670 PRODUCTION PROFILE IC\ c;:) -()S1) 10/03/07 1 1J-102 11846451 INJECTION PROFILE U-:tQ... :::Jc:to - /Lò 10/10/07 1 1Y-02 11837516 INJECTION PROFILE í rT{'I J "X~ - ~ 10/01/07 1 1 E-112 11846450 INJECTION PROFILE UT(\ ::::Jr.u_Œ1 ( 10/10/07 1 2T-12A 11839669 LDL J«.C# - ~ 5<" 10/02/07 1 2B-07 11837522 INJECTION PROFILE UT ~ I "if'-l-(");:J'-f 1 0/05/07 1 1E-12 11846447 DDL J "6;). -óCð () 10/08/07 1 2N-327 11839671 SCMT d--o"1--0C::,q 10/23/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. i3 10/25/07 . . LPP/SSV defeated on lE-112, lJ-102, lJ-127, lJ-164, lJ-180 e e Page 1 of1 .!.. ~9Y1 ~/~" Maunder, Thomas E (DOA) From: Maunder, Thomas E (OOA) Sent: Monday, August 27,20079:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (OOA) Cc: CPF1 OS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers. James T Subject: RE: LPP/SSV defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180 Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC -~----_._. From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26,20078:59 AM To: Maunder, Thomas E COOA); Regg, James B COOA) Cc: CPFl DS Lead Techs; CPH Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on lE-il2, lJ-l02, lJ-127, 1]-164, 1]-180 Tom 1 Jim, The LPP/SSV's on all of the West Sak DS1 E and DS1J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to drill numbers are also listed. I wasn't sure if you wanted the permit to drill number for the mainbore only or the laterals as well so I included both. rmit to Drill No. 204-09 (MAINBORE), 204-092 (L 1), 204-093 (L2SCANNED AUG 2 7 2007 206-11 (MAINBORE), 206-111 (L 1),206-112 (L2) 207 -027 (MAINBORE), 207-028 (L 1), 207-029 (L2) 206-047 (MAINBORE), 206-048 (L 1), 206-049 (L2) 207-015 (MAIN BORE), 207-016 (L 1),207-017 (L2) 205-144 (MAINBORE), 205-145 (L 1),205-146 (L2) 206-150 (MAIN BORE), 206-151 (L 1) .¡1E-112 1 J-1 02 1 J-1 05 1 J-127 1 J-160 1 J-164 1 J-180 Note: 1J-105 and 1J-160 were defeated in early July 2007, before the CPF1 ESD, because they were new injectors (notification for these wells was sent 7/9/2007). Let me know if you have any questions. Regards, Hai Hunt Hai Hunt 1 Pete Nezaticky 1 Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 8/27/2007 Lrr/L:)L:)v UCICaU;:;UUu lJ:,-II¿,e1V¿, IJ·l¿l, IJ-IU"t, IJ-I0V e rë1gc 1 VI 1 Maunder, Thomas E (DOA) ._ _'~_"'~'__'_'~_____<_~__'___'_~__~_~__'_~,^'___""______"~__'__'_"_'~__"_'-~~__r_"_"___'___'~__'_' _.__~~___.,.___~ . __.___ ___.___"_..~~._ ~_,,__.__. ___"~_...,__"__n·_ ~ _.___.,,_.___,_.~_____h__·.____,..·__·__,._<.··____..,·"_'.~'__"~___'_~"__'. From: NSK West Sak Prod Engr [n1638@conocophillips.com] Wednesday, August 15, 20072:01 PM Maunder, Thomas E (DOA); Regg, James 8 (DOA) CPF1 OS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: LPP/SSV defeated on 1 E-112, 1J-102, 1J-127, 1J-164, 1J-1So- ';).0(0 - \ s-O dQl+-Ö<i\l - J-Cb - \\U Tom / Jim, l' 1---... ~~b-ö'-\ ~ "- r ;).05- \ '-\ i.1 The Low Pressure Pilots (LPP) for West Sak Water Injectors 1 E-112, 1 J-1 02, 1 J-127, 1 J-164, and 1J-180 were defeated because of low wellhead injection pressure. These wells were shut in for a few days starting August 9 (CPF1 ESD/Coalescer shut down), allowing bottom hole pressure to fall off. The LPPs and SSVs have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." Sent: To: Cc: We expect the bottom hole pressures to build back up in a few days. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPPíSSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions or concerns. Regards, Hai Hunt Hai Hunt / Eric Hollar / Pete Nezaticky NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com SCANNED AU G 1 6 2007 R/16/?007 Schlumberger APR ? IJ 2007 NO. 4219 ~ .. ,. f\fnfn~S5~r~r;, R.. G~§ Con;,· \/- f\rcbo~~ Company: Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 5CANNED APR 2 5 2007 () .T c.. Ðð<-I- oq I Field: Well Job# Log Description Date BL 1A-10 11638846 INJECTION PROFILE 04/05/07 1 2L-313 11628996 LDL 04/08/07 1 1 D-137 11628997 INJECTION PROFILE 04/09/07 1 2N-31.1A N/A USIT 04/06/07 2N-337B 11638852 SCMT 04/11/07 1J-184 11638853 SBHP 04/12/07 1 1 H-1 0 11638844 GLS 03/20/07 1 2W-03 11649957 MEM LDLlPPROF 04/10/07 1 1 E-112 11638856 INJECTION PROFILE 04/14/07 1 1J-156 11638857 INJECTION PROFILE 04/15/07 1 1J-127 11638859 INJECTION PROFILE 04/17/07 1 1J-105 11628994 USIT 04106/07 1J-164 . 11638858 INJECTION PROFILE 04/16/07 1 1J-164. 11638860 INJECTION PROFILE 04/17/07 1 04/20/07 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 Kuparuk ( Color CD 1 1 1 ( Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. t3 LPP Defeated On West Sak Injectors at DSlE e e Tom / Jim, The Low Pressure Pilots for 1 E-102, 1 E-1 05, 1 E-112, and 1 E-114 were placed back into service today as the injection well head pressures have come up above 500 psi. Current status: 1E-102 822 BWPD, 541 PSI 1E-105 1006 BWPD, 660 PSI 1E-1121937 BWPD, 597 PSI 1 E-114 945 BWPD, 562 PSI dOL\-OC\ \ ~ This email is in accordance with Administrative Approval No. CO 4068.001. Regards, Hai Hai Hunt / Pete Nezaticky NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillíps.com &~M&D JAN 1 \) 2.007 1 of 1 1/16/2007 11 :07 AM ~ \ ~"'-.~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 j/~ J ~lJ-Jw.öi API No. 50-029-23211-00-00 PermittoDriJI 2040910 Well Name/No. KUPARUK RIV U WSAK 1E-112 Operator CONOCOPHILLlPS ALASKA INC MD 11425/ TVD 3597 ~ Completion Date 7/31/2004 ". Completion Status 1-01l Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud log No Directional Survey Yes Samples No 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 Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments rR~ Directional Survey 7864 11425 8/2/2004 MWD Rpt Directional Survey 0 8023 8/2/2004 PB1 MWD r Production 5 Col 87 6700 Case 7/21/2004 ULTRASONIC IMAGING TOOL, CEMENT & / CORROSION WITH CBl ¡tD C Las 12781 Induction/Resistivity 108 11425 1 0/19/2004 lDWG-LAS, GRAPHIC I~g IMAGES, RWD-GRlMPR 12781 Induction/Resistivity Blu 108 11425 10/19/2004 LDWG-LAS, GRAPHIC IMAGES, RWD-GR/MPR ~ 12781 Induction/Resistivity Blu 108 11425 1 0/19/2004 lDWG-LAS, GRAPHIC IMAGES, RWD-GRlMPR Rpt 12781 LIS Verification 108 11425 10/19/2004 LDWG-LAS, GRAPHIC IMAGES, RWD-GRlMPR ~ Production 5 Blu 5574 7166 1/19/2005 MPSP PRODUCTION PROFllE/GREAD/SPINITE I¿ MP/PRES Injection Profile Blu 5700 6110 3/16/2005 INJECTION PROFILE/SPINITEMP/PRE I SS Injection Profile 5 Blu 5650 8300 5/23/2005 INJECTION PROFllE/PSP: SPINITEMP/PRESS/DEVIA TION Injection Profile 5 Blu 5800 9300 Case 7/14/2005 03 July 2005 Induction/Resistivity 5 Blu 5732 5882 Case 3/24/2006 SPINITEMP/PRESS 22- Mar-2006 . . Permit to Drill 2040910 MD 11425 TVD 3597 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? Y"ì'T<r Analysis Received? ~ ---~- Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Well Name/No. KUPARUK RIV U WSAK 1E-112 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23211-00-00 Completion Date 7/31/2004 Completion Status 1-01L Interval Start Stop Sent Received Daily History Received? Formation Tops .J ~ ¡:;;) :...... Current Status 1WINJ UIC Y Sample Set Number Comments ---& / N fj/N ~ Ji/-~ (p - Date: . . Scblumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth u:rc... Well Job # 1 J-127 1 D-119 2L-321 2V-13 1Q-13 1 Q-26 1 R-14 1G-09 3N-16 1 E-112 11216302 11249924 11235382 11235385 11249936 11249937 11235386 11249938 11235389 11285935 08/09/06 RECEIVED NO. 3910 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD . 06/05/06 1 07/05/06 1 07/24/06 1 07/26/06 1 08/02/06 1 08/03/06 1 08/03/06 1 08/04/06 1 08/05/06 1 08/05/06 1 ;.:.w; 1· 0 20n6 1 ;,-,\:.__ U ~J~~ OH &. Gas Cons. Commission At'1ct1ornge ::)ðt..!-CF11 Log Description USIT INJECTION PROFILE LDL SBHP SURVEY INJECTION PROFILE PROD PROFILE W/DEFT PROD PROFILE W/DEFT INJECTION PROFILE SBHP SURVEY MEM INJECTION PROFILE . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg '~K' t;J" Ç.;,q/DÇ, P.I. Supervisor ¿!fIr { DATE: Wednesday, June 07, 2006 SUBJECT: Mechanicallntegrity Tests CONOCOPHILLIPS ALASKA INC IE-I 12 KUPARlJKRIVUWSAK lE-1l2 t\ ... rJ~ 1 ~o FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: :JB2- P.I. Suprv_ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK lE-I 12 API Well Number 50-029-23211-00-00 Insp Num: mitCS060605135751 Permit Number: 204-091-0 Rei Insp Num Inspector Name: Chuck Scheve Inspection Date: 6/412006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I IE-I 12 IType Inj. I W iTVD 3395 IA 645 2100 2050 2050 2040910 I ; ¡ i OA i ---f P.T. TypeTest ! SPT . Test psi 1500 350 i 530 520 520 ], i Tubing! Interval 4YRTST P/F P 650 650 650 650 I Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integriy Wednesday, June 07, 2006 Page 1 of I Sc~lIn~epgep NO. 3429 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL I 2G-02 /ß 'f -J.{ f 11047334 BHP SURVEY 06/30/05 1 , 2G-13 ¡g11.¡).'t 11047336 BHP SURVEY 07101/05 1 ,. 2G-11 If'1 -i f7 11047337 BHP SURVEY 07101105 1 >' 1Y-14)3~~ ùn 11022907 LEAK DETECTION LOG 06130105 1 ¡¡ 3H-19/87 '" (J) 11022907 PRODUCTION PROFILE 06128105 1 ¡J. 1J-Ó3 ,~vl - C). '( 11022893 PRODUCTION PROFILE 06117105 1 .J 1L-09 l'iO,':JI{ 11022895 PROD PROFILE WIDEFT 06/19/05 1 ", 3S-10 ,). 0). - .1. 3 1. 11001235 PROD PROFILE W/DEFT 06/14/05 1 .) 3F-04 irþ'· "t18 11022891 INJECTION PROFILE 06/15/05 1 1Y-2VA ¡ ;J8,/1~ 11022892 PROD PROFILE W/DEFT 06/16/05 1 .,¡ 1E-112 .2û'"f - ó'ì I 11047339 INJECTION PROFILE Ut<- 07/03/05 1 j 1E-102 ÂC'1~;t31 11047340 INJECTION PROFILE lJi Co, 07/04/05 1 SIGNED: 1tJ DATE: ûlLJ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color CD R. ~¡l :(,~ J-- 07/08/05 . . Re: West Sak 1.1::-112 Injector online with defeated LPP . . Thanks Pete. NSK West Sak Prod Engr wrote, On 8/17/2005 4:21 PM: Tom, This email is to notify the AOGCC that West Sak injector 1 E-112 has been placed on injection 8/17 with the LPP defeated in accordance with AOGCC Rule Amendment No. C0406B.001 dated 6/14/05. The LPP has been tagged and recorded in the facility safety defeat log. ConocoPhillips will notify the AOGCC again when this is injector is shut-in or the injection pressure has built to 500 psi and the LPP activated. Currently the well is injecting at 580 bwpd on a vacuum. Thanks, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 1 of 1 8/18/20053:37 PM RE: West Sak Injector LPP Variance - Temp Variance extension req... It . Subject: RE: West Sak Injector LPP Variance - Temp Variance extension request IE-I 12 & lB-102 From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Mon, 27 Jun 2005 08:07:02 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: jim Jegg@admin.state.ak.us Tom, l ~ ;;ìOS-\d-d dOL\.-OS.1 JOLl- DSd-- ôlOY-oS -S Thanks for the quick response. Marie -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, June 27,20057:54 AM To: NSK Problem Well Supv Cc: jim_regg@admin.state.ak.us Subject: Re: West Sak Injector LPP Variance - Temp Variance extension request lE-112 & lB-102 Marie, We did receive the "request" regarding the LPPs on WS wells and we are nearly finalized with "our" document. With regard to these specific wells, it is acceptable to defeat the LLP due to the low injection pressures. The LPP must be returned to service when the injection pressure reaches 500 psi. A copy of this authorization should be available should the Inspector request it. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Two low wellhead pressure West Sak injectors are planned to be brought on injection for reservoir diagnostics. Our records show the last temp LPP variance expired 6/20105. CPAI would like to request another temp variance to defeat the LPPs on 1 E-112 and 18-102 for 30 days without a 24 hr man watch. 1 E-112 will be brought on injection as soon as an extension is granted. Downhole gauges were installed on 6/25/05 to record data for 30 days in conjunction with surface tiltmeter data gathering. The well has been ready to bring on injection, but operations is waiting on a variance extension. The well has been intermittently on injection in the last month with the injection wellhead pressure ranging between 0 to 35 psi. 18-102 will be 801 for a week in the next month when a production profile can be scheduled on 1C-178. 18-102 will be 801 a few days prior to the PPROF and SI a few days later. The last time 18-102 was on injection for reservoir diagnostics the injection wellhead pressure ranged between 0 to 25 psi. On 6/13/05, Jerry sent a letter to the AOGCC requesting approval to defeat LPPs on West Sak water injectors with low tubing pressure. Has the AOGCC had a chance to consider this request? Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 1 of! 6/27/20058:25 AM Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska, Inc. 7. KB Elevation (ft): RKB 28', 99' AMSL 1. Operations Performed: . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Opera!. ShutdownD Re-enter Suspended Well Stimulate 0 Waiver 0 Other o Convert to Injector o o Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Time Extension Exploratory Service o o 5. Permit to Drill Number: 204-091/304-479 6. API Number: 50-029-23211-00 9. Well Name and Number: 1E-112 8. Property Designation: ALK 25651 & 25660, ADL 469 & 470 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE INTERMEDIATE SLOTTED LINER Perforation depth: 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool measured 11425' feet true vertical 3598' feet measured 6200' feet true vertical 3485' feet Length Size MD 108' 20" 108' 3003' 13-3/8" 3031' 6900' 9-5/8" 6926' 4520' 5-1/2" 11297' Plugs (measured) Junk (measured) rvD Burst Collapse 108' 2309' 3606' 3602' Measured depth: 7014'-7514',7759'-8340',9074'-9551', 9953'-10346',10658'-11202' true vertical depth: 3615'-3611',3595'-3592',3581'-3573', 3575'-3586', 3601'-3603' RECEIVED APR 2 6 2005 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6822' MD. Packers & SSSV (type & measured depth) packers @ 5780', 6038', 6777', 10 constrictor packers to isolate shales Landing Nipple = 508' 12. Stimulation or cement squeeze summary: Alatka 011 & Gas Cons. CUlllllli:s:siulI Anchorage Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 4025 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: OilD GasD WAG 0 GINJ 0 WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A it C.O. Exempt Daily Report of Well Operations _X Gary Targac @ 265-6586 Gary Targac s;,oat",a ~ ,'- , F,,,,, 1(}.4()4 Rev;,., 0412004 0 Contact Printed Name WDSPL 0 Title Phone West Sak Coordinator 907-265-6586 Date Preoared bv Sharon AI/suo-Drake 263-461~ ~Í?>1rV\5 if ldkl ~ Submit Original Only . 1 E-112 Well Events Summary . Date Summary 01/03/05 OBTAINED BHP @ 6092' WLM (975 PSI @ 69 DEGREES); DRIFTED TBG WI 3.83" SWAGE TO 5370' RKB; SET 3.813" DB-6 BLANKING PLUG @ 5370' RKB, IN PROGRESS. [Pressure Data, GL V, MIT] 01/04/05 PULLED GLV & SET DV @ 2414' RKB. PULLED OV @ 5320' RKB. LOADED IA & TBG WI SW & DSL CAP. ATTEMPTED SET DV @ 5320' RKB. IN PROGRESS. [GLV] 01/05/05 PULLED DV @ 5320' RKB. JOB SUSPENDED FOR PHASE 2 WEATHER. IN PROGRESS. [GLV] 01/06/05 PULLED & SET 1" DV @ 5320' RKB. VERIFIED DVs FULLY SET @ 2414' & 5320' RKB. MITIA 3000 PSI, PASSED. JOB SUSPENDED FOR WEATHER. IN PROGRESS. [GLV, MIT] 01/07/05 MITIA 3000 PSI, PASSED. PULLED 3.81" DB-6 BLANKING PLUG @ 5370' RKB. [MIT] 01/14/05 SET CHOKE WI 1/2" ORIFICE ON 3.875" DB-6 LOCK @ 508' RKB. 01/24/05 PULLED DOWNHOLE CHOKE @ 508'RKB [Open-Close A Sand] 01/24/05 SET 3.875" DB-6 LOCK XO 2.875" MCX INJECTION VALVE WITH .75" BEAN AND NO FLAPPER @ 508'RKB [Open-Close A Sand] 01/26/05 PULLED & SET DOWNHOLE CHOKE WITH 5/8" BEAN ON 4.5" DB LOCK @ 508'RKB [Maintenance] 02/15/05 PULLED DOWNHOLE CHOKE @ 508' RKB. CHOKE IN NEW CONDITION, NO EROSION. MEASURED BHP @ 6080'WLM IS (1290 PSI @ 100 DEG F.). SET 3.81" DB LOCK,FLOW THRU SUB,SHOCK & DUAL PANEXES @ 5370' RKB. [Pressure Data] 02/24/05 PULLED DUAL PANEX ASS'Y @ 5370' RKB. SET DUAL SPARTEC ASS'Y (12' OAL) @ 5370' RKB. [Pressure Data] 03/06/05 PULLED SPARTEK GAUGES ON DB LOCK @ 5370' RKB. [Pressure Data] 03/08/05 RAN IPROF -- SPLITS: 12% 0 SAND 188% B SAND I 0% A SAND -- CROSS FLOW FROM 0 SAND TO B SAND WITH WELL SHUT IN -- USED WELL TEC TRACTOR FROM 6020' TO 6112' - UNABLE TO TRAVEL PAST B SAND LEM WITH TRACTOR BUT SPINNER ASSB. 04/08/05 RIGGED UP CTU#8; PERFORMED BOP TEST, RIGGED UP I-COIL / FIBER OPTIC BHA. ATTEMPTED TO DISPLACE COIL WI WARM DIESEL TO TANKS, OVER-PRESSURED RUPTURE DISK (1500 PSI BURST). 04/09/05 ATTEMPTED TEMPERATURE I INJECTION PROFILE ON B SAND LATERAL. DTS / I-COIL TOOLS FUNCTIONED PROPERLY. CYCLED 90 DEG (15 DEG PER) WI DISCOVERY ML T TRYING TO LOCATE WINDOW. 04/1 0105 ATTEMPTED TO FISH DISCOVERY ML T W/ 2-5/8 RELEASEABLE OVERSHOT. TAGGED WHAT WE BELIEVED WAS FISH AT 6060' CTM, DIDN'T LATCH FISH- NO CLEAR MARKS ON TOOLS. RECEIVED APR 2 6 2005 Alaska Oil & Gas Cons. Commission Anchorage . 1 E-112 Well Events Summary . 04/11/05 ATTEMPTED TO FISH DISCOVERY ML T TOOLSTRING WI 2-1/8" MHA&JARS/2-1/4 DISCONNECT/3-1/8" HYDRAULIC OVERSHOT WI 6" MULESHOE. 1ST RUN, RIH TO 7327' CTM, TAGGED HARD-STACK WGT/RUN INTO IT HARDIFIRE JARS DN 2X, CAME OOH EMPTY, NO MARKS INSIDE OS. Perf (7013-7514) Perf (7759-8340) Perf (9074-9551 ) Perf (9953-10346) Perf :10658-11202) ConocoPhilllps Alas", Inc. 1E-112 . 1:-112 KRU API: 500292321100 SSSV Type: NIPPLE Annular Fluid: Reference Log: 28' RKB Last Tag: Last Tag Date: Ca$íng String - All STRINGS . Description Size CONDUCTOR 20.000 SURFACE 13.375 INTERMEDIATE 9.625 A-SAND SLOTTED LINER 5.500 Tubing String, - TUBING Size I Top 4.500 0 Perforations Summary Interval TVD 7013 - 7514 3615 - 3611 Type: INJ Orig Completion: 7/31/2004 Last W/O: Ref Log Date: TD: 11425 ftKB Max Hole Angle: 94 deg @> 7538 Angle @ TS: deg @ Angle @ TO: 92 deg @ 11425 Rev Reason: Pull Choke & Gauges Last Update: 3nt2005 Zone WSA2 Status Ft SPF Date Type Comment 501 40 7/9/2004 IPERF Slotted Liner Alternating wlBlank Pipe 581 40 7/9/2004 IPERF Slotted Liner Alternating w/Blank Pipe 477 40 7/9/2004 IPERF Slotted Liner Alternating w/Blank Pipe 393 40 7/9/2004 IPERF Slotted Liner Alternating w/Blank Pipe 544 40 7/9/2004 IPERF Slotted Liner Alternating Pipe 7759 - 8340 3595 - 3592 WSA2 9074 - 9551 3581 - 3574 WSA2 9953 - 10346 3575 - 3586 WSA2 10658 - 11202 3602 - 3603 WSA2 .G~S{lil"~ªnariil&~~UiÊi$ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt 2414 2021 CAMCO KBG-2 DMY 1.0 BK 0.000 0 1/6/2005 2 5320 3257 CAMCO KBG-2 DMY 1.0 BK 0.000 0 1/6/2005 øttìer,¡;pIUg.s::iiqu¡p:,etQ·.r~~I1ME15,~illi.l3lR~ Depth TVD Type Description ID 22 22 HANGER VETOO GRAY HANGER W/4.909" MCA TOP CONNECTION 4.500 508 508 NIP CAMCO DB-6 LANDING NIPPLE WINO GO PROFILE 3.875 5370 3276 SLEEVE-C BAKER CMU SLEEVE W/CAMCO PROFILE DB-6 3.810 5780 3395 Packer L2 BAKER ZXP LINER TOP PACKER FOR D-SAND LINER L2 7.000 5792 3398 SEAL BAKER LOCATOR/SEAL ASSEMBLY 3.880 5801 3401 SBR L2 BAKER 190-47 SBR FOR D-SAND LINER L2 4.750 5830 3408 LEM L2 LATERAL ENTRY MODULE FOR D-SAND LINER L2 3.680 5839 3410 Hanger L2 HOOK HANGER #2 FOR D-SAND LINER L2 6.290 6038 3456 Packer L 1 BAKER ZXP LINER TOP PACKER FOR B-SAND LINER L 1 6.230 6057 3460 SBR L1 BAKER 190-47 SBR FOR B-SAND LINER L1 4.750 6064 3461 SEAL L 1 BAKER 190-47 NLOCK SEAL ASSEMBLY FOR B-SAND L 1 3.880 6086 3465 LEM L 1 BAKER LAERAL ENTRY MODULE FOR B-SAND LINER L 1 3.680 6094 3467 Hanger L 1 HANGER FOR B-SAND LINER L 1 6.230 (i)t¡,;¡er:~li'llug$l,egtìíp;,etø;,)-l.iINI3R;A:.S~NIil¡jI3.I3IWR\Yl Depth TVD Type Description ID 6777 3582 PACKER HRD ZXP LINER TOP PACKER 6.278 6795 3585 NIP 'RS' PACKOFF SEAL NIPPLE 5.963 6798 3585 HANGER BAKER FLEXLOCK 7 x 9-5/8" 6.276 6808 3587 SBR BAKER 190-47 SBR 4.750 6819 3588 SEAL BAKER 190-4 NLOC SEAL ASSEMBLY 3.875 7014 3616 Constrictor 10 CONSTRICTOR PACKERS set TO ISOLATE SHALES FROM SAND, @ 7014', 5.963 PKR 7538',7758',8368',9074',9584',9950',10370', 10648', 11215' GeFle,FslI'!JotÊis Date Note 7/30/2004 TREE: ABB VETCO-GRAY / HORZ /4-1/16" 5M (W/PENETRATOR WIRE) TREE CAP CONNECTION: 9" OTIS THIS IS A TRI-LATERAL WELL - THIS SCHEMATIC FOR UNDULATING A-SAND LINER - REFER TO BAKER HUGHES SCHEMATIC SHOWING COMPLETE TRI-LATERAL WELLBORES RECEIVEr) APR 2 6 2005 Alaska Oil & Gas Cons. Commisswf Anchorage .. . .0 ~ . . Gary Targac West Sak Coordinator Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6586 April 25, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject Report of Sundry Well Operations for 1 E-112, 1 E-112L 1, 1 E-112L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent return of service of the Kuparuk wells 1 E-112, 1 E-112L 1 and 1 E- 112L2. If you have any questions regarding this maUer, please contact me at 265-6586. Sincerely, ~~ ~rJ:· TÕ-" West Sak Coordinator CPAI GT Iskad RECEIVED APR 2 6 Z005 Alaska Oil & Gas Cons. Commission Anchorage t~"e. .F'1?: variance tor lB-102 (PTD 2031220).1E-1l2 (PTD 20... tit Subject: Re: FW: Variance for IB-102 (PTD 2031220) and IE-112 (pTD 2040910) From: Thomas Maunder <torn _ maunder@admin.state.ak.us> Date: Thu, 07 Apr 200509:55:36 -0800 To: NSK Problem Well Supv <nI617@conocophillips.com> CC: James Regg <jim_regg@admin.state.ak.us>, AOGCC North Slope Office <aogcc yrudhoe _ bay@adrnin.state.ak.us> MJ, You have approval to operate the well for up to 30 days to perform the diagnostic testing you plan. Torn Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Jim ConocoPhillips requests a 30 day variance to operate 1 E-112 with a gagged SSV. The AOGCC had originally granted a variance to operate the well with a temporary gagged SSV on 04MAR05 for 30 days. However the well was SI on 12MAR05 with water break- through to the adjacent producer. We would now like to bring the well on line and warm it up for injection profile diagnostics (scheduled for later this week). As summarized in the email string below the injection pressure on this well operates at very low injection pressure and at the time it was 51, it was still on a vacuum. It is our intention to SI and freeze protect the well as soon as the injection profile diagnostics are completed. Please advise if this temporary variance is possible MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder [maìlto:tom maunder@admin.state.ak.us] Sent: Tuesday, March 29, 2005 10:56 AM To: NSK Problem Well Supv Subject: Re: Variance for 18-102 (PTD 2031220) and 1E-112 (PTD 2040910) Brad, Jerry, MJ, et al: Brad just sent in another request regarding a WS well operating on vacuum and when I searched for a reply regarding other wells, I was not able to find it. What you propose for I B-1 02 and I E-112 is acceptable. There is not a risk of the wells flowing to surface and avoiding nuisance trips helps prevent damaging the valve. Please keep us advised of 10f3 4/7/20059:55 AM h . ~ ". y all<1lH;e WT lB-101 (t' i'D 2031220_ IE-I 12 (PTD 20... e the well operations. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Operations recommend that 300 psi is an adequate amount of pressure on the tubing to re-set the SSV pilots. At this pressure there shouldn't be any nuisance trips of the pilot due to fluctuations in the tubing pressure. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 -----Original Message----- From: Thomas Maunder rmailto:tom_ maunder@admin.state.ak.us] Sent: Tuesday, March 08, 20059:19 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: Variance for 18-102 (PTD 2031220) and 1E-112 (PTD 2040910) Brad/J erry, Jim has asked me to get back with you: What is the threshold of 300 psi?? Thanks, Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Jim, We are requesting a temporary variance from Conservation Order #406B, Rule 6, section b which requires SSVs for water injection wells 1 B-1 02 and 1 E-112. A temporary variance to operate 1 B-1 02 and 1 E-112 water injection wells with a defeated SSV pilot and without a 24 hr man watch for a maximum of 30 days is requested. Both wells are injecting on a vacuum and the SSV low pressure pilot can not be placed in service at this time. Neither well will flow to surface at this time. Both wells have a single check valve and an SSv. 30 days is requested to allow these wells to be on injection for reservoir diagnostic work. If the injection pressure increases during this period to at least 300 psi, the SSV will be put back in service. Based on the verbal approval date of 3/04/05, the wells will either be SI or the SSV will be back in service by 4/03/05. Notification will be made to AOGCC when either the well is SI or the SSV has been placed back in service. 1 B-1 02 has been shut in since 11/7/04 when water injection appeared to communicate directly with production wells. 200 4/712005 9:55 AM :'" : 1 '",. V <ulaUCe lOr IH-102 (PTD 2031220).1E-112 (PTD 20... e 1 E-112 is a new injector and has been on a vacuum since initial injection due to low bottom hole pressure. A downhole choke was installed to maintain wellhead injection pressure above the SSV pilot trip point. The downhole choke was removed in preparation for reservoir diagnostic work. 1 E-112 water injection appeared to communicate directly with production wells and the injector was shut-in 2/12/05. 1 B-1 02 was brought back on injection on 3/04/05. 1 E-112 was brought back on injection on 3/02/05. Electric-line injection profile logs are planned for reservoir diagnostics during the week of 3/07/05 for both 1 B-1 02 and 1 E-112. Once diagnostic work is completed, it is anticipated the wells will be SI while results are evaluated. Please let me know if you have any questions. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 30f3 4/7/2005 9:55 AM .ili. We:>l ~ak 1'/:<'-112 . . ~~-OS \ Subject: RE: West Sak lE-112 From: "Targac, Gary" <Gary. Targac@conocophiIlips.com> Date: Wed, 30 Mar 2005 16:48:37 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> .?~!L t;) OL\-OS. ~ We have narrowed it down to the B Sand. We are working on a log down the lateral to see what the mechanism is? Right now, we have 4 plausible causes: 1) fracturing, 2) fault communication, 3) matrix event (high perm streak) or 4)fluidization event (ie. wormhole or weak sand interval). 00L\- oS -;) Will keep you posted. Gary -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, March 3D, 2005 4:40 PM To: Targac, Gary Subject: Re: West Sak lE-112 Gary, Your proposal is acceptable. Is there any feeling as to the mechanism regarding communication to IE-166?? Is it specific to one interval or have you been able to determine it down that far?? As noted in our earlier emails, the cement is suspect but suspect cement would more of concern for "getting out" in the vicinity of the wellbore not communicating to another wellbore. Keep us informed with the diagnostics. Tom Maunder, PE AOGCC Targac, Gary wrote: Tom, per our discussion, ConocoPhillips Alaska is requesting deferral of the warmback injection survey on Well 1E-112. 1E-112 started injection on Jan 13, 2005. The well was SI on Feb 12, 2005 due to the water breakthrough event to 1E-166. It has been on periodic injection twice since then while doing reservoir pulse testing and injection logging. More periodic injection is planned while we continue logging and pulse testing in the coming months to evaluate a remediation for the well. As noted on the Sundry, a warmback injection survey is required after thermally stable (-60 days). Due to the well being SI for some period, I would like to defer the warmback survey until (60 days) after we resume normal injection that is currently forecast to be June or July 2005. This note is requesting approval to do so. Please call me if you have any questions. Gary 907-265-6586 1of2 3131/20059:21 AM Kb: West Sak It-II2 . . -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, December 14, 2004 7:46 AM To: Targac, Gary; Allsup-Drake, Sharon K Cc: Shultz, Steven M¡ McKeever, Steve Subject: Re: lE-112, et al Gary, Sharon, et al: Robin Smyth delivered the bond log yesterday. In the lower portions of the section logged, the presentation shows pretty good coverage however it gets poorer the higher one goes. In order to evaluate further, I will need the operations reports for the intermediate cementing operation. All I have to examine now are the daily summaries attached to the completion report. Thanks for your assistance. Tom Maunder, PE AOGCC Thomas Maunder wrote: Gary and Sharon, I have looked further and I do have the plots for the well, at least as it was planned, but I will need the log. Tom Thomas Maunder wrote: Gary and Sharon, I have received the sundries for the multi-lateral wellbores. I do not have a copy of the bond log and am also in need of the proximity information. Such plot should start at the top of the sand above the L2 lateral and proceed out all the well path(s) to TD. Steve Shultz and Vern Johnson have previously provided me such information on other wells. From my review of the completion report, it appears that the cementing operation went fairly well. An e copy of the bond log is acceptable. Tom Maunder, PE AOGCC 20f2 3/31/2005 9:21 AM Ke: Vanance for lB-102 (PTD 2031220) and IE-112 (PTD 2040910) e e Subject: Re; Variance for 1B-102 (PTD 2031220) and lE-112 (pTD 2040910) From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 29 Mar 2005 10;56;02 -0900 To: NSK Problem Well Supv <n1617@conocophillips.com> Brad, Jerry, MJ, et al; Brad just sent in another request regarding a WS well operating on vacuum and when I searched for a reply regarding other wells, I was not able to find it. What you propose for IB-I02 and 1E-112 is acceptable. There is not a risk ofthe wells flowing to surface and avoiding nuisance trips helps prevent damaging the valve. Please keep us advised of the well operations. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote; Tom, Operations recommend that 300 psi is an adequate amount of pressure on the tubing to re-set the SSV pilots. At this pressure there shouldn't be any nuisance trips of the pilot due to fluctuations in the tubing pressure. Brad Gathman ConocoPhíllips Alaska Inc. Problem Well SupeNisor 907 -659-7224 -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Tuesday, March 08, 20059:19 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: Variance for 18-102 (PTD 2031220) and 1E-112 (PTD 2040910) Brad./J erry, Jim has asked me to get back with you. What is the threshold of 300 psi?? Thanks, Tom Maunder, PE AOGCC NSK Problem Well Supv wrote; Jim, We are requesting a temporary variance from ConseNation Order #406B, Rule 6, section b which requires SSVs for water injection wells 1 B-1 02 and 1 E-112. A temporary variance to operate 1 B-1 02 and 1 E-112 water injection wells with a defeated SSV pilot and without a 24 hr man watch for a maximum of 30 days is requested. Both wells are injecting on a vacuum and the SSV low pressure pilot can 10f2 3/29/2005 10:56 AM Re; Variance for 1 B-1 02 (PID 2031220) and 1 E-112 (PID 2040910) e e not be placed in service at this time. Neither well will flow to surface at this time. Both wells have a single check valve and an SSV. 30 days is requested to allow these wells to be on injection for reservoir diagnostic work. If the injection pressure increases during this period to at least 300 psi, the SSV will be put back in service. Based on the verbal approval date of 3/04/05, the wells will either be SI or the SSV will be back in service by 4/03/05. Notification will be made to AOGCC when either the well is SI or the SSV has been placed back in service. 1B-102 has been shut in since 11/7/04 when water injection appeared to communicate directly with production wells. 1 E-112 is a new injector and has been on a vacuum since initial injection due to low bottom hole pressure. A downhole choke was installed to maintain wellhead injection pressure above the SSV pilot trip point. The downhole choke was removed in preparation for reservoir diagnostic work. 1 E-112 water injection appeared to communicate directly with production wells and the injector was shut-in 2/12/05. 1 B-1 02 was brought back on injection on 3/04/05. 1 E-112 was brought back on injection on 3/02/05. Electric-line injection profile logs are planned for reservoir diagnostics during the week of 3/07/05 for both 1 B-1 02 and 1 E-112. Once diagnostic work is completed, it is anticipated the wells will be SI while results are evaluated. Please let me know if you have any questions. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 20f2 3/29/2005 10;56 AM ~ol.{ - 091 Schlumberger NO. 3365 Sch/umberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 03/15/05 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: . Well Job# Log Description Date BL 18-f-r.:¥/ 2U-12 10942844 PROD PROFILE/DEFT 02/15/05 1 /$1-/22. 2B-02 10922542 PROD PROFILEIDEFT 02/26/05 1 íY'3 -67130-07 10922549 INJECTION PROFILE 03/05/05 1 1'6~i-CFJ¿.2V-15 10922543 PROD PROFILE/DEFT 02/27/05 1 20'-/ _()~-¡ 1 E-112 10922552 INJECTION PROFILE 03/08/05 1 1.01. ~ ()/! 2P-427 10922545 SCMT 03/01/05 . Kuparuk Color CD 1 SIGNED: ~ý&fo5- /( r;;;,~j¿~~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM TO: Jim Regg P.I. Supervisor . ~1 t(C:3/t)i~ State of Alaska Alaska Oil and Gas Conservation commiss. DATE: Wednesday, February 09, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-I 12 KUPARUK RIV U WSAK IE-I 12 Src: Inspector g.,olt' oq I FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV U WSAK IE-Il2 API Well Number: 50-029-23211-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS050203164036 Permit Number: 204-091-0 Inspection Date: 2/3/2005 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IE-II2 ¡Type Inj. I TVD 3582 I IA I 1375 I 2000 i 1990 i 2000 ! ì I P.T. 2040910 TypeTest ! SPT Test psi 895.5 lOA I 280 I 350 , 350 I 350 i I I I Tubing! 1330 I 1330 i 1330 , 1330 i I Interval INITAL P/F P i Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity SCANNEDJAN o 3 2007 NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Wednesday, February 09, 2005 Page I of 1 Schlumberger NO. 3313 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1/19/05 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: . Well Job# Log Description Date BL !90-//P7 1A-25 10942816 PRODUCTION PROFILE/DEFT 12/25/04 1 I ~ - OI(C'f1D-1 0 10942818 LDL & MUL TIFINGER CALIPER 12/27/04 1 /lOtf..,()ff 1E-112 10715441 MPSP PRODUCTION PROFILE 11/12/04 1 JO/.,./:!/f 1C-119 10942819 INJECTION PROFILE 12/28/04 1 ;lc4~1.2. '7 1E-104 10942821 PERF RECORD W/SBHP 12/30/04 1 !ð'-/ZY 2T-12A 10922519 PRODUCTION PROFILE/DEFT 01/03/05 1 104'2-1.1 1 E-104 10942821 SCMT 12/29/04 2-of.¿' t 1E-102 10942815 USIT 12/24/04 . SIGNED: .!J~~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color CD 1 1 --- 1-(9- 05 ~~ÌÆ~E mF·~~~~~«] ¡tJ,ASIiA OILAlWD GAS CONSERVATION COMMISSION dor-ocrl FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Targac West Sak Coordinator ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska Re: Kupaurk lE-H2, lE-112Ll & lE-112L2 Sundry Numbers: 304-479,304-478 & 304-477 Dear Mr. Targac: Enclosed are the approved Applications for Sundry Approval relating to the above referenced wells. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing' is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Aperson may not appeal a Commission decision to Superi C unless rehearing has been requested. DATED this /6day of December, 2004 Enc!. . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 1. Type of Request: Abandon 0 o o Suspend 0 o o Alter casing Repair well Change approved program Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 28', 99' AMSL 8. Property Designation: ALK 25651 & 25660, ADL 469 & 470 11. Total depth MD (ft): 11425' Casing Total Depth TVD (ft): Effective Depth MD (ft): 3598' 6200' Length Size CONDUCTOR 108' 20" SURFACE 3003' 13-3/8" INTERMEDIATE 6900' 9-5/8" SLOTTED LINER 4520' 5-1/2" Perforation Depth MD (ft): Perforation Depth TVD (ft): 7014'-7514',7759'-8340',9074'-9551', 9953'-10346',10658'-11202' Packers and SSSV Type: December 20,2004 Date: Perforate 0 o Stimulate 4. Current Well Class: Development _ 0 Stratigraphic 0 Exploratory 0 o Service ~~rl" /. ~. ;::.---;::, ~ Waiver o o o Other 0 Convert to Annular Disp. 0 Time Extension Re-enter Suspended Well Iniprtnr 5. Permit to Drill Number: 204-091 6. API Number: 50-029-23211-00 9. Well Name and Number: 1 E-112 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 3485' MD "ië 230~ O€'c ~ll/~ 3601f4S~H 4, I 0 Â>-,.. 'D 3602' & GIJS r.. <"'UU¢ 41lcJ,. -o".r. ~ 'Ora,. O/h,.. . ~(! ..,,1/..... "'''10" Packers and SSSV MD (ft) packer @ 6777'. 10 constrictor packers to isolate shales Landing Nipple = 508' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 108' 3031' 6926' 11297' rvD 108' 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Ope rat 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name. Ga.. ry T a\ga:...r--- Signature ~;O...,(W . 17"\ t l) \J Commission Use Only Condffio", of approvaf, Notify Comm¡,,;oo '0 "'" a mp,",,"ta',,,, may wito~,UJ,..~Q..()~ l.. 'f'.IS""d"'~'q ~ L-ll q Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Location Clearance 0 Other: ~"\.\.~,,>s~-k.\\ ~~O-Ù\.~ ~ ~~~~&~~ \\ \~'\~~\\'i ~.6.\o \~.. ~G:>Q <2>e-'i~ . '~")~\cz:.<:..-\--"\o~ a.~~(:"- \<t,~(Ü.-\-vrt \O~ ~\..o~\cl ~ t\)('\ :t:.K\fè.C.c-\'t. t>C'L~~O~> \ ~$)"L<.f)~ $Vi' J\\Ù ~ß Subsequent Fornt Requir : "'-\ I\.....\ '" //;,.. RBDMS BFL DEC 2 ) 20D4 c.... I r¡ BY ORDER OF THE COMMISSION Tubing Size: 4-1/2" Collapse Tubing Grade: L-80 Tubing MD (ft): 6822' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Contact: Gary Targac @ 265-6586 Title: West Sak Coordinator. Phoneqo1-Z"5-b~8' Date I~ I c¡ '04 DaW¡z(tff OR! GiN A L Submit in Duplicate COMMISSIONER INSTRUCTIONS ON REVERSE "fUSING -- -:::: .- (0-6822, 00:4.500, 10:3.958) SURFACE - (0-3031, 00:13.375, Wt:68.00) TERMEOIATE -- (0-6926, 00:9.625, Wt:40.00) SLEEVE-O -- (5370-5371, L 00:5.470) SEAL ._,- (5792-5794, 00:5.200) PACKER - (6777-6778. 00:8.430) Constrictor m.../~~- PKR (7014-7015, 00:7.000) Perf (7013,7514) Perf (7759-8340) Perf (9074-9551 ) Perf (9953,10346) Perf :10567,11202} ,. KRU 15-112 API: 500292321100 SSSV Type: NIPPLE Well Type: PROD Orig Completion: Last W/O: Ref Log Date: TD: 11425 ftKB Max Hole Anç¡le: 94 deg Fluid: Log: 28' RKB Last Tag: Description ~ CONDUCTOR SURFACE INTERMEDIATE SLOTTED LiNER String - Size Top 20.000 0 13.375 0 9.625 0 5.500 6777 Bottom Zone Status WSA2 7759 - 8340 3595 - 3592 WSA2 581 40 ¡PERF 9074 - 9551 3581 - 3573 WSA2 477 40 IPERF 9953 - 10346 3575 3586 WSA2 393 40 7/972Ö04 ¡PERF 10567-11202 3599 - 3603 WSA2 635 40 7/9/2004 IPERF 1 E-112 Anç¡le @ TS: deç¡ @ Angle @ TO: 92 deg @ 11425 Rev Reason: NEW WELL Last Update: 8/14/2004 Wt 94.00 68.00 40.00 15.50 Grade K-55 L-80 L-80 L-80 BTC BTC-M DWC Thread IBT Comment Slotted Liner Alternating w/Blank Pipe Slotted Liner Alternating w/Blank Pipe Slotted Liner Alternating w/Blank Pipe Slotted w/Blank Pipe Slotted Liner Alternating St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 2414 2021 CAMCO KBG-2 GLV ""TO"' ." BK 0.188 1456 8/5/2004 3257 CAMCO KBG-2 OV 1.0 BK 0.313 0 8/5/2004 etc.) - COMMON JEWELRY BAKER 190-4 NLOC SEAL ASSEMBLY 10 CONSTRICTOR PACKERS set TO ISOLATE SHALES FROM SAND, @ 7014', 7538', 7758',8368',9074',9584' 1037 10648',11215' Date Note 7/30/2004 TREE: ASS VETCO-GRAY / HORZ! 4·1/16" 5M TREE CAP CONNECTION: 9" OTIS THIS IS A TRI-LATERAL WELL - THIS SCHEMATIC FOR MAIN LEG - REFER TO BAKER HUGHES __ SCHEMATIC SHOWING COMPL,¡;JE TRI-LATERAL VETDO GRAY HANGER DS-6 LANDING 5370 3276 CMU SLEEVE W/CAMCO 5792 3398 SEAL BAKER LOCA TOR/SEAL ASSEMBLY Other (plugs, equip" etc,) - MAIN LEG LINER JEWELRY Depth ND Type 6777 3582 PACKER 6795 3584 NIP 6798 3585 HANGER ~"3587 SSE 6819 3588 SEAL 7014 3616 Constrictor PKR D8-6 HRD ZXP LINER TOP PACKER 'RS' PACKOFF SEAL NIPPLE 7 x 9-5/8" 3.880 10 6.278 5.963 0.276 4.750 3.875 5.963 WIRE) Tubing String 4-1/2" 12.6#, L-80, IBTM 3.958" JD, 3.833" Drift 13-3/S" Casing Shoe, 6S#, L-SO, BTC set @ 3,031' MD, 2,309' TVD 5,780' MD - 7" X 9-5/8" ZXP Liner Top Packer Final As Completed 507' MD - DB Nipple, 3.875" Profile 2,400' MD - GLM, Camco 1" KBG·2 5,320' MD - GLM, Camco 1" KBG·2 5,369' MD - CMU Sliding Sleeve, w/3.81" DB Profile ConocJ'Phillips West Sak 9-5/8" Injector 1 E-112 Tri-lateral Completion Baker Oil Tools 5,830' MD - Lateral Entry Module (LEM) 'D' Sand lateral Lateral Entry Module (LEM,) With Diverters and Isolation Lateral Isolation Diverter Installed 5,803' MD - Casing Sealbore Receptacle OS Running Tool String ;5,1/2" 15.5#, :-80 Slotted Liner ~Ar@J;j¡:r:LlhJ;;] 5-1/2" Casing Shoe, 15.5#, II L-SO DWC Set @ 11 ,23S' MD ~ n ¡ :r--- Coil Connector ~ (1.00' Length) Hi ~... :.¥~Back Pr~8sure Valve {, (1.60 Length) ~.................... ........ ~ Flow-Th,u Swivel .. .. (1.25' Length) '---D~:~~~ ;.. (1.50' Length) :':: .--¡; .c:. ~:~:~h) 6.85ftApprox.OAL* 6,OS6' MD . Lateral Entry Module (LEM) 6,03S' MD - 7" X 9-5/S" ZXP. Liner Top Packer Lateral Entry Module (LEN!) Assembly __ 7" X 9-5/8" ZXP Liner Top Packer with Hold Downs 7.500" Tieback Ex!. ID 6.278" Tool Body ID -- Casing Sealbore Receptacle 4.75"ID, 5.75" OD 15' Length ~ Tubing Swivel, 4a1l2" Orienting Profile Automatic Alignment of LEM - Positive Latching Coilet Indicates Correct Location Seal Bore for Lateral __________ Isolation· 3.68" ID Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3,68" ID --- Isolation Seal Asembly 4.75" Seal OD 3.875" SeallD 12' Length 'B' Sand lateral * Jars may be I'equired in highly deviated or deep applications (6' approx length). 5-1/2"15.5#, L·SO Slotted Liner ~. J.;~ 5-1/2" Casing Shoe, 15.5#, L-80 DWC Set @ 11,253' MD 7" X 9-5/S" ZXP Liner Top / Packer 7" X 9-5/S" Flex Lock Liner Hanger Latel'al Acces. Diverier Installed ~ H: ~ ~ L' ~ 'GS' Profile for /' RunninglRetrieving .........,~;.'....... Snap In/Snap Out , ..... .#"'" Positive Locating-" Collet ' Latel'8llsolation .--. , S..I, 1 / Latel'al Olverier 4 Ramp I Isolatlonl Malnbore -"",;. Diverier Sleeve 11 Lateral Isolation --- t~.1 .., Seats 'i '.. I 'A' Sand Undulating lateral Liner Hanger / Packer Assembly set @ 6,776' MD Confidential 6,S07' MD - Casing Sealbore Receptacle 5-1/2" Casing Shoe, 15.5#, L-SO DWC Set @ 11,296' MD 9-5/S" Casing Shoe, 40.0#, L-SO BTC Set @ 6,926' MD F"" ¡ Dill,: 1£-11' - Trt4ateral Completion -Injector I Drawn By: Marc D. Kuck R'VIsIOfl No.: Baker Hughes 2003. This document may not be reproduced or distributed, In whole or In part. In any form or by any means electronic or mechanical, Including photocopying, recording, or by any Information storage and retrl.val system now known or hereafhtr Invented, without written permission from Bak.r Hughe. Inc. 1Jlíi.. ..... . 1.....1 ~r 4- . jDrawlngNo.: Ipag,~o.: 101. 1 . . . ck)~-O~' d-04 --0'\ J JC)4 \)~"3. \~Q0 -l1 -Ld- MECHANICAL INTEGRITY REPORT' ......... :~IG RELE;_S=:: . OPER & FIELD C?j¿- r w""ELL NUM:BER \ ~ - \ \ d =?UD IìA!::: : ~5Jf5 ~-\.t.'~c.a..-\c. ~ ~LL DATA TD: .liD.. .:...:..:¡e::::-: Shoe: TVD¡ :?BTD: HD TVD 3~~ TVD¡ DV: ~~ l1D . TV""]) TVD¡ :CP: HD ;:VD c.: Sf U' Ca.s ing : ì. 1'0 Shoe: bSJ<O HD MD _;JOl.:1g: 4\/;) Packer 58-t>3 HI) C' \ I'" ,. ~ole Size Ö g and TVD¡ Set: êt "5S-~:2 -\-o"o~L?~\~ow ~ðL-\\\~ O~<L~ \....ð\t.. I ~\ \o..~~ \ Perfs ~C?.ANrC;'-L INTEGRITY - PART /1 Annulus Press Test: ~p ¡ 15 min i 30 mi.n Co¡:¡:¡¡z¡ents: ",.,- ~CHÞ_1'iICÞ.L INTEGRITY - PART /2 ~dCo \ 'to ~ \ ~ Cement: Volumes :.. Amt. Liner ~t\ Csg ~li<;. ~y. ; DV N ~ . C¡nt -"01 to cover perfs '\5 ~'o\, ~d<ÖÇ ~~ ') ~<::::. '>ù~\ ù<c~~ ~ tt:N1è:..\ \-\.,.(è L d-(Li.\\- ~'\~-\- ~\\.)~ soo' ú.\\Ö'Ñì~ :t::J'2~ 'J..S Theoretical TOC G\.~ 3f:) l.c ~ s {_tJ\.~e\-~ \ \O~ . \"':> ~ 2:>:)..' · '1"o-ö4 Cement Bond Log (Yes or No) '\~S ; In AOGCC File ~€- S. G1 ~<c"-\-"~ \~'o \""(t~öfdC~\ëf>~~C\ CBL~valuation, zone. above perfs œc\.~~~') ~~C\.\~'H,a~~ a.. ~~~\- \o~~~.,~\-\ot-... ~~~~ \~ ~~~,,-", (t,)\.,)+- ~ \()~~c::. ~~.. ,~\~\t: ~~\X\.,~:" "-I~\..~~~\;..\~ ~~\- \0 ~~,gko~\~s. ~~~~~ ~f';~ ?Q.~,\~~~~\~ ~~~ s~\E.~ ~~~o('o.. ~c::.. kr\- ~c~ Proåuc.tion Log: Type i Evaluation \XC'c~~"è:.. ~o ~-\c.,,"". CONCLUSIONS: . ? art !l: 1:'101 l' <OS} \,,,,"':.:.w Iw".~ ~"<f)~ ~\£). ~,-\ r-€S~ \\.(\ ~, ?art: ;2: t-'\,r'\c>\',~'i ~~~~\->ttè\'"\ S~,\\.c~ ~ ~IÍ'\. ~o~<o<!)~~c; Q..~ç-~\.\'\~(:)~'-~":\<tc....~" ~ . . ~;Lrr~( ~O.--\ -a~ \ Conoco Phillips Ala5ka,lne" . . Daily Drilling Report .,.. ¡.IOaNU, MBERËVENTOD¢RoDE 24HRSPAOG' TMD TVD IDFS' REPTNO. "[OATE 6,933.0 3.~07.0 8.00 . .. 9 7/312004 '.. II'IELDNAME/OCSNO.' AUTfoIMD IDAILVTANG ...¡CUM.TANGO· Doy,pn141. Wêst&ik1'.071.0 0 ACCIDENTS LAST 24 HRS.? DAILY /NT WIO MUD CUM INTANG wi MUD PJ~M & PU 8-1/2".BHA... ..0 0 24 HI'! FORECAST DATE OF US1' SAFETY MEETINQ DAILY TOTAL CUM COST WI MUD MU BHA, RIH,. PU 5" DP. Dr.1 shoe & 20' tJ9le, LOT, DriH ahead . 6129/2094 501.820 . 2,100,09a LITHOLOGY IJAfll-I"'S ÒF SERVICE aHA HRS SINCE INSP LEAI<O"FF AFE AUTH. .. ... .. . 13.90 . 1oo~5112 LA$TSURVEY: DATE TMD !HC AZIM LASTCASING NËXT¢.ASING LAST80PPRSSTEST 7/21200.4 6,897.53 ~0.830 .193.990 9.625 (in) @. 6.926.3 (~) 5.500 (in) @ 11.S;;S.0 (ft) 6/29/2004 'DE~SITY(ppg) 9.30 j pp . ¡ecD! I MUD DATAl OAILYOOST ¡ 0 I CUM.cosT I" 0 ;1~:~:) ~~Sl w=~! FC~~SOL'I OIU;A!·I.%S;1~:~T.! P:%;~~f 1 CII ca. ~2S LI~f! ES BAAIlÌÒj. 3 . I.. BHAI HOLECONDITIQNS 'laITNO; I ? B"HAWT.BELOWJAAS . . SÌ'ft\NG wi UP sTAIÌ\lGWT_DN I SJR.ÌNGWT.ROT ro~QUE/UN~ I . BHAi.~NG1H. ... I. '. 1,C!~8.68 .ITEMDJ:~RwnON . . NOJ!S LeNGTH O.D. .1' ID. CONN SIze . coNN TYpe 1 1.00 12.250 1 41.23 12.125 1 3.15 7.625 1 6.00 12.125 1 31.00 8.000 1 30.94 8.000 1 30.98 8.000 1 2.48 8.000 3 90.57 5.000 1 29.86 6.250 26 785.47 5.000 1 6.00 12.250 5.000 .. WELL NAME; . .., ~ ... . 1E-1J2 ~ $UPERV1$OR I RIG NAMe & NO. Dearl Gladd~n/$hane CI9 n1334@ppco.co CURRENr STATUS Bit Autotrak Gen 1.5 CroSSQver - Non~ag Stabilizer.- NonMag Dr!.!,' Pipe - Non·Mag 4 CO~'p Serv Drill Pipe - Non-M~.9 4 comp Se.rv Drill Pipe __ Non-Mag 4. Comp Serv Cros$over Drill P¡p.~ . HeavyWgt Jars 'Drill Pipe -.Heavy Wgt . . Ghost Reamer .. . Drill Pip4) . ~"S . ·16~~:7NO. \... ~~~:~~;I·· .. .. . . BIT OPERATIONS PR¡;SS I p eirr I HRS I 24Hr DlST 24~rRoP ! cü~ HRS I CUM DEPTH I CuM ROP . .". -I. OPERj%,TION$,SUMM4¡::1V .. PHAsE INTRM1 POOH to aHA. .... ~ INTRM1 Download MWD & UD sama. . INTRM1 _Pull wear ~ushing & .':fI8ke dummy run witl1. landing jt. Install tes!.plug. '. INTRM1 Change out top set of rams to 9-5/S' and test to 3500 psi high & 250 psi low. Chart 5 min. RU equip. to run 9-5/8" csg. PJSM on running 9-518" csg. . Run'g-5IS" casing to 3015' MD. At 1~-3I8" osg shoe. U~ 115K & ON 98K. èircui.ate èasing at 13.318" $l'IOa, staging up to 7 BPM @400 psi. . CÕf,tlnue running 9-518" csg tö btm. Worked thru bridge at 4024' MD. Total 175 jts ran. ....... BIT / RUN 2/ ....\ . . 3 .. ....\ .. I ., SI,lE . MAN~F.· TYPE 12.25~ HUGHE.S.CHR MXC1 . BIT I RUN. woe' Ff'OM :TO HOURS CODe 00:00 01:00 1.00 DRILL P 01:00 03:00 2.00 DRIL.LP .. 03:00 04;00 1.00 CAse p 04;00 05:00 1.00 WEL.CTL P 05;00 06:30 1.50 CASE P 06:30 07:00 0.50 CAse p 07:00 12:00 6.00 CASE P 12:00 13:00 1.00 CASE P 13:00 18:30 5.50 CASE P m'd 9££1: S9C:: ¿06 RPM ¡' GPM lROUBLI; . Sue TRIP PUL.D OTHR eOPE RURD 8m RUNC CIRC RUNC . I INTRM1 INTRM1 INTRM1 INTRM1 IN1RM1 . Page 1 of 2 3.000 2.875 2.875 2.875 2.875 2.875 3.000 2.250 3.000 2.750, 4.281 ,.' .. "W ""'... ....... DB'TH IN DATE IN, I-O·O-L-B-G-O·R I 3,()45.0 6/30/20" 2'1-~T-M~E'1.EC-TD . ~ . . Sll3M / 9lè!G DES9RIPTION . . . . . Pr1nted; 8/512004 4:41:38 PM SC:::60 Þ00C::-Þ1-J3G . . 1E;-11Z' Conoco Phillip5Alaska, Inc.,.. Daily Drilling Report I JOe NUMBER I"YE~DC~DE l:w HRS PRO~ IT~~933.0 Page 2 of 2 WELL NAME ¡TV!) .' DFS 3.1307.0 8.00 ¡ REFt ~'. I D;~~004 21 ;30 00:00 2.50 CEMENT P PUMP opeRATIONS SUMMARY "1 PHASE'· . ." .... oeSCRIPT10N· . IINTRM1 m C¡rc & eond m~d for CQm8nt~ ~i.JD Frank's run-;¡¡ng tool & MlU Döwell cement head. ~. . .. . a, INTRM1 R/U Dowell. Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 4.0 bpm @ 230 pSI, Shut down. Test Jines to 3500 psi, Continue pumping CW100 to total of 40 bblS at rate of 5.0 bpm @ 280 psi, Mix & pump 40 bbls MudPUSH II mixed at 10.5 ppg at rate of 4.6 bpm @ 265 psi, Shut down and drop btm plug, Mix & pump 649 sxs (260.1 bbls) DeepCRETE cmt mixed at 12.5 ppg wi additives at rate of 5.5 bpm @ 300 psi, Shut down and drop top plug, Displace emt w/3 bbls fresh water, Shut down and turn over to rig pumps and continue to displace wI 521.2 bbls 9.0 ppg oil based mud at rate of 7.5 bpm @ 300 to aoo psi, Slowed rate to 3.0 bpm @ 500 psi for last 10 bbls of displacement, e;'.~,~ed calculated displacement of 519.3 bbl plus:3 bbl (112 shoe track) for total displacement of 522,3 bbl. Plug did not bump, Rosts held· OK, CIP @ 23;59 hrs 713/04. Had good returns throughout job, reeiprocatéCl c;;l~ing . throughout job & finally set on btm @ 3656 stks into displacement UP 200K. .J I DN. 10SK with 9.5/~" esg on btm '. - .~:~~12:0H;.~~$ . CEC::~T JJAOU8L~ CI:~ä' :,.--. ... . ". . " ...." .... .~. 24 HR SUMMARY: Cont. POOH. Download MWD and IJD same. Pull we¡u- ring & J1'I$ke dummy run w/landing it. Install test plug. Change out top rams to 9·5/8" & test RU O$g equip. PJSM. Run O$g. Circ at 13-3/8" shoe. Cont. run esg to btm. Circ & condo RU Dowell & c.mt esg. Fuel .... -... Water, ?rilling . USAGE 275 520 . . PERSONNEL DATA N.0. HOURS I "CO~PANY . 3 . Doyon Uni':'Brsal Sérvlc.~ 3P M·I Drilling Fluids 2..1 APC. Alask~ Petroleum _ 21. . . MATERIALS rC;ONSUMf'TION ON HÀND . m:M . . 11.110 Water. Po~able 560 SERVICE NO:. 6 2 2 '.-- <COMPANY ConocoPhilliP$ C'?fOpany Doyon ,?rllling 'nc .Baker Hughes Inteq ~~er Hughes Inteq - D SERVICE HOURS . ITEM UNITS gal$ bbls UNITS gals USAGE . 3,541 ON. H~ND 14.073 RESERVOIANÀME 1E-33 . ·"11 ~~112 :·RESERVO.IR AND INTERVAL DATA ZONE .... . I rc;:o~ ¡. eAs:~5 ~11 05~ ... .. .. COMMEN1S Prn'~d: 8/512004 4:41:36 pM 20'd 9££1: £92 ¿06 Sll3M / 8lèJQ £2:60 Þ002-Þ!-J3Q . . Page 1 of 2 Conoco Phillips Ala~ki1, Inc. Daily Drilling. Report WELL NAME 1E-112 '.. l"oe~UM8ERIEV~D~~DE¡24HR$PI'I~G T~~933.0 IT~~07.0 ÞI'Sg.oo SUPERVISOR /RIG NAMlifc NO. jflEl.O.NAME/OCSNO.·· AuTHMD' I DAlL1 TANG Dearl.Ç?Jadden/Shane_CIO n1334@I?!?CO.co Doyor. 141 .. West Sak .. 11.071.:.9 Q CUFlR,"NT STATUS ¡ACCIDENTS \.AST 24 HRS.? OAlLY INT WIO MUØ .. POH frpm csg test wi ens. ... . .... 0 24 HI'! I'ORECAST I DAre OF LAST SAFETY iCEETING DAILY TOTAL Co.nt. ?OH, MU Bt:iA. RIH, Dr sh~e +20' hole. LOt Drill ahead_ 7/..3/2.004 . , 305.226 LITHOLOGY ¡JAR HilS OF SeRVIcE ! ilHA HFlS SiNCE INSP.. , t..£AKo.FF . . AFE . -. _.,. . . . . . . . 13.90 . 10935112 LAST SURVEY: OATE TMD INC AZIM ¡LAST CASING ¡HIDer CASIN(¡ LAST BOP PII&$ TEST 7/2/2004 e,a91.53 80.830 193.990. 9.625 (in) ~ 6.926.3 (ft). 5.500 (in) ~ 11,358.0 (ft) 6/29/~004 De¡';¡~(ppg) { . 9.! 0 !pp I.. . .., I ECD I MUD DATAl DAILY cosrj 0 I CUM c~T'1 0 :: 1.;;1;' \ ~~~s_\~~P[F;~SOl¡:OI¡AT r %S~njBT-·!P.~PM PJ¡t \ CI \ Ca I:H2s !LlMElE~. ~HANO. I" 5 I BHA I H6L~ CONDiTIQNS fe'T NO. I BH~~WT;BELOW~.ARS¡: STRINGWT.UP --¡ STRING Wf:_ON J' STRINGWT.ROT I TORQUE/UNITS ... ¡BH~~~5:GTH ... . ...h., ! .. ." .~M D.ESCRIPTlON NO J'ffi LENGTH O.D: 1.0. CONN SIZE CONN :TYpe EA FlETRIEVAMAïlC 14.84 8.430 Crossover 0.75 6.250 Drill ~'!pe 1. l 5.000 IFlePT NO. !DÁTE 10 7/4J2004 I CUM. T.ANG 0 CUM INtA/IIG WI MUD . .0 CUM COST W/ MUO . 2.405,319 AVTH. 2.125 4.2S1 B!T/RUN .. ¡.. 3/ 4 ....... . .. ....SITS.. SIZE 1 MANUF. ¡TYPE ¡SERiAl NO. ·1 JETS OF! irA B..500 HUGHE.S-CHR HCM~05 71 011 ~.5 12/12/12/12112/ ...-..... ~...... ....-... DEPTH IN DATE IN I-O-D-L-B-G-O-R I· 6..933.0 '-7/412: O~O-NO-A.!?-I.NO-HP BIT OPERATIONS ." L PRESS I...Þ BIT '1" ...HRS ! 24Hr DI5T ¡ 24Hr RaP ¡ CLI!o' HRS I CUMI:>.EPTH CÜMROP . . . . . . ., . . OPERATION~SUMMARY PHASE INTRM1 INTRM1 INTAM1 .' BIT/RUN j RPM ..... ¡ -. GPM woe·' FFiOM':l? ., HOURS. OO~OO 01 ;30 1.50 01 :30 02:30 1.00 02~30 03:30 1.00 CODE rOUBLE SUB C~MENT PULD WELCTL OTHR DRILL P LOT WELCTL. P I EQRP .. WELCTL P OTHR DRILL P PULD INTRM1 PROD I 03:30 05:00 1.50 05:00 05:30 0.50 05:30 09:00 3.50 INTRM1 .... 09:00 12:00 ¡ 3.00 DRILL P TRIP PROD ... 12:00 13:30 1.50 DRilL P TRIP PROD 13;30 14:30 1.00 DRILL P TRIP PROD 14:30 15:30 1.00 RIGMNT P RSRV PROD 15:30 16:00 0.50 I DRILL P T¡::¡IP PFlOD 16:00 16:30 0.50 DRILL P CIRC PROD 16:30 19:00 2.50 CASE T EQIP DEar PROD .. 19:00 22:00 3.00 DRilL T EQI? TRIP PROD [Ø'd 9[[1: S9ë: ¿06 DESCRIPTION ... .~, . -. RID çement head.& UD 9-5/8" landing it... _ ..~ Install Vetco Grô!y 9-5/8' pa¢k off. Test $~me to. 2500 psi for 30 min- OK. Rig up & pump down 13·3/8' X 9-5/8' annulus w/9.5 bbls mud, pumped away ..- ~ bbls. monitor for 10 min held 480 psI. Leak off at 540 psi = .13.5 p)g EM~..:- Chsnge out top rams to 3-1/2" X 6'. jest same to. 250 psi low and 5000 psi high. - OK. RIO test i.t & install wear bushing: . Pick up 8-1/Z' BHA. Bit, AutoTrak Gen 2.5, ORD caliper tool, MAP sub, NMFS. NM Stab, 3-NMCSDP. XO, 3-HWDP, Jars, 2-HWDP, 21 jts S" OP, & 8-1/2" Ghost Reamer. PU 76 íts 5" DP from pipe sh~d. Shallo.w test AutoTrak 30 min at 160..0' MD. Cont. ~U 5" DP fro(fl pipe shed'..,TotaI114 its PU from p~pa shed. ~_----. RIH fro.m derrick to 6?6S' MD. Service rig, ¢.ut 90' drilling. line. .... RIH to 6753' MD. Wash 116753' to 6842' MD. ragged up on emt at 6842' MD. §' above fl~at collar (5.~tk5). CBU for cssíngtest. ... Attempted to test 9-S/6" esg with no success. 1st attempt - pressured up to +- 2900 psi max (could no.t build to 3000 psi). Bled off to. 1000 psi in 5 min. 2nd att'!mpt - pressured up ~ 181 0 ps~ max. Br~ off to 700 psi În 5.r:nin. Pump .dry jo.b an~ POOH. . Prir>t&cI: 81512004 4:41:09 PM Sll3M / 8lèJG Sè:60 Þ00ë:-Þ!-J3G ,,^' " '...., ...M a..... 24 HR SUMMARY: RID cmt equip. Install packoff & test. Clear 13-3/8" X 9-5/8' ann1.Jlt,Js. C/O top rarM & test. UD test it, install wear ring. PU BHA. PU 114 its Dr=> 1/ shed. Cut drlg.Une. RIH tQ bt':1' CBU. Attempt_csg test - failed. F>.<:>OH. MU RTl"$ &_TIH to test csg. eE;RSONNEI.,. DATA, .' NO. 'HOUR$ I . COMPANY· ·1' 3 Doyon Univer$~.1 Service 30 M.I.ÇIrilling Fluids 2 APC - Ala$ka Petroleum .2 '(Other_" .. WELl. NAME .",. fflOM 22;00 22;30 TO I MOOR$ 2NO I . a..50 23:00 0.50 23:00 1 00:00 1.00 . COMÞAN.Y Con~coPhjlfips C0m.pany Doyon Drilling Inc Baker Hu¡;¡heS Inteq Baker Hughes I.nlec¡ 0 D ITEM Fuel Wate:!.Drilling _~~SERVOIR NAME 1 E-33 Þ0"d 9£:£:1 S9C: ¿06 .1E-11.2 CODE DRILL T DRILL T DRIL.L. T .. UNITS gals bbls . . . Conoco Phillips Ala$ka, Inc. Daily Drilling Report JOBNUM8EAjEVENTcODE !24H1'ISPAOG ITMD ITVD .... oM I ODA .' ". 6.93~9. 3,607.0 . Page 2 Of 2 DFS ..' 9.ºO I FtEPT NO. 10 IOÄ-r¡¡ ]/4/2004 . " - " - . ... . .' OPËRATIONS SUMMARY 'T!I~UalE' SUB... PHASE I... ' . DESCRIP110N EQIP p'~LD PROD ,.UD AutoTrak, br~akdown & remove so~rces. eO!p PULD PROD M/U Baker Retrievomatie Packer per Baker rep and RIH to 70' MD in order to pressure test casing hanger & pup. Closed bag & Pressured up DP to 1180 I .~ I psi and bled to ~70. psi in 2 min. Tested backside to. 1640 psi, helcl5 min. EQIP ¡TRIP PROD E~IH f170' MD to 7.~0' MD. .. '" SERVICE ... SERVice NO. .. HOURS 6 2 2 1 ..MATERIA.LS I CONSU~P.TION ON HAND ITEM ..."', ...._,. 10,780 Water, Potable 460 USAGE . ... ~,471 ON HAND . .13,S01 UNITS gals USAGE 330 1,035 I . 11E-112 RESERVOIR AND INTERVAL DATA ZON~"!-'~~6aJ"BAS~ 2 1105.0 . COMMENTS Printed; 815/2004 4:41;09 PM Sll3M / 8lèJQ 9C::60 Þ00C:-ÞI-J3Q Conoco PhillipsAla$ka, Inc~ Daily Drilling Report WELL NAME ¡JOB NUMBER. . íEVENT CODE 124 H~$ PAM' TMD ¡TVD I DF$ . 1E-1.12.. I ODR 817.0 7,750.0 3.595.0.L 10.00 supeAVISOR !RIGNAMEINO. . FIELDNAME/OCSNO. AUTHMD DAII.V TANG -º~arJGladdenlShant'J.CIO n1334@ppCQ.¢O Doyon 1.41 I West$~ 11,071.0 0 CURRENT STATUS .. . I ACCIDENTS LASTZ4 I1A$.? DAILY INT wfO MUD J:lerforming low-~.ide ~90logical si<;tetrack at 7800' MD,. .. 0 24 HFI FORECAST DATE OF LAST SAFETY MIiETING DAILY TOTAL Drill 8·1/2" A-Sand LatÐral. 7/3/2004 111 969 .¡ JAR HFlS OF sERvice 18H. A HI'IS SINCE INSP I LEAKOFF I AFE . ...' AUTH. _ . .' n 12.82... 1Q93S11¿ ..... LAST SURVIiY: I)ATE TMD rNC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 7/5/2004 7,972.41 92.480 lS4.010 9..~~5 (in) @ .§,926.3 (ft) 5..500 (in) @ 1.1,358.0 (tt) 6/29/2004 PENSrrY(PP9)! 9.20 1 PP I ~JECDI (MUD DATAl OAtlYCOST ¡ 0 '00 ICUMoosT ¡'" 0 FV ! PVI'fP !. GELS ¡ WLIH~P! Fcrr.SOL! OILJWAT I' ~ndIMBT ., PWpM" !.. ptfMf~l. .j_ Os I t.f2~ .1.·3L1.MOOE ¡ 6E8S0" 64,. 22/24 121g2 14.8 1/ J18 ... I / / _ BHA NO:] 6 In SHA I HOLE CONDITIONS J .~ITNO. T 3R~.~ 'aHA 'NT. BE~OW JARS!.' Sl1tIHG WT. UP STRING W!..~N . ... STAfNGW'[. >RÖ:¡' !. TORQUI:/UNITS' [ ~HAl;.eNG.ll1 .' ...17 . . 156 ... .68 .. . 100. .. 8tt-lbf... 900.04.._ .. ITEM !)I:SCFIIPT1ON NO .,ITS LENGTH . 0.0. . r I.D. . CONN SIZE CONN .'TYPE 1 1.00 8.500 I . 1 49.20 8.375 1 8.13 8.375 1 4.80 8.375 1 2.33 6.$00 1 4.19 8.375 1 29.20 5.000 1 29.20 5.000 1 28.53 5.000 1 1.22 6.375 3 90.57 5.000 1 29.86 6.250 2 60.59 5.000 21 650.22 5.000 1 7.00 8.500 5.000 . . LITHOLOGY Bit HCM605 PDC AutotraK Gen 2.5 .ORD Caliper To~1 Map Pressure SUI) NN~ XO Float Sub Stabili;~r . NonMag Drill Pipe ~. Non·Mag 4 Comp Serv prill Pipe - NOt't·Mag 4 COf!!.þ Serv Dritl Pipe:. Non-Mag 4 Comp Serv Crossover Drill Plpe,.Heavy Wgt Jars Drill Pipe' Heavy w.gt DRILl. PIPE Ghost Reamer Drill Pipe Page' of2 ¡REPT NO. ". IClATE ... 1 t 7/512004 ¡ CUM. T,.HG 0 CUM INTANG WI MUg o CUM COST W, MUD 2,517,2~ 2.750 2.7óO 2.813 2.750 2.750 2.625 3.000 2.250 3.000 4.281 2.750 4.281 " .. '" .'. .. SIT$ . '. .. '''.m ·SR R.81fT/' RV~_ 6 I.: . SIZI:: ·1 . MANUF. . ¡TYPe ¡SERIAL NO.!. JETS OR TFA . . ,. DEPTH IN DAllii IN . I -O-D-L-8·G-D-R 8.500 HLJGHES~ëHR "HCM605' 7101195" . 12Ï12112112112/... 6,134.0. 7/5/2ÖO{~.,.B-r-Ä~D~2-RO'TD alT / RUN 3RR1/ sl· ." . . srr OPERATIONS ... woe I FlPM t ~600' Pili ¡ PRE~! P err. . ¡ HRS I. ~4H~' DIST I 5/20···ä'O/110. 3,000 1,563 4.60 817.,0 ... I. ..... ,. SURVEY. ÇtATA AZIMUTH T.V.D.. NisCUM E/WCUM SeC'nON I rJ.~. 194.490 3,612.81 -2,764.7 3.066.52 2.405.1~ 7,537.97 19~.650 3,620.24 ·2,856.2 ~,042.74 2,498.72 7.631.44 195.460 _3.622.76 ~2!946.7 3,0.16.42 2.59,1.31 7,724.42 196.050 3,6~.55 -3..036.72,993.31 2,682.54 J,817,26 192.450 3,619.18 .3,126.1!2,970.35 2,774.97 7,91.0.20 ...190.170 3.614.75 -3.2~.6.5 2,952.25 2,866.88. 7,972.41 24H~ ROp' I CUM H~ '?l'M·DEPut I CUM'RÖP 177:61 4.60 I 817.0. 177.61. M.D. 6,976.84 1.!.o73.70 7,167.39 ?,259.86 7,353.24 7,445.60. INCL.; 82.700 SS,310 88.610 91.65.0 92.4~.0 ! 93.0.00 INCL. ¡ 93.83<> 93.720 93,710 1)3.53.0 92.64.0 92.480 : ... .".. .. n,,, AZIMUTH T.V.D.. HIS CUM iJW CUM SECll0N .-. .... ... " . 187.38.0 3~.609.25 -3,397.72.938',19 2.959.00... 187.240 3,603..10 .3.400.2.2,926.32 3,052.26 186.140 3,597.07 ·3,492.3 2,~15,5' 3,14?04 1S4.76.o 3~S9L21 -3,684.62,906.71 3,237.68 184.280 3,5a6.21 -3,67J..1 2,899.40 3.330.43 184.019 3.583.4~ ·3.739.1 2,894.91 3,392.53 S0'd 9£n S9ë: ¿06 Sll3M / 8lèJŒ Pri~(e<t Bl5t.i!Q04 4:40:37 PM 9ë::60 v00ë:-v~-J3Œ ConocoPhillips Alaska, Inc. . Daily Drilling Report IJOBNUMaERIEVENT~Ot1¡¡ 24HRSPROG .... TMD L OPR B17.0 ._. 7,750.0 . WELL NAM~ 1e-112. FROM .TO , . HOURS' CODE TROU8LE SUB ... 00:00 01:30 1.50 DRill T EQIP TRIP 01:30 02:00 0.50 CAse T EQIP MIT .--, .~'. 02:00 03;30 1.50 DRIll T EQIP TRIP 03:30 05:00 1.50 CASE P MIT 05;00 08:00 3.00 DRILL T EQ¡p TRIP 08:00 08:30 0.50 DR~~ T EOIP PULD 08:30 09:00 0.50 DRILL T 'EQlP PUlD 09:00 12:00 12;00 12:30 12:30 14:30 DRILL T eOIP DRILL T eOIP CEMENT P TRIP TRIP DSHO 3.00 0.50 2.00 OPERATIONS SUMMARY ! PHAse ... . INTRM1 RIH f/760' to 3540' MD. - . ~- '-" INTRM1 set ÞKR & pressure test backside (casing) to 1500 psi. held 5 min. Increased e.ressure up to 300~ psi, held 5 m~n. INTRM1 AIH t/3540' to 6830' MD. un "_...._ INiRM1 Set PKR above shoe track & below lowest collar. Test 9-518" casing to 3000 psi on chart.!or.30 min - OK_ '. ." ~A POOH fl 6830' MD w/ Baker Retrievomatic Packer. .. . lJ.D Baker Retrievo"2atic Packer & c~e!n rig floor. _ Pick up 8-1/2" aHA, Bit, AutoTrsk Cen 2.5, ORD caliper tool. MAP sub, NM!=S, NM Stab. 3-NMCSDP, XO, 3-HWDP. Jars. 2-HWDP, 21 jts 5" DP, & S-1j2" Ghost Reamer. RIH to t)~OO' MD. Sf'lallow tested ALJtoTr~k at 1454' MD. RIH f/ 6100' to 6842' MD. . . .-, Drill out cement. float collar @ 6848' MD, cmt. shoe @ 6925' MD. emt to 6933' MD. Drill new hole tf 8933' to 6953' MD /3610' TVD, WOB = 5-10K lb. 600 GPM @ 2900 psi, ROT:: 110 RPM. UP 135K, DN 76K, ROT 100K. TO (on/off) 9/~. Circ hole clean. .. ... Rig up & p$~orm LOT of 12..~ EMW wI 9.2 i?e,Q OBM. 678 p$¡~.3610' ND. Drill 8·1/2" /'Iole with AutoTrak f/ 6953' to 702$' MD. WOB;; 5-10K Ib, 600 GPM @ 2900 psi, ROT ..110 RPM, UP 145K, ON 75K, ROT 102K, TO (oJ"l/off)ß·5/8. . Circ hole.c:I.san... . . Perform PWD base line test. Clean hole ECD's at 600 GPM & 110 APM '" 10.26 ppg eM"Y.. .. . .. .... Drill 8-1/2" hole with AutoTrak fl 7028' to 7750' MD /3595' TVD. ADT;; 4.6 I hrs, woe = 5-20K Ib, 600 GPM @ 2900 psi, ROT = 110 RPM. UP 156K, DN aSK, ROT 100K, 'fQ (on/off) S/S.._ ...'_ INTRM1 INTRMl INTAMl INTRM1 I'NTRM1 IINTRM1 14:30 15:00 0.50 DRILL P CIRC INTRM1 15:00 15:30 0.50 DRILL P LOT INïRM1 -. 15:30 16;15 0.75 DRI!.L P ORLG PROD I 16:15 16:45 0.50 DRILL P CIRC PROD 16:45 17;00 0.25 DRIll P CIRC PROD -- 17:00 00:00 7.00 DRILL P DRLG PROD j . Page 2 óf 2 I TV!> IDFS IRÈPr NO. 3,§!15.0 10.00...! 1 DATE 7/S/2004 "..,. DESCRIPTION .. .-. ", ..,. .. 24 HR SUMMARY: RIH to 3540'. Test csg to 3000 psi - OK. RIH to 6830'. Test csg to 3000 psi on chart for 30 min - OK. POOH w/ PKR. PU BHA & RIH to 6M2'. Drill out shoe track + 20' new hole. Perform L.Or. Drill to 7028', Perform PWD baseline test. Drill to 7750' MD. . - - . .... . PER~ONNEL Q~TA . ~. HOURS_ . C0Pt!PANY . 3 Doyon Universal. Service 30 M- Drilling Fluids . 2 APC - Alaska Petroleum 2 I Other I MATERIALS' CONSUMPTION .' ON HANO 1¡.·.reM 10,560 Water, Potable . 370.1 .. COPtWANY Con.~coPhillip$ Company Doyon '?.rimng Inc .Baker Hughe~,!nteq Saker Hughes Integ.- D SERVICE ITEM UNIT$ gals bbls . USAGE 220 90 Fuel Water, Drilling SERVICE . NO. tiOURS 6 2 2 1 r_ UNITS gals USAGe 3.820 ON HAND 13.801 . RESERVOIR NAME 1 e·S3 RESERVOIR AND INTERVAL DATA !1E-112 ZONE . ·'1' ro~40\f!AS~2"1'25o. .... COMMeNTS 90-d 9£[1; S9C ¿06 Printed: 6/5/2004 4:40:37 PM Sll3M / ÐlèJQ 9c:60 Þ00c-Þt-J3Q Conoço Phillips,Alaska, Inc. Daily DriJlingReport IJ08 NUMBER ¡EvENT ëoDE !:ì4HF1S p¡:¡QG TMD ITVD jDFS ODR 883.0 6,933.0 3,607.0 7.00 II"IELo NAME I oes NO." AUTH MD I DAilY TANG DQyon141 WestSak 11071.0 0 AC~DENTSLAST24HR$.1··'· 1 DAILY INT WIOMUD ... F\\,IJO Aun 9·5/8" Csg.... 0..... 24 HI! FORECAST DATE OF LAST SAFI£'rY MEETING DAILY TOTAL Aun.~:?I8" c$Q. Circ & con~ f/ cmt. Cmt 9-518" c.sÇ. MU BHA. ... 6/.29/2004... 127t~31 LITHOt.OGY IJA. R HR5 01' SERVICE ¡8HA HRS SINCE INS" lEAKOFF .. . AFE . ... .. 13.90 .... 10035112. '.. LAST SURVEY: DATE TMD INO AZIM I LAST CASING NEXT CASING LAST 80P PRES TES'/' 7/2/2904 6.897.5?. 80.830 .193.990 13.375(Î.ry) @ 3.031.()jft) 9.625 (in) @ . _6,912.0 (ft).fj/29/.2004 ~~NsrrY(ppg)'¡ ~:~ ¡PI;] ....... !r;CDr IMµD DATAl DAI~YOOST'I ..~rCòM¢~ I 0 FV..:PVIYF' I GELS ··I·~~·UH.· THP. j FCIT~SOL ·l O'lJWAT I. %sindlMBT 1 '.. PhII'M .! PflMf ....j... 01 ·Ca ···¡.H2S ¡LIME ¡ £S 54 17/31 13/19 ~.8/' 1/ ,,, / /13.0 ~.-Y /._ BHANO. ,.. ~.. 3 ¡ BHAI HO~E'CONDITI()NS l.srrNÖ. I 2 EiHA WT. BELO.,.,J.ARS ,. STRING WT. UP . .., ¡ srAlNG WT. DN j STRING WT. RO! I . TORQUE I UNITS I· BtoIA. LENG1H ..~ . 21 . 137 107 I 85 .. 10 ft-Ibf 1,05a.6.~ m!"" DESCRIPTION . NO JTS . LENG1H O.D. I.). CONN SIZE CONN TYPE 1 1.00 12.250 1 41.23 12.125 1 3.15 7.625 1 6.00 12.125 1 31.00 8.000 1 30.94 8.000 1 30.98 MOO 1 2.48 8.000 3 90.57 5.000 1 29.86 6.250 26 785.47 5.000 1 6.00 12.250 5.000 ¿0 'd It:llOl . . .. WELL NAME .. 1E-112 SUPERVISOR ¡RIG NAME 4\ NO. Dear' ~ll!ldden/$hane Clo n1334Cppco.co CURRENT STATUS Bit Autotrsk GenJ :5 ~ro$Sover - NonMag . Stabilizer - NonMag ._. Drill Pipe - Non~Ma9 4 Camp Serv Dri'.' Pipe - Non-Ma9~Comp Serv Drill ~ipe - Non-Mag 4 Comp Serv Crossover D.rill Pipe - Heavy 'N.gt Jars Drill Pipe - He~vy w@ Ghost Reamer Dri/lPipe .'. . .... ..... ..... " ... ...SITS.. BIT/RÚN .1 SIze.·! . ·MANUF. I TYPE SERIALNO.! JETSOATFA 2/ 3 .... '12:.250 HUGHES-CHR IMXC'·... 6024547'.. 12i1~16/1611 Page 1 of 2 .. REnNO. JOATE .. 8 7/2/2004 !CUM. TANG;' . . CUM INTANG WI MUD o CUM COST WI MUD 1.59,!!,273 AUfH. 3.000 2.875 ..:t875 2.875 2.876 2.875 3.000 2.250 3.000 2.750 4.281 ..~ "r ... J ....... ...... PePTHlN . DATE IN.' J-O~D-L-e--B-O-A . ;045.0 6/30/200 2-1-WT-M-;-1-eC.TD _......~ BIT/RUN' . WOB . '. ¡ . . ßPr.t . . G7'P4""0' . 2/ 31 I '"/130 ... BIT OPERATIONS PRESS.. ¡ . P BIT . .'. tfFl$· . ì 24J.rr OI$T·I. 24Hr RO~ ! CUMHRsj.s:Ur.t DEPTH. j.CIJM ROP 2,7~~ 969 ... 12.10 I. 883.0 72.98 4O.~0 3,8aS.O. 95.76 M.D; 6,030.92 6,125.96 . 6,217.79 6.31.1.82 ~~. 6,494.59 ·INOJ.... 78.490 80.420 80.920 81.010 80.260 79.980 " " SU.¡:I\fEY DAT'A. AZIMUTH.. T.Y.D. ¡HIS CUM EIW CUM SEemON M.D. . INC!.. 189.270 3,455.13 -,,848.73.25ô'·ã3 1,4.74.30 6.588:~ 79.990 190..720 3,472.52 .-',940.7 3,234:~U 1.567.54 ?,681.58 79.860 189.590 3,487.41 -2,029:~ 3,218.44 1,657.96 6,773.~ 80.450 190.050 3,502.18 .2,121.43,202.60 1.750.66 6,867.451" $0.790 190.070 3.517~~1 -2,211.8 3,1.8,6.57 1,842.~ 6,897.53 .ao.830 190:17:0 3,532.71 -2,298.8 3,170.~! 1.930.46.. ... .,. .. .. AZlMtmf I T.v.D. NIS CUM Ëtw CUM $EC110N . . 191.73'0 3.S~9.13 -2,389.93,152.« 2,023.Q8 . 191.~O 3.565.33 :2,479.23.133.~~ 2,113.85 192.850 3,.581.10 -2,568.03,114.39 2.2Q4.25 1.93A60 3,596.~!. -2,657.93,093.36 2.296.02. m 19~.990 3.601.16. -2,686.7 3.08~.32 2,325.43 . . . . OPERATIONS SUMMARY ... ~ROM< TO . HOURS COD! . TROUBLESU8. PHASE 00:00 12:00 12.00 DRILl. P DRLG INTRM1 DESCRIPTION ..- '" Drill 12-1/4" hole with AutoTrak f/ 6050' to 6810' MD /3588' TVD. ADT = 8.9 hl'$, woe", 20-301< Ib, 740 GPM @ 2400 psi, ROT = 120 RPM. u~ 135K, DN S6K, ROT 106K. TQ(on/off) 11/10. Connectiol'!.gas 700-150~ units, ¿0'd 9£n S9ë ¿06 Sll3M / ~:Jlè!a Pfinted: $/5/2004 4:42:02 PM 9ë:60 Þ00ë-Þ1-J3a . . ¡ø f-{)cr I Transmittal Form r'ill BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: .... Rubin Dtaf:cl1 . Reference: 1E-112PBl Contains the following: 1 LDWG (LAS) Compact Disc (Includes Graphic Image files) 1 blueline - MPR Measured Depth Field Log 1 blueline - MPR TVD Field Log * Note: Due to the short interval covered by this plug-back hole section, and at the request of ConocoPhillips Alaska, this final distribution of data & logs for this plug-back well is limited to the initial field prints and the field supplied LAS. LAC Job#: 693594 Date: Oct. 15, 2004 Date: /cf¡ló <{ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, A]aska 995]8 Direct: (907) 267-66] 2 FAX: (907) 267-6623 fT":;·:··-~:~;~:~:---] ~,,' I ;L" ËÊ ~f":--~ , _'GJU~ ;r:f.~-~-~-~_._.~:---:~-_.~~ - -- ,~§ª . . :;ocf - ð '7/ Transmittal Form r~ill BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: lE-112 Contains the following: 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#: 693594 Date: Oct. 14,2004 Date: /t;/,t</ 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 rj-::'=:-:~:~:--T! ~1=,~',~:=J ¡to ~t ::! ..... ¡~-~.~--~~:~~-:-:-.~*. ¡=~~--~~;-~..~.._--_. -- :::':2 ...,..;....:;0... - .....-. .'- -,.-....p----.-.. ... ...... ......... ~. ~.... ~.,I"'..""..... _''I\: _ ... IIJ _~ ...-..-..,--.......-..,.-.... ,_-...., .....u . . ConocJPhillips e Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 September 13, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 '~"""'...."""...'.."" . . ...,.'~ . . .'. -..' '0 .~, '__ , . ..__,_,·c < Subject: Well Completion Report for 1 E-112, 1 E-112L 1, 1 E-112L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 E-112, 1 E-112L 1 and 1 E-112L2. If you have any questions regarding this matter, please contact me at 265-6830 or Steve Shultz at 263-4620. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad RECEIVED SEP 1 7 2004 Alaska Dil & Gas Cons Comm· . . . ISSIOI1 Anchorage O[~JG1NAL ·~ .. STATE OF ALASKA e AlA~ Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U GINJ 0 2. Operator Name: WINJ 0 WDSPL 0 Plugged 0 Abandoned 0 20AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 191' FSL, 226' FEL, Sec. 16, T11N, R10E, UM At Top Productive Horizon: 2466 FNL, 2418' FEL, Sec. 22, T11N, R10E, UM Total Depth: 1695' FNL, 2250' FWL, Sec. 27, T11N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550300 . y- TPI: x- 553412 y- Total Depth: x- 552839 I y- 18. Directional Survey: Yes 2] NoU 21. Logs Run: GR/Res 22. CASING SIZE WT. PER FT. 94# 68# 40# 15.5# GRADE K-55 L-80 L-80 L-80 20" 13.375" 9.625" 5.5" 5959781 .. 5957145 5952632 .) Zone-4 Zone-4 Zone- 4 Suspended 0 20AAC 25.110 Other _X Pre-Produced Injector WAG 0 5. Date Comp., Susp., or Aband.: July 31,2004 6. Date Spudded: June 26, 2004 7. Date TD Reached: ,/ July 8, 2004 8. KB Elevation (ft): 28' RKB I 99' AMSL 9. Plug Back Depth (MD + TVD): 6200' MD I 3485' TVD 10. Total Depth (MD + TVD): ,/ 11425' MD /3597' TVD ,/ 11. Depth where SSSV set: Landing Nipple @ 508' 19. Water Depth, if Offshore: N/A CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 3031' 28' 2309' 28' 6926' 28' 3606' 6777' 11297' 3582' 3602' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): slots in liner from 7014'-7514', 7759'-8340', 9074'-9551', 9953'-10346',10658'-11202' MD slots are 40 slots/ft 26. Date First Production September 7, 2004 Date of Test Hours Tested 17 hours Casing Pressure 24. SIZE 4.5" 1b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic Test 0 12. Permit to Drill Number: .I 204-091 13. API Number: 50-029-23211-00 14. Well Name and Number: 1 E-112 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ALK 25651 & 25660 17. Land Use Permit: ADL 469 & 470 feet MSL 20. Thickness of Permafrost: 1584' MD HOLE SIZE AMOUNT PULLED CEMENTING RECORD 42" 16" 268 sx AS I 618 sx ASIII, 219 sx DeepCrete 649 sx DeepCrete slotted liner 12.25" 8.5" TUBING RECORD DEPTH SET (MD) 6822' PACKER SET 5780', 6038', & 6777' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a PRODUCTION TEST Method of Operation (Flowing, gas Jift, etc.) Flowing (shared production with 1 E-112L 1 and 1 E-112L2 Production for OIL-BBL GAS-MCF WATER-BBL Test Period --> 979 787 Calculated OIL-BBL GAS-MCF 24-Hour Rate -> 5470 3639 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). f{ I::. eEl VE D SEP 1 7 2004 Alaska Oil & Gas Cons, Commission Anchorage 9/7/2004 Flow Tubing press. 330 psi 27. 1367 Submit core chips; if none, state "none". ROOMS 9fl SEP 2 1 100~ NONE Form 10-407 Revised 12/2003 o WATER-BBL ~'~::~<:-71 ! COMddlON i ~ ':á"t:· I-.:Z:¿) ,()'/ ¡ \iicg¡;:::;,.;r,' I"'''' ........ . _._ L.b--, ~,~~.~~---' CONTINUED ON REVERSE OQIGINAL CHOKE SIZE 129% OIL GRAVITY - API (corr) not available IGAS-OIL RATIO 665 c,( GEOLOGIC MARKERS e 29. e FORMATION TESTS 28. 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-112 West Sak A2 6866' 3596' N/A RECE,\\fEO SEt> 11 7J1Ü4. ' \ C mOì\ßS\I,)~ .~ & Ga. CQt\!hQ, . ~\a~\<.a Q\ þ.1;\c,Mtage 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 N~ ~a~dV Tho~s Signature \ -------, \. ~ - Title: Df1J1ne Kuparuk Drillina Team Leader 4r6~"3 c Date c::r I.., ~ ~ 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-Altemating-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: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 6/25/2004 08:00 - 12:00 4.00 MOVE MOVE MOVE Hold PJSM w/ Toolpusher, Peak truck pusher, & rig crew. Stage rock washer & rig complex's down the pad. Move sub & spot same over well. 12:00 - 15:30 3.50 MOVE MOVE MOVE Spot Pits, Pump Room, Motor room, boliler complex, rock washer & pipeshed. Rig up Complex's. 15:30 - 17:00 1.50 MOVE RURD MOVE Rig up Rig. Complete rig acceptance checklist. Rig accepted on 1 E-112 @ 17:00 hrs 6/25/2004. 17:00 - 19:00 2.00 MOVE RURD MOVE Load pipeshed with 5" DP. Mix spud mud in pits. 19:00-21:00 2.00 MOVE RURD MOVE M/U Diverter system and cotinue to mix spud mud. 21 :00 - 00:00 3.00 MOVE RURD MOVE P/U 5" DP and rack in derrick. Continue to mix spud mud. 6/26/2004 00:00 - 04:00 4.00 RIGMNT RGRP RIG UP Work on top drive, replace traction motor encoder. Test same, OK. 04:00 - 09:00 5.00 DRILL PULD RIG UP Continue PU 5" DP, 29 jts 5" HW, & jars. Rack back same in derrick. 09:00 . 09:30 0.50 WELCTL BOPE RIG UP Perform Accumulator & Diverter function test. AOGCC rep John Crips waived witness test. 09:30 - 10:15 0.75 DRILL PULD RIGUP Clear rig floor and PU BHA. 10:15 - 10:30 0.25 DRILL SFTY RIGUP PJSM w/ directional driller, Toolpusher, & rig crew on handling BHA. 10:30 - 12:00 1.50 DRILL PULD RIGUP MU 16" Bit, 9.5" motor w/1.6 deg AKO, NMDC, NM stabalizer, NM XO, & MPR. 12:00 - 14:00 2.00 DRILL PULD RIGUP MU MWD, initialize & orient. 14:00 - 14:30 0.50 DRILL RIRD RIGUP RU Halliburton wireline for planned surface Gyro. 14:30 - 15:30 1.00 DRILL CIRC RIGUP Pressure Test lines to 1000 psi. Flood system & check for leaks. 15:30·16:30 1.00 DRILL DRLG SURFAC Drill 16" surface hole f/108' to 197'. Spud well @ 15:30 hrs 6/26/2004. 16:30·17:30 1.00 DRILL PULD SURFAC Rack back 5" HWDP & PU (3) 8" Drill Collars. 17:30 - 00:00 6.50 DRILL DRLG SURFAC Drill 16" surface hole f/197' to 740' MD /739' TVD, ART = 2.2 hrs, AST = 2.4 hrs, WOB 10/15K, 500 GPM @ 1300 psi, UP 75K, DN 75K. ROT 75K, TO (on/off) 2/1. Gyro surveys @ 262' MD and 351' MD. 6/27/2004 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drill ahead from 740' MD /739' TVD to 1900' MD /1765' TVD, ADT = 7.1 hrs, ART = 1.0 hrs, AST = 6.1 hrs, WOB = 20/45K. 525 GPM @ 1700 psi, ROT = 60 RPM, UP 102K, DN 92K, ROT 96K. TO (on/off) 4/3. 12:00 - 15:00 3.00 DRILL DRLG SURFAC Drill ahead from 1900' MD /1765' TVD to 2180' MD 11912' TVD, ADT = 2.0 hrs, ART = 0.6 hrs, AST = 1.4 hrs, WOB = 15/20K, 615 GPM @ 1700 psi, ROT = 65 RPM, UP 108K, DN 82K, ROT 93K, TO (on/off) 6/4. 15:00·15:30 0.50 DRILL CIRC SURFAC Circulate hole clean for TOH. 15:30 - 18:00 2.50 DRILL TRIP SURFAC Observe well & backream out of hole to 900' MD. 18:00·19:00 1.00 DRILL TRIP SURFAC TOH on elevators to MWD @ 104' MD. 19:00 - 20:00 1.00 DRILL PULD SURFAC Dowload MWD tool. 20:00 - 20:30 0.50 DRILL PULD SURFAC Rack back MWD tool and UD motor. 20:30 - 22:00 1.50 DRILL PULD SURFAC MU BHA # 2. 16" bit, 9.5" motor w/1.3 deg AKO, NMDC. NM stab, NM XO, & MPR. 22:00 - 23:30 1.50 DRILL TRIP SURFAC RIH f/68' to 2126' MD with no problems. 23:30 - 00:00 0.50 DRILL TRIP SURFAC Wash & ream from 2126' MD to 2180' MD (26' of fill) 6/28/2004 00:00 - 09:30 9.50 DRILL DRLG SURFAC Drill ahead from 2180' MD /1912' TVD to surface hole TD at 3045' MD / 2315' TVD, ADT = 6.8 hrs, ART = 2.8 hrs, AST = 4.0 hrs. WOB = 20/45K, 615 GPM @ 1800 psi, ROT = 100 RPM, UP 124K, DN 72K, ROT 94K, TO (on/off) 5-13/8. 09:30 - 10:00 0.50 DRILL CIRC SURFAC Circulate hole to clear BHA. Observe well. static. 10:00 - 13:30 3.50 DRILL TRIP SURFAC Back ream out of hole from 3045' MD to HWDP at 920' MD. Back ream at 110 RPM & 615 GPM. 13:30 - 14:30 1.00 DRILL TRIP SURFAC TOH on elevators from 920' MD to MWD at 105' MD. 14:30 - 15:00 0.50 DRILL PULD SURFAC Download MWD tool. Printed: 8/18/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 6/28/2004 15:00 - 16:00 1.00 DRILL PULD SURFAC Stand back NMDC, UD stabalizer, MWD, motor, & bit. 16" MXC1 bit grade: 1-1-WT-A-E-I-SS- TO. 16:00 - 18:30 2.50 CASE RURD SURFAC Clear rig floor. Rig up to run 13-3/8" surf csg. Make dummy run with Vetco Grey casing hanger. PJSM with all crews on running 13-3/8" csg. 18:30 - 00:00 5.50 CASE RUNC SURFAC Run 13-3/8" Weatherford Float shoe, 1 jts 13-3/8", 68#, L-80, BTC csg, Weatherford Float collar, 50 of 75 jts 13-3/8", 68#, L-80, BTC csg. Ran 13-3/8"x 16" Bow spring centralizers as follows = 1-10' above shoe, no centralizer between jt. #1 & #2, 1 on every collar on jts #3 thru #17, Total of 15 centralizers and 1 stop ring. Tight spot at 900' MD. Circulate hole clean and continue running casing. 6/29/2004 00:00 - 02:00 2.00 CASE RUNC SURFAC Continue to run 13-3/8" surface casing to btm. Ran last 25 of 75 jts. Float shoe @ 3,031.17', Float collar @ 2,987.94'. 02:00 - 03:15 1.25 CEMENTCIRC SURFAC Circ btm's up with Frank's tool. Break circulation at rate of 2.5 bpm @ 350 psi. Stage up rate to 7 bpm @ 450 psi. Reciprocate csg ?7'- UP ??K, DN ??K. 03:15 - 03:45 0.50 CEMENT RURD SURFAC UD Frank's tool and RlU cement head. Break circulation. 03:45 - 05:00 1.25 CEMENTCIRC SURFAC Circ and Cond mud for cement. Stage up rate to 7 BPM @ 450 psi. Final mud properties 9.2 ppg, 45 vis, PV 15 YP 12, Gels 3/4, PH 8.0. 05:00 - 05:30 0.50 CEMENT SFTY SURFAC PJSM for surface cmt job with Co Man, TP, rig crew, cmt crew, & vac truck drivers. 05:30 - 08:45 3.25 CEMENT PUMP SURFAC Rig Up Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 5.5 bpm @ 120 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 50 bbls, Mix & pump 50 bbls MudPUSH II with red dye added mixed at 10.5 ppg at rate of 5.0 bpm @ 95 psi, Shut down and drop btm plug, Mix & pump 618 sxs (489.98 bbls) Lead ArcticSet III cmt mixed at 10.7 ppg w/ additives at rate of 7.0 bpm @ 150 psi, Followed by 219 sxs (100.35 bbls) Tail DeepCRETE cmt mixed at 12.0 ppg w/ additives at rate of 6.5 bpm @ 190 psi, Shut down and drop top plug, Displace cmt w/ 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace w/421 bbls 9.2 ppg mud (total of 441 bbls to bump plug) at rate of 7.0 bpm @ 400 to 720 psi, Slowed rate to 3.0 bpm @ 500 psi for last 10 bbls of displacement, Bump plug w/1000 psi and held 5 min, Floats held- OK, CIP @ 08:45 hrs 6/29/04, Had good returns thru out job, Reciprocate csg. 15' until dropping top plug, Had 106 bbIs good cmt returns to surface. 08:45 - 09:30 0.75 CASE MIT SURFAC Test casing to 2500 psi for 30 min. on chart -- OK. 09:30 - 10:30 1.00 CEMENT RURD SURFAC Check float equipment -- OK. Flush stack & flowline, RID Dowell cement head, UD landing jt. 10:30 - 13:30 3.00 WELCTL NUND SURFAC UD csg equip. N/D diverter system & clear floor. 13:30 - 15:00 1.50 WELCTL NUND SURFAC N/U & Orient Vetco Gray Wellhead. Test to 5000 psi for 10 min. 15:00 - 18:00 3.00 WELCTL NUND SURFAC N/U BOPE and RlU to test. 18:00 - 23:30 5.50 WELCTL BOPE SURFAC Test BOPE to 250 psi low and 5000 psi high, Hydrill to 250 psi low and 3500 psi high. Test witnessed by John Spaulding AOGCC. 23:30 - 00:00 0.50 DRILL RIRD SURFAC Clear rig floor & install wear ring. 6/30/2004 00:00 - 01 :00 1.00 WELCTL NUND SURFAC RID BOPE test equip. Install wear bushing. 01 :00 - 04:30 3.50 DRILL PULD SURFAC Pick up 12-1/4" AutoTrak BHA = Bit, AutoTrak, NM FS, NM Stab, 3-NMCSDP, XIO, 3-HWDP, Jars, 26-HWDP, Ghost Reamer, Program & load tools, Surface test same. 04:30 - 05:30 1.00 DRILL DEQT SURFAC Shallow Test AutoTrak tool -- OK. 05:30 - 06:30 1.00 DRILL TRIP SURFAC RIH to 2915' MD. 06:30 - 07:00 0.50 DRILL REAM SURFAC Break eire, wash & ream f/2915' to 2941' MD. Tag cement @ 2941' 07:00 - 08:30 1.50 CEMENT DSHO SURFAC Drill cement, float equipment, & 20' of new hole to 3065' MD / 2323' Printed: 8/18/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 6/30/2004 07:00 - 08:30 1.50 CEMENT DSHO SURFAC TVD. 08:30 - 09:30 1.00 DRILL CIRC SURFAC Circulate & displace hole with clean 9.2 ppg LSND mud. 09:30 - 10:30 1.00 DRILL LOT SURFAC RIU and perform LOT w/568 psi surface pressure, for an EMW of 13.9 ppg. 10:30 - 12:00 1.50 DRILL DRLG INTRM1 Drill 12-114" hole with AutoTrak f/3065' to 3098' MD /2342' TVD. ADT = 1.1 hrs, WOB = 5-35K Ib, 740 GPM @ 2500 psi, ROT = 110 RPM, UP 120K, DN 75K, ROT 93K, TO (on/off) 5-14/5-11. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 12-1/4" hole with AutoTrak f/3098' to 4305' MD /2855' TVD. ADT = 8.8 hrs, WOB = 10-25K Ib, 720 GPM @ 2000 psi, ROT = 120 RPM, UP 118K, DN 85K, ROT 102K, TO (on/off) 5-1017. ·"Note: Had 600 units connection gas @ 3400' MD / 2480' TVD. Gas stayed up 200-600 units for two stds, then back below 100 untils by 3560' MD. ·"Note: HotOil reestablished injection into OIA of locked up annular disposal we111E-33. Broke at +1- 3000 psi. HotOil pumped 85 bbls diesel1bpm @ 1350p$I&8Qbbf$water2bpm @ 1600 psi. 7/1/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 12-114" hole with AutoTrak f/4305' to 5565' MD /3347' TVD. ADT = 8.6 hrs, WOB = 10-30K Ib, 700 GPM @ 2200 psi, ROT = 120 RPM, UP 128K, DN 92K, ROT 106K, TO (on/off) 10/8. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 12-1/4" hole with AutoTrak f/5565' to 6050' MD /3461' TVD. ADT = 10.0 hrs, WOB = 10-30K Ib, 700 GPM @ 2300 psi, ROT = 120 RPM, UP 140K, DN 90K, ROT 110K, TO (on/off) 9/8. Pump 30 bbl hi-vis weighted sweep at 5696' MD, saw no cuttings increase on btms up. Had 500 units connection gas at 5880' MD, and 700 unit spike at 5945' MD. Hard spots at 5900' MD & 5940' MD. 7/2/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 12-114" hole with AutoTrak f/6050' to 6810' MD /3588' TVD. ADT = 8.9 hrs, WOB = 20-30K Ib, 740 GPM @ 2400 psi, ROT = 120 RPM, UP 135K, DN 86K, ROT 106K, TO (on/off) 11/10. Connection gas 700-1500 units, background gas 150-300 untis. 12:00 - 16:30 4.50 DRILL DRLG INTRM1 Drill 12-1/4" hole with AutoTrak f/6810' to TD at 6933' MD /3607' TVD. ADT = 3.2 hrs, WOB = 20-30K Ib, 740 GPM @ 2600 psi, ROT = 120 RPM, UP 137K, DN 85K, ROT 107K, TO (on/off) 10/9. Connection gas 700-800 units, background gas 120-300 units. 16:30 - 17:00 0.50 DRILL CIRC INTRM1 Circulate while read logs & pick TD @ 6933 MD. 17:00 - 17:30 0.50 DRILL CIRC INTRM1 Circulate hole clean to clear BHA. 17:30 - 22:30 5.00 DRILL TRIP INTRM1 Observe well, static. Backream out of hole to 3020' MD with no problems. 22:30 - 23:00 0.50 DRILL CIRC INTRM1 Observe well, static. Circulate hole clean at 13-3/8" shoe. 23:00 - 00:00 1.00 DRILL TRIP INTRM1 Pump dry job and POH on elevators to 2000' MD. 7/3/2004 00:00 - 01 :00 1.00 DRILL TRIP INTRM1 POOH to BHA. 01 :00 - 03:00 2.00 DRILL PULD INTRM1 Download MWD & UD same. 03:00 - 04:00 1.00 CASE OTHR INTRM1 Pull wear bushing & make dummy run with landing jt. Install test plug. 04:00 - 05:00 1.00 WELCTL BOPE INTRM1 Change out top set of rams to 9-5/8" and test to 3500 psi high & 250 psi low. Chart 5 min. 05:00 - 06:30 1.50 CASE RURD INTRM1 RU equip. to run 9-5/8" csg. 06:30 - 07:00 0.50 CASE SFTY INTRM1 PJSM on running 9-5/8" csg. 07:00 - 12:00 5.00 CASE RUNC INTRM1 Run 9-5/8" casing to 3015' MD. At 13-3/8" csg shoe, UP 115K & DN 98K. 12:00 - 13:00 1.00 CASE CIRC INTRM1 Circulate casing at 13-3/8" shoe, staging up to 7 BPM @ 400 psi. 13:00 - 18:30 5.50 CASE RUNC INTRM1 Continue running 9-518" csg to btm. Worked thru bridge at 4024' MD. Tota/175 jts ran. 18:30 - 21 :30 3.00 CEMENTCIRC INTRM1 Circ & cond mud for cement. UD Frank's running tool & M/U Dowell cement head. Printed: 8/18/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/3/2004 21 :30 - 00:00 2.50 CEMENT PUMP INTRM1 RlU Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 4.0 bpm @ 230 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 40 bbls at rate of 5.0 bpm @ 280 psi, Mix & pump 40 bbls MudPUSH II mixed at 10.5 ppg at rate of 4.6 bpm @ 265 psi, Shut down and drop btm plug, Mix & pump 649 sxs (260.1 bbls) DeepCRETE cmt mixed at 12.5 ppg w/ additives at rate of 5.5 bpm @ 300 psi, Shut down and drop top plug, Displace cmt w/ 3 bbls fresh water, Shut down and turn over to rig pumps and continue to displace w/ 521.2 bbls 9.0 ppg oil based mud at rate of 7.5 bpm @ 300 to 800 psi, Slowed rate to 3.0 bpm @ 500 psi for last 10 bbls of displacement, pumped calculated displacement of 519.3 bbl plus 3 bbl (1/2 shoe track) for total displacement of 522.3 bbl, PJuodid not bump, Floats held- OK, CIP @ 23:59 hrs 7/3/04, Hadgood I'ètUm$tI'IreJJghootjob, reciprocated casing thrQUghout job & finally set on btm @ 3656 stks into displacement. UP 200K, DN 1 05K with 9-5/8" csg on btm. 7/4/2004 00:00 - 01 :30 1.50 CEMENT PULD INTRM1 01 :30 - 02:30 1.00 WELCTL OTHR INTRM1 02:30 - 03:30 1.00 DRILL LOT INTRM1 03:30 - 05:00 1.50 WELCTL EaRP INTRM1 05:00 - 05:30 0.50 WELCTL OTHR INTRM1 05:30 - 09:00 3.50 DRILL PULD PROD 09:00 - 12:00 3.00 DRILL TRIP PROD 12:00 - 13:30 1.50 DRILL TRIP PROD 13:30 - 14:30 1.00 DRILL TRIP PROD 14:30 - 15:30 1.00 RIGMNT RSRV PROD 15:30 - 16:00 0.50 DRILL TRIP PROD 16:00 - 16:30 0.50 DRILL CIRC PROD 16:30 - 19:00 2.50 CASE DEaT PROD 19:00 - 22:00 22:00 - 22:30 22:30 - 23:00 3.00 DRILL 0.50 DRILL 0.50 DRILL TRIP PROD PULD PROD PULD PROD 23:00 - 00:00 1.00 DRILL TRIP PROD 7/5/2004 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 01 :30 - 02:00 0.50 CASE MIT INTRM1 02:00 - 03:30 1.50 DRILL TRIP INTRM1 03:30 - 05:00 1.50 CASE MIT INTRM1 RID cement head & UD 9-5/8" landing jt. Install Vetco Gray 9-5/8" pack off. Test same to 2500 psi for 30 min - OK. Rig up & pump down 13-3/8" X 9-5/8" annulus w/ 9.5 bbls mud, pumped away 2 bbls, monitor for 10 min held 480 psi. Leak off at 540 psi = 13.5 ppg EMW. Change out top rams to 3-1/2" X 6'. Test same to 250 psi low and 5000 psi high. - OK. RID test jt & install wear bushing. Pick up 8-1/2" BHA, Bit, AutoTrak Gen 2.5, ORD caliper tool, MAP sub, NMFS, NM Stab, 3-NMCSDP, XO, 3-HWDP, Jars, 2-HWDP, 21 jts 5" DP, & 8-1/2" Ghost Reamer. PU 76 jts 5" DP from pipe shed. Shallow test AutoTrak 30 min at 1600' MD. Cont. PU 5" DP from pipe shed. Total 114 jts PU from pipe shed. RIH from derrick to 6565' MD. Service rig, cut 90' drilling line. RIH to 6753' MD. Wash f/6753' to 6842' MD. Tagged up on cmt at 6842' MD, 6' above float collar (5 stks). CBU for casing test. Attempted to test 9-518" csg with no success. 1 st attempt - pressured up to 2900 psi max (could not build to 3000 psi). Bled off to 1000 psi in 5 min. 2nd attempt - pressured up to 1810 psi max. Bled off to 700 psi in5min. Pump dry job and POOH. UD AutoTrak, breakdown & remove sources. M/U Baker Retrievomatic Packer per Baker rep and RIH to 70' MD in order to pressure test casing hanger & pup. Closed bag & Pressured up DP to 1180 psi and bled to 970 psi in 2 min. Tested backside to 1640 psi, held 5 min. RIH f/70' MD to 760' MD. RIH f/760' to 3540' MD. Set PKR & pressure test backside (casing) to 1500 psi, held 5 min. Increased pressure up to 3000 psi; held 5 min. RIH f/ 3540' to 6830' MD. Set PKR above shoe track & below lowest collar. Test9-5IS' casing to 3000 psi on chart for 30 min - OK. Printed: 8/18/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/5/2004 05:00 - 08:00 3.00 DRILL TRIP INTRM1 08:00 - 08:30 0.50 DRILL PULD INTRM1 08:30 - 09:00 0.50 DRILL PULD INTRM1 09:00 - 12:00 3.00 DRILL TRIP INTRM1 12:00 - 12:30 0.50 DRILL TRIP INTRM1 12:30 - 14:30 2.00 CEMENT DSHO INTRM1 14:30 - 15:00 0.50 DRILL CIRC INTRM1 15:00 - 15:30 0.50 DRILL LOT INTRM1 15:30 - 16:15 0.75 DRILL DRLG PROD 16:15 - 16:45 0.50 DRILL CIRC PROD 16:45 - 17:00 0.25 DRILL CIRC PROD 17:00 - 00:00 7.00 DRILL DRLG PROD 7/6/2004 00:00 - 03:30 3.50 DRILL DRLG PROD 03:30 - 05:00 1.50 DRILL TRIP PROD 05:00 - 12:00 7.00 DRILL DRLG PROD 12:00 - 15:30 3.50 DRILL DRLG PROD 15:30 - 16:15 0.75 DRILL DRLG PROD 16:15 - 00:00 7.75 DRILL DRLG PROD 7/7/2004 00:00 - 02:30 2.50 DRILL DRLG PROD 02:30 - 03:00 0.50 WAlTON ORDR PROD 03:00 - 12:00 9.00 DRILL DRLG PROD 12:00 - 21 :45 9.75 DRILL DRLG PROD 21 :45 - 22:00 0.25 DRILL DRLG PROD 22:00 - 23:00 1.00 DRILL DRLG PROD POOH f/ 6830' MD w/ Baker Retrievomatic Packer. UD Baker Retrievomatic Packer & clean rig floor. Pick up 8-1/2" BHA, Bit, AutoTrak Gen 2.5, ORD caliper tool, MAP sub, NMFS, NM Stab, 3-NMCSDP, XO, 3-HWDP, Jars, 2-HWDP, 21 jts 5" DP, & 8-1/2" Ghost Reamer. RIH to 6100' MD. Shallow tested AutoTrak at 1454' MD. RIH f/6100' to 6842' MD. Drill out cement, float collar @ 6848' MD, cmt, shoe @ 6925' MD, cmt to 6933' MD. Drill new hole f/6933' to 6953' MD /3610' TVD. WOB = 5-10K Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 135K, DN 76K, ROT 100K, TO (on/off) 9/8. Circ hole clean. Rig.up'" ~ LOT of 12.8 EMW w/9.2 ppg OBM, 678 psi, 3610' TVD. Drill 8-1/2" hole with AutoTrak f/6953' to 7028' MD. WOB = 5-10K Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 145K, DN 75K, ROT 102K, TO (on/off) 8.5/8. Circ hole clean. Perform PWD base line test. Clean hole ECD's at 600 GPM & 110 RPM = 10.26 ppg EMW. Drill 8-1/2" hole with AutoTrak f/7028' to 7750' MD /3595' TVD. ADT = 4.6 hrs, WOB = 5-20K Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 156K, DN 68K, ROT 100K, TO (on/off) 8/8. Drill 8-1/2" hole with AutoTrak f/7750' to 8023' MD /3581' TVD. ADT = 2.0 hrs, WOB = 5-10K Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 152K, DN 73K, ROT 100K, TO (on/off) 9/8. 1'ß i.. ~ <6.~ _ Backream out to 7800' MD for open hole sidetrack. ~ Perform open hole sidetrack f/7800' MD to 7903' MD. ADT = 3.7 hrs, ~ d S WOB = 0-2K Ib, 600 GPM @ 2950 psi, ROT = 90 RPM, UP 146K, DN 76K, ROT 98K, TO (on/off) 9/10. Cont. open hole sidetrack f/7903' MD to 7961' MD /3585' TVD. WOB = 5-10K Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 155K, DN 70K, ROT 100K, TO (on/off) 7/8.5. Cont. open hole sidetrack f/7961' MD to 8023' MD. Back to total depth before sidetrack at 16:15 hrs. Drill 8-1/2" hole with AutoTrak f/8023' to 8699' MD /3592' TVD. ADT = 8.15 hrs, WOB = 5-1 OK Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 165K, DN 63K, ROT 100K, TO (on/off) 9/10. Drill 8-1/2" hole with AutoTrak f/8699' to 8977' MD /3584' TVD. ADT = 1.1 hrs, WOB = 5-1 OK Ib, 600 GPM @ 3050 psi, ROT = 110 RPM, UP 170K, DN 65K, ROT 100K, TO (on/off) 8/10. Geologist evaluate Logs - Circu, Rotate & Recip drill string - PR 600 gpm, 110 RPM Drill 8-1/2" hole with AutoTrak f/8977' to 9904' MD /3576' TVD. ADT = ?? hrs, WOB = 5-10K Ib, 600 GPM @ 3100 psi, ROT = 110 RPM, UP 175K, DN 65K, ROT 105K, TO (on/off) 10/12 Drill 8-1/2" hole with AutoTrak f/9,904' to 10,948' MD /3604.5' TVD. WOB = 5-10K Ib, 600 GPM @ 3100 psi, ROT = 110 RPM, UP 180K, DN 60K, ROT 105K, TO (on/off) 10/12 Stuck at 10,948' while drilling ahead. (Torque went to 25K ft-Ib). Worked pipe, jars would not go off. Pulled 120K overpull (325K), and pulled free. A small fault(??), is suspected. Recip and rotate, pump hi-vis weighted, sweep, and circ hole clean. Printed: 8/18/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-112 1E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/7/2004 23:00 - 00:00 1.00 DRILL DRLG PROD 7/8/2004 00:00 - 04:45 4.75 DRILL DRLG PROD 04:45 - 05:15 0.50 DRILL CIRC PROD 05:15 - 05:30 0.25 DRILL SURV PROD 05:30 - 12:00 6.50 DRILL REAM PROD 12:00 - 13:30 1.50 DRILL REAM PROD 13:30 - 14:00 0.50 DRILL CIRC PROD 14:00 - 16:30 2.50 DRILL TRIP PROD 16:30 - 18:00 1.50 DRILL CIRC PROD 18:00 - 22:00 4.00 WAlTON EOIP PROD 22:00 - 00:00 2.00 DRILL CIRC PROD 7/9/2004 00:00 - 01 :00 1.00 DRILL CIRC PROD 01 :00 - 06:30 5.50 DRILL TRIP PROD 06:30 - 07:00 0.50 DRILL OBSV PROD 07:00 - 11 :00 4.00 DRILL TRIP PROD 11 :00 - 12:30 1.50 DRILL PULD PROD 12:30 - 12:45 0.25 CASE SFTY CMPL TN 12:45 - 13:30 0.75 CASE RURD CMPL TN 13:30 - 18:30 5.00 CASE PULR CMPL TN 18:30 - 20:00 1.50 CASE PULR CMPL TN 20:00 - 22:00 2.00 CASE RUNL CMPL TN 22:00 - 22: 15 0.25 CASE CIRC CMPL TN 22:15 - 00:00 1.75 CASE RUNL CMPL TN 7/10/2004 00:00 - 02:00 2.00 CASE RUNL CMPL TN 02:00 - 02:30 0.50 CMPL TN PCKR CMPL TN Drill 8-1/2" hole with AutoTrak f/10,948' to 11,010' MD /3605' TVD. WOB = 5-10K Ib, 600 GPM @ 3100 psi, ROT = 150 RPM, UP 185K, DN 75K, ROT 11 OK, TO (on/off) 12/11. ADT = 6.4 hrs Drill 8-1/2" hole with AutoTrak f/ 11,010' to 11,425' MD /3604' TVD. WOB = 12-14K Ib, 550-600 GPM @ 3550 psi, RPM = 150, UP 185K, DN 74K, ROT 111 K, TO (on/off) =12-14K /11 K ft-Ib. ECD - 11.3-11.6 ppg ADT = 2.7 hrs Circ sweep to surface -- MW 9.4=>9.3 ppg, FV 84=>75 sec. Survey and downlink AutoTrak for backreaming. Backream from 11,425' - 7,960' at 100 RPM, 600 GPM. Continue backreaming to 6,900' at 100 RPM and 600 GPM. No problems, hole was clean. Circ hole clean at 9-5/8" shoe. RIH to TD at 11,425'. Pump high-Vis, weighted sweep, and circulate hole clean. Circ and Cond mud. - Hot Oil heating OBM in storage tanks - Had two mechanical problems w/ Vac Trucks( 1 tracter had to be replaced (leaking radiator) & 1 had a problem with pony motor. Displace hole to new solids free OBM. Fin Displacing hole to new solids free OBM and circ hole to shear new mud, circ at 600 gpm at 3,500 psi. rot wt 111 K, up wt 185K, dn wt 74K Precautionary pumped out of hole from 11,425' to 6,900' to up inside 9 5/8" csg with no problems, pumped out at 420 gpm at 1,700 psi Monitored well at shoe-static Pumped dry job and POOH on elevators from 6,900' to 63', stood back HWDP Down loaded MWD/Auto trak and stood back same Held PJSM on RU and running 5 1/2" liner RU Doyons 5 1/2" liner running tools PU and ran 5 1/2" liner per well program, ran 5 1/2" ROT silver bullet guide shoe with no float, 144 jts, 4,465.33' of 51/2" 15.5#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 64 jts (1,969.'15') of blank liner and 80 jts (2,496.18') of slotted liner, ran 1- 5 1/2" x 81/4" spiralglide centralizers 1/jt to shoe (144 total) then ran 10 restrictor packers with 20 spacer rings placed on blank liner to isolate shalè sections, liner wt 77K up, 68K dn 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, liner wt with hanger 80K up and 70K dn RIH with 5 1/2" liner on 5" DP to 6,850' (Csg Shoe @ 6,926') with full returns and no problems Circ 1 DP volume at csg shoe, staged pump rate up to 6 bpm at 550 psi, st wt up 106K, dn wt 84K, set torque limiter on top drive to 8,500 ft-Ibs and est rotation at 10 rpm's with 3,500 ft-Ibs torque Cont RIH with liner on 5" DP from 6,850' to 8,803' with full returns and no losses Cont RIH with 5 1/2" liner on 5" DP from 8,803' to 11,297', no problems in open hole or mud losses, st wt up 153K, dn wt 85K Dropped 29/32" ball and pumped down to seat, staged up pump rate to 5 bpm at 580 psi, with ball on seat pressured up to 2,500 psi to set hanger, then pressure up to 3,500 psi to set packer and pressure bleeding down past ball seat, cont to set packer by PU and releasing dogs then setting 50K string wt down, then rotated at 50 rpms and set .....- Printed: 8/18/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 80K down w/rotating, packer set with no problems, set lower lateral liner with TOL @ 6,776' and shoe at 11,297', st wt after setting liner 142K up and 1 05K dn with 115K rotating wt RU and tested annulus above ZXP packer to 1,000 psi for 5 min, good test Monitored well-static Pumped dry job and POOH LD liner setting tool Held PJSM, then RU Schlumberger wireline (SWS) scheaves and 7' shooting nipple with pack-off f!tan USIT Bond log with GRlCCL, logged up from 6,700' to 4,100' with lot showin¡ fair to good bond, POOH LD 10QQinQ tools and RD SWS PU Whipstock and mills to rig floor PU and MU Baker seal assembly, 20 jts of 5" DP for space out and 9 5/8" Baker btm trip whipstock, milling assembly with LWD/MWD and oriented BHA #7 RIH W/ HWDP on BHA #7 to 1,600' and shallow tested MWD, circ at 296 gpm at 550 psi TIH with whipstock assembly (BHA #7) from 1,600' to 3,100' RIH with whipstock on 5" DP (BHA #7) from 3,100' to 5,977' Est Circ and made MADD pass to correlate DP to K-13 sand, Logged down from 6,044' to 6,092' (GR depth 5,305' to 5,353') shifted MWD down 2' to put on depth Cont RIH with whipstock to 6,730', st wt up 132K, dn wt 90K Oriented whipstock and RIH, tagged top of liner at 6,776', set btm trip anchor and whipstock at 10 deg left of high side, set top of whipstock at 6,096', worked 45K wt down and sheared bolt, st wt up after setting whipstock 118K and 80K dn 1.25 WINDOWCIRC CMPL TN Displaced out 9.3 ppg solids free MOBM with 9.0 ppg reconditioned OBM, circ at 8 bpm at 1,000 psi 4.50 WINDOWSTWP CMPL TN Milled window in 9 5/8" csg, top of window at 6,096', btm of window at 6,112', drilled 8 1/2" hole to 6,134' (38'), 2-3K wom, 60-100 rpm's, 470 gpm, 1,300 psi, rot wt 107K, up wt 142K, dn wt 85K, torque off btm 8K ft-Ibs, on btm 1 0-12K ft-Ibs 1.00 WINDOWCIRC CMPL TN Pumped hi vis sweep and circ hole clean while working mills thru window, had 10% increase in cuttings back from sweep, circ at 550 gpm at 2,000 psi, shut pumps down and ran mills thru window without any problems Monitored well-static Pumped dry job and POOH from 6,134' to 930' to BHA #7 Monitored well at HWDP-static, POOH standing back HWDP, downloaded MWD and LD milling assembly, upper mill in gauge, cleared rig floor RIH with 5 stds HWDP, MU HES 95/8" RTTS/Storm packer and set same at 48', pressure tested to 1,500 psi and ck ok ··Note" Storm packer was set due to open fromatlons to provide 2 nd barrier. 1.00 WELCTL CIRC CMPL TN Pulled wear bushing and flushed out BOP stack after milling window 6.00 WELCTL BOPE CMPL TN RU and tested BOPE, tested valves, manifold and rams to 250 psi low and 5,000 psi high, tested annular to 250 psi and 3,500 psi, performed accumulator test, RD Test equipment. NOTE: John Spaulding W/AOGCC waived witnessing of test 0.50 WELCTL TRIP CMPL TN Installed wear bushing, RIH to 47' with packer retrieving tool and 7/10/2004 02:00 - 02:30 0.50 CMPL TN PCKR CMPL TN 02:30 - 03:00 0.50 CMPL TN DEOT CMPL TN 03:00 - 03:15 0.25 CMPL TN OBSV CMPL TN ~~<o~ 03:15 - 07:30 4.25 CMPL TN TRIP CMPL TN 07:30 - 10:00 2.50 LOG RURD CMPL TN 10:00 - 15:00 5.00 LOG ELOG CMPL TN 15:00 - 16:30 1.50 LOG RURD CMPL TN 16:30 - 17:00 0.50 WINDOWPULD CMPL TN 17:00 - 22:00 5.00 WINDOWPULD CMPL TN V \£-\.;) Li 22:00 - 22:45 0.75 WINDOWTRIP CMPL TN 22:45 - 00:00 1.25 WINDOWTRIP CMPL TN 7/11/2004 00:00 - 01 :45 1.75 WINDOWTRIP CMPL TN 01 :45 - 03:00 1.25 WINDOWCIRC CMPL TN 03:00 - 03:30 0.50 WINDOWTRIP CMPL TN 03:30 - 04:15 0.75 WINDOWSETW CMPL TN 04:15 - 05:30 05:30 - 10:00 10:00 - 11 :00 11:00 -11:15 0.25 WINDOWOTHR CMPL TN 11 :15 - 13:30 2.25 WINDOWTRIP CMPL TN 13:30 - 15:30 2.00 WINDOWPULD CMPL TN 15:30 - 16:30 1.00 WELCTL TRIP CMPL TN 16:30 - 17:30 17:30 - 23:30 23:30 - 00:00 Printed: 8/18/2004 1 :24:05 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/11/2004 23:30 - 00:00 0.50 WELCTL TRIP CMPL TN washed top of storm packer NOTE: RU MI Swaco's solids control van 7/12/2004 00:00 - 01 :00 1.00 WELCTL TRIP CMPL TN Latched onto Storm Packer at 48' and unseated pkr, well-static, POOH LD pkr and stood back 5 stds HWDP 01 :00 - 03:30 2.50 DRILL PULD PROD2 PU & MU 8 1/2" BHA #8 with Bakers AutoTrak tool and RIH to 157', PU AutoTrak and LD ORD caliper tool and uploaded same 03:30 - 07:00 3.50 DRILL TRIP PROD2 RIH from from 157' to 6,000', PU ghost reamer at 980' and shallow test Autotrak tool at 1,450' then RIH to 6,000' 07:00 - 08:30 1.50 RIGMNT RSRV PROD2 Slip and cut 45' of drlg line and serviced rig 08:30 - 09:00 0.50 DRILL REAM PROD2 Est Circ and RIH from 6,000', no problems going thru window at 6,096', then washed 20' to btm at 6,134' 09:00 - 00:00 15.00 DRILL DRLG PROD2 Drilled 8 1/2" hole with AutoTrak from 6,134' to 7,763' MD/3,430' TVD, (1,629') ADT 9.5 hrs, 5-15K wob, 110-150 rpm's, 640 gpm, off btm pressure 3,125 psi, on btm 3,200 psi, off btm torque 11 K ft-Ibs on btm 12K ft-Ibs, rot wt 98K, up wt 168K, dn wt 66K, 9.0+ ppg MW, aye ECD 10.4 ppg, ave BGG 350 units, max gas 1,600 units 7/13/2004 00:00 - 12:00 12.00 DRILL DRLG PROD2 Drilled 81/2" hole with AutoTrak tool from 7,763' to 8,618' MD/3,439' TVD (855') ADT 8.2 Hrs, 5-25K wob, 150 rpm's, 640 gpm, off btm pressure 3,150 psi, on btm 3,225 psi, off btm torque 10K ft-Ibs, on btm 11 K ft-Ibs, rot wt 98K, up wt 165K, dn wt 64K, pumped weighted hi vis sweep at 8,050' with 50% increase in cuttings back, drilled thru several calcite stringers, 9.0+ MW ECD aye 10.4 ppg, ave bgg 400 units max gas 1,900 units 12:00 - 00:00 12.00 DRILL DRLG PROD2 Drilled 81/2" hole with AutoTrak tool from 8,618' to 9,712' MD/3,426' TVD (1,094') ADT 8.2 Hrs, 5-25K wob, 150 rpm's, 640 gpm, off btm pressure 3,400 psi, on btm 3,425 psi, off btm torque 10K ft-Ibs, on btm 12.5K ft-Ibs, rot wt 97K, up wt 168K, dn wt 55K, cont to drill thru calcite stringers, 9.1 MW ECD ave 10.7 ppg, ave bgg 400 units max gas 1,200 units 7/14/2004 00:00 - 12:00 12.00 DRILL DRLG PROD2 Drilled 81/2" hole with AutoTrak tool from 9,712' to 10,543' MD/3,422' TVD (831') ADT 8.3 Hrs, 5-25K wob, 150 rpm's, 640 gpm, off btm pressure 3,400 psi, on btm 3,500 psi, off btm torque 13K ft-Ibs, on btm 15K ft-Ibs, rot wt 100K, up wt 180K, dn wt 53K, cont to drill thru calcite stringers, 9.1 MW ECD ave 10.7 ppg, max ECD 10.9 ppg, ave bgg 300 units max gas 800 units, pumped 1-weighted hi vis sweep with no increase in cuttings, at 10,359' began running HWDP for push pipe 12:00 - 00:00 12.00 DRILL DRLG PROD2 Drilled 8 1/2" hole with AutoTrak tool from 10,543' to 11,178' MD/3,413' TVD (635') ADT 8.3 Hrs, 5-25K wob, 150 rpm's, 640 gpm, off btm pressure 3,700 psi, on btm 3,800 psi, off btm torque 13K ft-Ibs, on btm 15K ft-Ibs, rot wt 110K, up wt 180K, dn wt 50K, 9.0+ MW ECD ave 10.7 ppg, max ECD 11.0 ppg, ave bgg 200 units max gas 1800 units, pumped 1-weighted hi vis sweep with no increase in cuttings, ran a total of 8 stds HWDP for push pipe 7/15/2004 00:00 - 01:15 1.25 DRILL DRLG PROD2 Drilled 8 1/2" hole with AutoTrak tool from 11,178' to 11,271' (93') 01:15 - 01:45 0.50 RIGMNT RSRV PROD2 Changed out 2 valves on #2 mud pump, circ hole at 460 gpm at 2,300 psi 01 :45 - 02:30 0.75 DRILL DRLG PROD2 Drilled 8 1/2" hole with AutoTrak tool from 11,271' to 11,285' MD/3,408' TVD (14') (TD) ADT 1.3 Hrs, 5-10K wob, 150 rpm's, 630 gpm, off btm pressure 3,550 psi, on btm 3,700 psi, off btm torque 13K ft-Ibs, on btm 14K ft-Ibs, rot wt 108K, up wt 180K, dn wt 50K, 9.0 MW ECD aye 10.7 ppg, max ECD 11.1 ppg, 02:30 - 02:45 0.25 DRILL OBSV PROD2 Monitored well-static 02:45 - 03:00 0.25 DRILL CIRC PROD2 Circ hole to clear BHA, 630 gpm, 3,550 psi Printed: 8/18/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/15/2004 03:00 - 03:30 0.50 DRILL REAM PROD2 Began backreaming out of hole, backreamed out from 11,285' to 11,180' at drlg rate 03:30 - 04:30 1.00 RIGMNT RGRP PROD2 High line SCR breaker on rig failed, started and supplemented hi-line power with rig motors while repairing breaker, no problems reported at CPF 1 04:30 - 05:30 1.00 DRILL REAM PROD2 Backreamed out of hole from 11,180 to 10,630' at drlg rate, 640 gpm, 3,550 psi and 150 rpm's when swivel packing failed on top drive 05:30 - 06:30 1.00 RIGMNT RSRV PROD2 Changed out swivel packing on top drive, circ hole at 255 gpm at 900 psi, rig back on highline at 06:30 hrs Note: Roustabout relieving on rig floor got a small amount of OBM in left eye when swivel packing failed, flushed eye at rig then, sent to KOC Medic and had eyes flushed again and returned to work 06:30 - 13:15 6.75 DRILL REAM PROD2 Fin backreaming out of hole from 10,630' to 6,002' to above top of window at 6,096', circ and rotated at 630 gpm, 2,500 psi and 150 rpm's with no problems 13:15 - 14:30 1.25 DRILL CIRC PROD2 Monitored well at window-static, circ hole clean by circ 2X btms up at 640 gpm, 2,500 psi, no increase in cuttings at btms up, st wt up 135K, 85K dn 14:30 - 16:45 2.25 DRILL TRIP PROD2 Pumped dry job and POOH from 6,002' to 330', SLM no corr. 16:45 - 19:00 2.25 DRILL PULD PROD2 POOH standing back HWDP, downloaded Autotrak and LD same 19:00 - 20:30 1.50 DRILL PULD CMPL T2 PU & MU Baker fixed lug whipstock retrieving tool, BHA #9 with MWD and orient same 20:30 - 21 :45 1.25 DRILL PULD CMPL T2 RIH with BHA #9 with 9 stds HWDP, PU additional 18 jts of 5" HWDP from pipe shed while RIH to 1,482', shallow tested MWD and ck ok 21 :45 - 00:00 2.25 DRILL TRIP CMPL T2 TIH with BHA #9 from 1,482' to 6,030' ( Top of window @ 6,096') 7/16/2004 00:00 - 01:15 1.25 DRILL CIRC CMPL T2 Est Circ and oriented whipstock retrieving tool, latched onto whipstock and released same by pulling 67K over st wt to release, st wt up 148K, dn 85K 01:15 - 02:00 0.75 DRILL CIRC CMPL T2 Circ btms up after releasing whipstock, circ at 420 gpm 1,500 psi, no gas on btms up 02:00 - 02:15 0.25 DRILL OBSV CMPL T2 Monitored well-static 02:15 - 07:00 4.75 DRILL TRIP CMPL T2 POOH from 6,102' to 5,550', hole taking calc fill, pumped dry job and cont POOH to 116', stood back HWDP, no problems POOH 07:00 - 11 :00 4.00 DRILL PULD CMPL T2 LD whipstock retrieving BHA #9 with MWD, LD whipstock and 20 jts of 5" DP used as spacer pipe, cleared rig floor 11 :00 - 11 :30 0.50 CASE RURD CMPL T2 RU Doyon's 5 1/2" liner running tools and held PJSM 11:30 -15:15 3.75 CASE PULR CMPL T2 PU and RIH with 5 1/2" 15.5#, L-80 DWC liner to 5,124'. ran 5 1/2" guide shoe with no float, blank bent jt with insert pack-off on btm, then RIH with 71 slotted jts and 69 jts of blank liner, alternating slot/blank jts, ran 71 jts, 2,913.10' of slotted and 71 jts, 2,205.48' of blank liner, ran 140 SpiralGlide centralizers 15:15 - 15:30 0.25 CASE RURD CMPL T2 RD 5/12" Tongs and RU to run 3 1/2" wash string, held PJSM 15:30·22:30 7.00 CASE OTHR CMPL T2 MU HR liner wash stríng assembly, RIH PU 161 jts of 3 1/2" Hydril 511 tbg and tagged pack-off bushing and spaced out wash string 22:30 . 00:00 1.50 CASE PULR CMPL T2 MU Baker's model B-1, 7" x 9 5/8" Hook liner hanger assembly for LEM, MU 1 std of 5" DP, RIH to 5,156' and est circ thru wash string at 168 gpm, (4 bpm) at 600 psi, st up wt 110K, dn wt 84K, RD 31/2" handling tools and cleared rig floor 7/17/2004 00:00 - 01 :00 1.00 CASE RUNL CMPL T2 TIH with liner and hook hanger assembly on 5" DP from 5,156", went past top window at 6,096' and tagged SBE on lower lateral 01 :00 - 04:00 3.00 CASE OTHR CMPL T2 PU liner to above top of window at 6,096' and rotated liner, RIH and tagged up again at SBE at 6,808', PU and RIH and tagged SBE a 3rd time, PU to above top of window at 6,096' and rotated liner at 10 rpm's Printed: 8/18/2004 1 :24:05 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRilLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: and 6,500 ft-Ibs of torque, liner would only rotate when going down, tagged btm of window at 6,112', released torque RIH thru window and cont RIH, RIH from 6,112' to 11,245', ran 51 stds DP and 15 stds HWDP for push pipe, worked last 2 stds thru bridges to btm, no other problems RIH Est circ at 168 gpm at 850 psi, st wt up 185K, dn 65K, located window and latched hook hanger, tagged 3' high, unhooked from window and was able to work liner deeper past window, PU and rehooked hanger in window, tagged at 6,115', 3' deeper than btm of window at 6,112', verified hook by PU and unhooking then relatching hanger 1.25 CASE OTHR CMPL T2 Dropped 29/32" ball and pumped down to seat, pressured up to 4,350 psi and sheared ball seat, PU and verified running tool was released Set top of hook hanger at 6,095' with shoe at 11,252' 2.75 CASE CIRC CMPL T2 Monitored well-static, took on solids free MOSM into pits, then displaced out OSM in 5 1/2" x 8 1/2" annulus with 229 bbls of 9.2 ppg solids free MOSM, circ at 294 gpm at 1,625 psi, unstung from pack-off and displaced inner annulus 31/2" x 51/2" with 123 bbls of 9.2 ppg MOSM, circ at 294 gpm at 1,400 psi Pumped dry job and POOH with 15 stds HWDP (dry), POOH with 51 stds of DP (wet), POOH to setting tool, SLM No Corr. Pumped additional dry job to LD wash string RU 3 1/2" tools to LD 3 1/2" wash string LD hanger running tool POOH from 5,200' to 2,500' LD 70 jts 31/2" wash pipe, tubing tongs failed Changed out rigs hydraulic tubing tongs POOH LD an additional 31 jts of 31/2" wash pipe, 101 total LD (60 jts remaining in hole) Fin POOH LD 60 jts (161 total) of 31/2" wash string LD setting tool and RD 3 1/2" tools and RU 4 1/2" handling tools Held PJSM with rig crews on PU and running of 4 1/2" tbg and LEM assembly PU and MU 41/2" seal assembly, 22 jts (681.20') of 41/2", 12.6#, L-80 1ST tubing, pup jt, 3.562" DS nipple, pup jt and LEM/Seal Sore ReceptaclelZXP liner top packer assembly (794.81' total) RIH with LEM assembly on 5" DP from 795' to 6,094', latched into hook hanger setting 30K wt down then PU 10K over st. wt to verify latch, st wt up 155K, dn wt 108K Dropped 29/32" ball and pumped ball down to seat, pressured up to 3,000 to release from running tool and ball seat blew early, packer set early and HRD running tool not released, top of ZXP packer set at 6,038' Dropped 2nd ball, (11/2") and attempted to pump down and well pressured up to 600 psi, shut down Installed safety valve and Cleaned rig floor waiting on HES slickline unit RU HES slickline and RIH with 2.7" swedge tool and attempted to push ball down to seat, was unable to get deeper than 5,590', POOH Pumped 31 bbls to seat ball with no success, pumped at 2 bpm pressure increased to 650 psi and after 13.5 bbls pressure dropped back to 490 psi, shut down after 31 bbls Sled well to -0- and monitored well, bled back 11.5 bbls then well was static Dropped 1 3/4" ball then RIH with slickline and 2.5" gauge ring, worked 7/17/2004 01 :00 - 04:00 3.00 CASE OTHR CMPL T2 04:00 - 07:00 3.00 CASE RUNL CMPL T2 07:00 - 11 :00 4.00 CASE OTHR CMPL T2 11:00-12:15 12:15 - 15:00 15:00 - 19:00 4.00 CASE RUNL CMPL T2 19:00 - 19:15 0.25 CASE CIRC CMPL T2 19:15-19:45 0.50 CASE RURD CMPL T2 19:45 - 20:15 0.50 CASE OTHR CMPL T2 20:15 - 22:30 2.25 CASE PUTS CMPL T2 22:30 - 23:00 0.50 RIGMNT RSRV CMPL T2 23:00 - 00:00 1.00 CASE PUTS CMPL T2 7/18/2004 00:00 - 02:00 2.00 CASE PUTS CMPL T2 02:00 - 02:45 0.75 CASE RURD CMPL T2 02:45 - 03:00 0.25 CMPL TN SFTY CMPL T2 03:00 - 05:30 2.50 CMPL TN PULD CMPL T2 05:30 - 09:15 3.75 CMPLTN RUNT CMPL T2 09:15 - 10:00 0.75 CMPLTN PCKR CMPL T2 10:00 - 10:30 0.50 CMPL TN PCKR CMPL T2 10:30 - 13:00 2.50 WAlTON EQIP CMPL T2 13:00 - 16:30 3.50 CMPL TN SUN CMPL T2 16:30 - 17:30 1.00 CMPL TN PCKR CMPL T2 17:30 - 19:00 1.50 CMPL TN OSSV CMPL T2 19:00 - 21:30 2.50 CMPL TN PCKR CMPL T2 Printed: 8/18/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 2.50 CMPL TN PCKR CMPL T2 ball down to 5,700' and was unable to go deeper, POOH 0.50 CMPL TN PCKR CMPL T2 Pumped 7.5 bbls to seat ball, pressured up to 3,800 psi and blew ball seat 2.00 CMPL TN PCKR CMPL T2 Attempted to release setting tool with no success, worked pipe up to 200K st wt (45K over) while working left hand torque (7K Ft-Ibs) down hole with no success, discussed options with office and continued to work left hand torque into pipe Continued to work left hand torque in DP to release HR running tool, with DP in neutral wt and putting 3 turns to left with 14K ft-Ibs of torque, running tool released, st up wt 150K, dn 108K Tested ZXP packer to 1,500 psi for 5 min and ck ok Monitored well-static Pumped dry job and POOH to running tool LD Baker HR running tool, all 3 balls in ball seats, cleared rig floor PU and MU Baker seal assembly, 4 jts and 2-pups of 5" DP for space out and 9 5/8" Baker btm trip whipstock, milling assembly with LWD/MWD and oriented BHA #10 RIH W/ HWDP on BHA#10to 1,030' and shallow tested MWD TIH with whipstock assembly (BHA #10) from 1,030' to 5,619' Est Circ and made MADD pass to correlate DP to K-13 sand from 5,619' to 5,666', POOH 1 std to 5,610' and re-Iog from 5,575' to 5,615', shifted MWD down 2' to put on depth, st up wt 148K, dn wt 94K TIH with whipstock assembly (BHA #10) from 5,610' to 6,022' Oriented whipstock and RIH, tagged top of ZXP packer at 6,038', set btm trip anchor and whipstock at 15 deg left of high side, set top of whipstock at 5,841' MD/3,41 0' TVD, st wt up after setting whipstock 153K and 104K dn 6.00 WINDOWSTWP PROD3 Milled window in 9 5/8" csg for "D" sand lateral, top of window at 5,841', btm of window at 5,857', drilled 8 1/2" hole to 5,880' MD/3,420' TVD (39' total), 2-10K wom, 60-90 rpm's, 428 gpm, 1,400 psi, rot wt 120K, up wt 153K, dn wt 104K, torque off btm 8K ft-Ibs, on btm 1 OK ft-Ibs, pumped hi vis sweep at 5,847' while milling window Pumped 30 bbl hi vis sweep and began circ hole clean while working mills thru window, circ at 428 gpm at 1,400 psi Finish pumping 30 bbl hi vis sweep and circ hole clean while working mills thru window, circ at 428 gpm at 1,400 psi Monitor well, Dry pipe, POOH & lay down milling assembly, All mills in guage. Pull wear bushing, Flush out metal shavings from BOP stack, Reinstall wear bushing. Make up 8-1/2" bit & Autotrak tools, Program tools. RIH, Pick up Ghost reamer & surface test tools @ 987', RIH & test down link on Autotrak @ 3,586', RIH to 5,835'. Work thru window - tagged @ 5,848', Rotated at 20 RPM @ 5,851', Work down to 5,880'. Drill 8-1/2" hole f/5,880' to 6,556' ADT= 4.8 hrs, WOB 5/20K, RPM 150,640 gpm @ 3100 psi, UP 136K, DN 70K, ROT 97K, TO on 9K1 off 9K, Ave. ECD's 10.2 ppg @ 9.1 ppg mud. Note; Dropped down below sand into shale f/6,054' to 6,327'. 0.75 DRILL CIRC PROD3 Lost communication with Autotrak, Trouble shoot same, Reset Autotrak several times, Regain contact. 0.75 DRILL DRLH PROD3 Drill 8-1/2" hole f/6,556' to 6,649' ADT = 0.5 hrs, WOB 5/20K, RPM 150,640 gpm @ 3100 psi, UP 136K, DN 70K, ROT 97K, TO on 9K1 off 7/18/2004 19:00 - 21 :30 21 :30 - 22:00 22:00 - 00:00 7/19/2004 00:00 - 00:45 0.75 CMPL TN PCKR CMPL T2 00:45 - 01 :00 0.25 CMPL TN DEOT CMPL T2 01:00 - 01:15 0.25 CMPL TN OBSV CMPL T2 01 :15 - 04:00 2.75 CMPL TN TRIP CMPL T2 04:00 - 05:00 1.00 CMPL TN PULD CMPL T2 ~ 05:00 - 09:30 4.50 WINDOWPULD PROD3 \€.-hJL d 09:30 - 10:15 0.75 WINDOWTRIP PROD3 10:15 - 13:15 3.00 WINDOWTRIP PROD3 13:15 - 16:30 3.25 WINDOWCIRC PROD3 16:30 - 17:00 0.50 WINDOWTRIP PROD3 17:00 - 17:30 0.50 WINDOWSETW PROD3 17:30 - 23:30 23:30 - 00:00 0.50 WINDOWCIRC PROD3 7/20/2004 00:00 - 00:45 0.75 WINDOWCIRC PROD3 00:45 - 05:00 4.25 WINDOWTRIP PROD3 05:00 - 06:30 1.50 WINDOWOTHR PROD3 06:30 - 08:45 2.25 DRILL PULD PROD3 08:45 - 12:30 3.75 DRILL TRIP PROD3 12:30 - 13:30 1.00 DRILL REAM PROD3 13:30 - 21 :00 7.50 DRILL DRLH PROD3 21 :00 - 21 :45 21 :45 - 22:30 Printed: 8/18/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/20/2004 21 :45 - 22:30 0.75 DRILL DRLH PROD3 9K, Ave. ECD's 10.2 ppg @ 9.1 ppg mud. 22:30 - 23:00 0.50 DRILL CIRC PROD3 Lost communication with Autotrak, Unable to reset Autotrak. 23:00 - 00:00 1.00 DRILL TRIP PROD3 Pump out of hole to 6,180'. 7/21/2004 00:00 - 01 :00 1.00 DRILL TRIP PROD3 Back ream slow f/ 6,180' to 6,094' due to packing off, Pump out f/ 6,094' to 5,908' with no problems, Pull slow thru window @ 5,857' to 5,841' with no problems, pull to 5,815'. 01 :00 - 01 :30 0.50 DRILL CIRC PROD3 Circ btm's up & hole clean @ 5,815' at rate of 615 gpm @ 2400 psi. 01:30 - 05:15 3.75 DRILL TRIP PROD3 Monitor well, POOH, Down load Autotrak, Lay down Autotrak & Bit. 05:15 - 07:00 1.75 DRILL TRIP PROD3 Pick up new Autotrak & bit, Program Autotrak. 07:00 - 12:00 5.00 DRILL TRIP PROD3 RIH, Surface test tools @ 970', RIH, Slide thru window @ 5,841' with no problems, RIH, Wash f/6,550' to 6,649'. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 8-1/2" hole f/6,649' to 7,805' ADT = 8.8 hrs, WOB 5/25K, RPM 150,615 gpm @ 2550 psi, UP 143K, DN 60K, ROT 96K, TO on 91<1 off 10K, Ave. ECD's 10.5 ppg @ 9.2 ppg mud, Max gas 571 units. 7/22/2004 00:00 - 05:00 5.00 DRILL DRLH PROD3 Drill 8-1/2" hole f/7,805' to 8,191' ADT= 2.7 hrs, WOB 5/15K, RPM 150,615 gpm @ 2600 psi, UP 148K, DN 63K, ROT 96K, TO on 10/111<1 off 11/12K, Ave. ECD's 10.5 ppg @ 9.2 ppg mud, Ave. BGG 350 units, Max gas 614 units, Pumped 1 weighted Hi-vis sweep @ 8,150' with 10-15% increase in cuttings. Note; Hydralic system on AutoTrak steering unit failed. 05:00 - 09:30 4.50 DRILL TRIP PROD3 Monitor well, Back ream out of hole to 6,085' (Mild packing off f/6, 187' to 6,094'), Pull & pump out thru window to 5,806' with no problems. 09:30 - 10:00 0.50 DRILL CIRC PROD3 Circ 2 times btm's up & hole clean @ 5,806' at rate of 615 gpm @ 2150 psi. 10:00 - 14:30 4.50 DRILL TRIP PROD3 Monitor well, POOH, Break bit, Down load AutoTrak, Lay down same. 14:30 - 20:00 5.50 WELCTL BOPE PROD3 Pull wear bushing, Set test plug, Teat all BOPE to 250 psi low & 5000 psi high, Hydril to 250 psi low & 3500 psi high, Test waived by AOGCC John Spaulding. 20:00 - 21 :30 1.50 RIGMNT RGRP PROD3 Change out Wash pipe packing on top drive. 21 :30 - 00:00 2.50 DRILL PULD PROD3 Make up AutoTrak & Program same. 7/23/2004 00:00 - 04:30 4.50 DRILL TRIP PROD3 RIH to 980', Surface test AutoTrak- OK, RIH to 8,044' with no problems. 04:30 - 05:00 0.50 DRILL REAM PROD3 Break eire, Wash f/8,044' to 8,191', Stage pump rate up to 615 gpm @ 2600 psi. 05:00 - 12:00 7.00 DRILL DRLH PROD3 Drill 8-1/2" hole f/8,191' to 8,783' (3,374' TVD) ADT = 4.3 hrs, WOB 5/20K, RPM 120, 615 gpm @ 2750 psi, UP 152K, DN 58K, ROT 96K, TO on 10/121<1 off 11/12K, Ave. ECD's 10.5 ppg @ 9.0+ ppg mud, Ave. BGG 300 units, Max gas 372 units. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 8-1/2" hole f/8,783' to 9,760' (3,362' TVD) ADT = 8.9 hrs, WOB 5/15K, RPM 160, 615 gpm @ 2800 psi, UP 150K, DN 48K, ROT 95K, TO on 121<1 off 12K, Ave. ECD's 10.6 ppg @ 9.0 ppg mud, Ave. BGG 300 units, Max gas 394 units. 7/24/2004 00:00 - 04:45 4.75 DRILL DRLH PROD3 Drill 8-1/2" hole f/9,760' to 9,882' ADT= 4.0 hrs, WOB 5/15K, RPM 150,615 gpm @ 2800 psi, UP 146K, DN 54K, ROT 95K, TO on 121<1 off 11 K, Ave. ECD's 10.6 ppg @ 9.0 ppg mud, Ave. BGG 300 units, Max gas 350 units. 04:45 - 05:30 0.75 RIGMNT RGRP PROD3 Work pipe and replace air boot in bell nipple. 05:30 - 16:45 11.25 DRILL DRLH PROD3 Drill 8-1/2" hole f/9,882' to 10,533' (3,350' TVD) ADT= 8.4 hrs, WOB 5/15K, RPM 150, 615 gpm @ 2900 psi, UP 160K, DN 60K, ROT 105K, TO on 12/13K / off 12K, Ave. ECD's 11.0 ppg @ 9.0 ppg mud, Ave. BGG 300 units, Max gas 405 units. 16:45 - 17:15 0.50 RIGMNT RGRP PROD3 Circ & work pipe while changing valve & seat on #2 mud pump. 17:15 - 00:00 6.75 DRILL DRLH PROD3 Drill 8-1/2" hole f/10,533' to 11,230' (3,339' TVD) ADT= 5.0 hrs, WOB 5/15K, RPM 150, 595 gpm @ 3050 psi, UP 185K, DN 60K, ROT 115K, Printed: 8/18/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/24/2004 17:15 - 00:00 6.75 DRILL DRLH PROD3 TO on 13K1 off 13K, Ave. ECD's 10.9 ppg @ 9.1 ppg mud, Ave. BGG 300 units, Max gas 625 units, Pumped 1 Hi-vis weighted sweep @ 10,989' with very little increase in cuttings. 7/25/2004 00:00 - 00:45 0.75 DRILL DRLH PROD3 Drill 8-1/2" hole f/11 ,230' to 11,273' (3,336' TVD) ADT = 0.8 hrs, WOB 5/15K, RPM 150,595 gpm @ 3200 psi, UP 180K, DN 60K, ROT 120K, TO on 13K1 off 13K, Ave. ECD's 10.9 ppg @ 9.1 ppg mud, Ave. BGG 300 units, Max gas 625 units. 00:45 - 01 :30 0.75 DRILL CIRC PROD3 Circ, Survey, Retract AutoTrak blades, Monitor well. 01 :30 - 02:30 1.00 DRILL TRIP PROD3 Backream out of hole at drilling rate f/11 ,273' to 10,536'. 02:30 - 03:00 0.50 RIGMNT RGRP PROD3 Hiline power tripped, Reset same. 03:00 - 09:45 6.75 DRILL TRIP PROD3 Continue to backream out of hole with no probelms to 5,816' 09:45 - 10:45 1.00 DRILL CIRC PROD3 Circ 3 times btm's up at rate of 595 gpm @ 2200 psi & 80 RPM. 10:45 - 14:00 3.25 DRILL TRIP PROD3 POOH to AutoTrak. 14:00 - 16:00 2.00 DRILL PULD PROD3 Down load AutoTrak, Lay down same, Clear floor. 16:00 - 20:30 4.50 DRILL TRIP CMPL T3 Make up Fixed lug whipstock retrieveing tools, RIH to 5,787'. 20:30 - 22:30 2.00 DRILL CIRC CMPL T3 Circ btm's up, Wash whipstock face & Latch onto whipstock @ 5,847' (Retrieving slot), Pull whipstock loose w/60K over pull, Observe well. 22:30 - 23:00 0.50 DRILL CIRC CMPL T3 Pull to 5,757', Circ btm's up. 23:00 - 00:00 1.00 DRILL TRIP CMPL T3 POOH to 5,380', Observe well- OK, Pump dry job. 7/26/2004 00:00 - 04:30 4.50 DRILL TRIP CMPL T3 Continue POOH w/ whipstock slow (50 ftlmin.) due to mild swabbing if pulled to fast (Hole took proper fill). Note; Whipstock also snagged @ 1,655', 1,400', 1,000'. 04:30 - 06:30 2.00 DRILL PULD CMPL T3 Lay down all whipstock tools. 06:30 - 07:45 1.25 CASE RURD CMPL T3 Clear rig floor, Rig to run 5-1/2" liner, Monitor well. 07:45 - 13:00 5.25 CASE PULR CMPL T3 PJSM, Pick up 5-1/2",15.5#, L-80, DWC Blank & slotted liner as per detail (Total of 152 jts.). 13:00 - 19:30 6.50 CASE PUTB CMPL T3 PJSM, Pick up 3-1/2" inner wash string. 19:30 - 20:00 0.50 CASE PULR CMPL T3 Pick up Baker model B-1 Hook Hanger for LEM, Break eire, UP 118K, DN 90K. 20:00 - 20:30 0.50 CASE RUNL CMPL T3 RIH w/liner to 5,780'. 20:30 - 22:00 1.50 CASE CIRC CMPL T3 Circ hole volume at rate of 244 gpm @ 1100 psi, UP 122K, DN 90K, ROT 102K, TO 5/6K. 22:00 - 00:00 2.00 CASE RUNL CMPL T3 RIH w/liner to 7,550'. 7/27/2004 00:00 - 02:00 2.00 CASE RUNL CMPL T3 RIH w/liner to 11,241', Had to work last 60' to btm. 02:00 - 02:45 0.75 CASE RUNL CMPL T3 Hook hanger 3' low @ 5,860', Unhook and rehook to confirm- OK, Shoe @ 11,241' 02:45 - 05:00 2.25 CASE CIRC CMPL T3 Break circ at rate of 5 bpm @ 1000 psi, Drop ball and pump down at 2.5 bpm @ 590 psi, Release from liner & blow ball w/3800 psi. 05:00 - 05:45 0.75 CASE CIRC CMPL T3 Circ btm's up w/8 bpm @ 2000 psi, Monitor well. 05:45 - 07:00 1.25 CASE CIRC CMPL T3 Pump 360 bbls 9.2 ppg Solids free OBM at rate of 8 bpm @ 2000 psi and flush 8-1/2"x 5-1/2" annulus, Pull out of seals and pump 68 bbls 9.2 ppg Solids free OBM to flush 5-1/2"x 3-1/2" annulus. 07:00 - 11 :00 4.00 CASE OTHR CMPL T3 POOH slow to 5,691' at 45 ftlmin. due to pulling 3-1/2" inner string out of liner, Pump dry job. 11 :00 - 16:30 5.50 CASE OTHR CMPL T3 Rig & lay down 3-1/2" inner string. 16:30 - 22:30 6.00 CMPL TN PCKR CMPL T3 Clear floor, Rig & make up LEM assembly, RIH slow to 6,030' - OK. 22:30 - 23:30 1.00 CMPL TN CIRC CMPL T3 POOH to 5,720', Drop ball & circ down at 4 bpm @ 580 psi- Seat ball. 23:30 - 00:00 0.50 CMPL TN PCKR CMPL T3 RIH w/ LEM assembly to 6,032' 7/28/2004 00:00 - 02:45 2.75 CMPL TN PCKR CMPL T3 RIH to 6,039' (Top of liner on "B" Lateral), Work thru TOL @ 6,039', Work thru BTM of tie back sleeve @ 6,048', Work down to Top of Seal Bore Extension @ 6,058' and unable to get past. 02:45 - 04:30 1.75 CMPLTNCIRC CMPL T3 POOH to 5,756', Rig & reverse ball from ball seat at rate of 3 bpm @ 400 psi, Lost 14 bbls while reversing. Printed: 8/18/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/28/2004 04:30 - 09:00 4.50 CMPL TN PCKR CMPL T3 Rig down circ equip., Monitor well- OK, Pump dry job, POOH to 391 '. 09:00 - 11 :00 2.00 CMPL TN PCKR CMPL T3 Rig & lay down ZXP Packer, SBE & LEM Assembly, Found some scratches on seal assembly and seals damaged. 11 :00 - 14:30 3.50 CMPL TN TRIP CMPL T3 Make up 4-1/2" Mule shoe for Wash Assembly, RIH to 6,015'. 14:30 - 16:00 1.50 CMPL TN CIRC CMPL T3 Circ & wash f/6,015' to 6,058'- Unable to work past 6,058'. 16:00 - 20:30 4.50 CMPL TN TRIP CMPL T3 Monitor well, POOH & lay down Mule shoe Assembly. 20:30 - 21 :00 0.50 RIGMNT RSRV CMPL T3 Service top drive. 21 :00 - 21 :30 0.50 CMPL TN RURD CMPL T3 Rig to run 2-7/8" drill pipe, Unload & strap 2-7/8" drill pipe in pipe shed. 21 :30 - 00:00 2.50 FISH PULD CMPL T3 Make up 4-11/16" Mill & reverse circ basket, XlO's, 3 jts 3-1/8" DC's, 7 jts 2-7/8" Drill pipe, Bumper sub & jars. 7/29/2004 00:00 - 02:45 2.75 FISH TRIP CMPL T3 RIH w/4-11/16" mill assembly to 5,975', Wash down to 6,056' & tag junk. 02:45 - 03:45 1.00 FISH MILL CMPL T3 Mill on junk f/ 6,056' to 6,056.5' UP 145K, DN 107K, ROT 121 K, TO 4/5K ftr/lb, 50 RPM, 5 bpm @ 1450 psi, Fell thru & wash down to 6,076' (Btm of Seal bore Extension), Wipe thru to ensure free of junk. 03:45 - 08:45 5.00 FISH TRIP CMPL T3 Monitor well, Dry pipe, POOH, Lay down 7 jts 2-7/8" drill pipe, 3 jts 3-1/8" DC's, Break & clean out junk from Reverse circ basket- Recovered 6 peices of metal centralizer blades. 08:45 - 09:45 1.00 FISH PULD CMPL T3 Make up 3.4" milling assembly. 09:45 - 12:00 2.25 FISH TRIP CMPL T3 RIH to 4,849', Attempt to break circ- Pipe plugged, Attempt to clear pipe- No good. 12:00 - 16:00 4.00 FISH TRIP CMPL T3 POOH- wet to Mill, Clean out metal shavings from BHA. 16:00 - 19:00 3.00 FISH TRIP CMPL T3 Make up 3.4" mill assembly, RIH to 4,850' (Breaking circ every 10 stands). 19:00 - 21 :00 2.00 FISH CIRC CMPL T3 Wash f/4,850' to 6,076'. 21:00-21:15 0.25 FISH MILL CMPL T3 Mill f/6,076' to 6,078' UP 140K, DN 107K, ROT 123K, 4/5K ftIlb, 50 RPM, 5 bpm @ 1050 psi Fell thru, RIH to 6,098' set down, Mill to 6,099' fell thru, RIH to 6,200' very free. 21:15 - 22:30 1.25 FISH CIRC CMPL T3 Pump Hi-vis weighted sweep at rate of 8 bpm @ 2200 psi, Had some small metal shavings in sweep on btm's up. 22:30 - 23:30 1.00 FISH TRIP CMPL T3 Monitor well - OK, Pump out of hole at rate of 8 bpm @ 2200 psi to 5,390'. 23:30 - 00:00 0.50 FISH TRIP CMPL T3 Pump dry job, POOH. 7/30/2004 00:00 - 04:45 4.75 FISH TRIP CMPL T3 POOH to BHA, Rig & lay down 2-7/8" drill pipe, 3-118" DC's, Baker mill assembly. 04:45 - 06:30 1.75 CMPLTN PCKR CMPL T3 PJSM, Rig and make up LEM assembly. 06:30 - 11 :00 4.50 CMPLTN TRIP CMPL T3 RIH w/ LEM assembly to 6,066', Top of liner top packer @ 5,780'. 11 :00 - 13:00 2.00 CMPL TN PCKR CMPL T3 Latch & set LEM, Set ZXP Packer w/3000 psi, Neutralize w/3700 psi, Test ZXP w/1500 psi f/15 min., Shear out ball w/5600 psi. 13:00 - 16:30 3.50 CMPL TN TRIP CMPL T3 Monitor well, Pump dry job, POOH & Lay down LEM running tool, Pull wear bushing. 16:30 - 17:30 1.00 CMPL TN RURD CMPL T3 Rig to run 4-1/2" completion string. 17:30 - 23:00 5.50 CMPL TN RUNT CMPL T3 PJSM, Run 4-1/2" Completion to 5,780'. 23:00 - 00:00 1.00 CMPL TN RURD CMPLT3 Rig pump lines to circ down and locate Seal bore extension. 7/31/2004 00:00 - 01 :00 1.00 CMPL TN SOHO CMPL T3 Break eire, Locate SBE, Pick up pups & space out tbg, Make up Vetco Gray Tubing hanger, Lana tbg w/ tail @ 5,810'. & RILDS. Note; See Tubing tally for full details. 01 :00 - 02:45 1.75 CMPL TN DEOT CMPL T3 Rig & test 4-1/2" annulus to 2500 psi for 15 min, 3000 psi for 30 min. on chart, Pressure up and shear RPva!ve w/ 3700 psi. 02:45 - 03: 15 0.50 CMPL TN PULD CMPL T3 Lay down landing joint, Set BPV. "" 03:15 - 04:15 1.00 WELCTL OTHR CMPL T3 Make up stack washer, Flush out stack, Lay down stack washer. 04:15 - 05:15 1.00 WELCTL NUND CMPL T3 Nipple down BOPE. 05: 15 - 06:45 1.50 WELCTL NUND CMPL T3 Nipple up tree, Test bonnet to 5000 psi f/10 min. Printed: 6118/2004 1 :24:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/31/2004 06:45 - 10:45 4.00 WELCTL NUND CMPL T3 10:45 - 20:30 9.75 DRILL PULD CMPL T3 20:30 - 22:00 1.50 CMPL TN FRZP CMPL T3 22:00 - 00:00 2.00 WELCTL NUND CMPL T3 Build scaffold around tree, Rig up lubricator, Pull BPV, Set 2-way check, Test tree to 250 psi low & 5000 psi high, Pull 2-way check. Rig & lay down 5" drill pipe from derrick, Displace 4-1/2"x 9-518" annulus thru GLM @ 5,320' with 394 bbls. diesel, Freeze protect 9-518"x 13-3/S" annulus with 120 bbls diesel to 2,000' MD, 1 ,SOO' TVD. Set BPV, Rig down scaffold. Install wing valve on tree, Dress tree w/ all guages, Wash down tree, Record all pressures = Tbg. 150 psi, 4-1/4"x 9-5/S" 250 psi, 9-5/S"x 13-3/S" 250 psi, Flush and freeze protect injection well 1 E-33. Note: Release rig at 00:00 hrs 7/31/2004. Printed: 8/18/2004 1 :24:05 PM . ..' ConocoPhillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . . SURVEY LISTING Page 1 Wellbore: 112 Wellpath: MWD w/Sag <7864 -11425'> Date Printed: 28-Jul-2004 ~-i -ocr I Ri. BAKER HUGHES INTEQ Wellbore - ~ame --------~---~-- I Creat~_______.____________~_!J.j¡-ªIReYi~ed_____________J j 12______ _ ___ __ ______ _ ____ 1~1Y1:200~ ____ _______ _____~Q:JJji~;W!M__ ______ _______ __ _ -_.~--,--~-~------.._------~---,,~-"--~'-----'-'----"~--,._~--~ --C-'-i Well Name 112 I Govemment ID 50-029-23211-00 i Last Revised 23-Jun-2004 Slot -~.'-- i Grid Northina .5959781.0000 I Grid Eastina 550301.0000 I Latitude N70 ~ 3.1987 I Lonaitude . ------rNo~-- W149 35 33.3560 1191.43N lEast .225.93W Name Slot #112 r Installation :f~i=====-~====-==j~s~Q!l=_5~~Z~19~==i~=~~m~cr~~~~R~~~MEBIÇA-~º-AllJMi927 9at~f~rth-þJ~=~~t=-TIY~ -------.----.---.- ._-----,_.-_._.__.~-------._--,_.._--_._---_._-,._------'---"._-'----,-------._----~_.._---, Field ----------·----F--------r. -.Name Eastina I Northino j(uparuk River Unit 487754.6208 i· 5948985.8206 ------------~-----J--.--.-.----- Coord System Name North Alionment : I AK-4 on NORTH AMERICAN DATUM 1927 datu Tru~ iCreated By ~______._____~_______________~~_________ __.___ ______._________________.__.___~_._.J r- ¡Comrnents rCtI{"c:L g¡ôýoq:; 5-0 - C) Á...'1 ~ ..< J 21 I - (j \J - Ò 0 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 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7585.93 Feet on azimuth 160.83 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~' ConocoPhillips . ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . SURVEY LISTING Page 2 Wellbore: 112 Wellpath: MWD w/Sag <7864 -11425'> Date Printed: 28-Jul-2004 rei. BAKER HUGHES INTEQ I Wellpath (Grid) Report MD[ft] ¡ Inc[deg] Azi[deg] I TVD[ft] i Station ¡Station i Dogleg Severit}j Vertical Easting Northing _ L~__~_~_~~~__l£'9sitiQ!l11'L- po~itÎº-~}~ ] __~~tiQ!!If!L ._lillì4.0º-L_91.0~_-c-_184,52 _L.--ª588.5L.-,-..~º~1jj.~ _ u_~Q~j~ ~_..J!,ºº-__. ~:2JH,£Q~_5532£Z,ª-9__~$561Q$. 7L_· 7875.62 93.22 184.69 3587.88 3642.67S 2902.01E 1.89 3295.80 553227.04 5956158.19 7910.49 .. 92.12. . 184.70 , .. 3586.25 ' 3677.39S . 2899.16E ... . 3.15 ...... 3330.62 . 553224.42:.. 5956123.46, ~=Z94~7.' .- 91~4.L===::184.14=;=~585::H::::';·~13.04~= 2ª-96.4QE== 2.,w= ' _ 3366,~===55i221.i()=- 5~56087-:7!)-J 8002.40 88.80 185.26 3585.02 3768.98S 2891.80E 5.11 3422.46 553217.68 5956031.84 _ .ª-0!M]7.J_ .ßß,ll__ _1 8~L-,-_~§6. 9JL----'._ 386º,-$58__.£8§~.4QL _-'-._ Q,1]__\--351~7ª---,-.2.5.3209..l!.Q. __ _5955939.82._ 8187.20' 89.90 186.57 3588.05' 3952.898 2874.05E 2.00 3607.20 553201.16 5955847.83 8281.17 87.75 186.27 3589.98 4046.258 2863.55E 2.31 3701.14 553191.28 5955754.41 8374.23 87.76 185.73 3593.63 4138.738 2853.83E 0.58 3794.13 553182.18 5955661.88 8466.22 89.20 185.49 3596.07 4230.248 2844.84E 1.59 3886.07 553173.81 5955570.32 -----ª~~. 75~1__JtL1.6___.1.84.4L---,-~ 3595.11~- 43:13.4£8_...2836. 77.LL~nfL__L..1.9]9.~_._553166.ªº---_..ß)554 77 .,lQ_, 8651.93' 91.90 185.40 3593.31 4415.228 2828.89E 1.34 4071.68 553159.10 5955385.25 _ 87 43. M....J..~91 ,93___185.áL+._3590.2L---,-_4506.5~ _ _ 2820.17E_L_O.J..2_---1 _ 4163.4L_. 553150.~-¡_5955.29.3...8º- 8837.12, 91.72 185.96' 3587.27 '4599.438 2810.84E' 0.53 ,4256.75 553142.28' 5955200.94 , =--. .ª-930,42_~.-ªº.8$--=------- 185.15___·___~3..5..8iT4 - i _ . 49.!)2.2 is==-2801Z1 E ., -=::1~24 _____ r--- 435.i02=----S5.Ú33 .8i-:=J____59551 ()8~06= _.9022,3Q.._-+--_Q1.99__~1~,1.1_+-~58:2.8L~783.81 8__£Z93.59E_L_12.0__--+~4441.9º-__. 55.3126.27..L_5.95501QAL.J 9116.00 92.02... 185,45'. 3579.56 . i 41376.998 2784.98E'. 0,36 .' 4535.47 . 553118.29'. 5954923.24, ::::.J1.:1()8.06__--ª.0.61-=-_ 1§6.Q.§.=-i____ 3577.44._, ....1.968.56S-=_:1775.7~·=-· 1,67=J..~627A9==553109:§?_ i -5954831.6~_J _ 9299.95.--1_ --ª.0.6L__.1.I3~,22_'_~5l§A1---L~60.00~__2766. 72E----L-....J),~_.l ~4I19.37~~ 55.31 01.2LJ.._5.9547 4QJ.LJ 9394.55' 90.64 184.91' 3575.43 I 5154.23S 2758.37E; 0.33 . 4813.94 553093.53, 5954645.86 ; _....9..4illì.2L...._ 90.7L__ 185.91 , . 357 4d.3-------i-..-5.245.97S __:1H9.º8E..J~_L0J1_-L .....1~9.08._~ 553085,1!:;---L...J1.$54554.0I_i 9579.28 1 90.76 188.40 3573.13 5337.80S 2738.15E' 2.69 1 4998.62 553074.55 5954462.17' 9671.45 i 90.70 188,36 3571.95 5428.98S 2724.72E 0.08 5090.73 553061.73 5954370.92 9766.44 i 89.14 189.73 3572.09 5522.78S 2709.79E 2.19 5185.62 553047.43 5954277.02 9859.18 89.14 190.30 3573.48 5614.108 2693.66E 0.61 5278.16 553031.91 5954185.61 ~ 9950.-ºLJ._---ªª.23 __..1.8~&1._i~....257 4. 78.---l.......§704 .328__2678. 6~__..-1~.-----l.---l5369.49 . 553017.50 -----:-._5954.ill15..31_.J 10041,81' 89.01 187.86' 3576.18 I 5794.528 2665.58E 1 0.86 5460.59 553005.05 5954005.02 i 10135.95 I. 89.11 188.66 ..3577.72 '5887.688 2652.06E, 0.86. ! 5554.67 . 552992.15 . .5953911.79. ' _ 10228.40 +-- 87.48-=----=-18a.-20-,_____ 3580.47 ~]_ 5.979.088.-=- 2638.51Ei ---=-'1.8L=-1_5647.02-=' 55.2979.21.. '=59538~0.3L~ _10322.2£. I 86.83 ___..1.§8.30 _L...3.585..13~l...--º071.8~_ _26:25,07E_!~_0.7()_--+-~5740.6L~ 55296.Þd.L":"...-5...953727.49 _J _10415.00--+-_ 86~_ 188.3~ 1 3590.26 _L--º163,4 7~_._261H2E -.-l-----º-,1Q.---i- ....§833.26___552953,~L~953635.. 76_! ...J0506.49 i 86.68 _._..---.1ª-9.09 --.L_ 3595.44..J_ 6253.768 _...2597.L4~ __L_ 0.78~-i--~24.53__~552Q40.2.J1._¡_ 5953545,.3JL..j _.10600.6º--L---ª7.4.!L~~--.188,1j__l.-~600.2~---º34¡¡. 71 8 .__2Þ.83'~L--__:L11__;-----ºº-18.5º--__ ....5..5292ß...QL.J...~59!¡34~2.3L_~ __1 069Q.62.J._---ªª.4 L __..1.138.27_L~¡¡-º-:1.63~ +-- 6435.688__.2Þ.70.39E~L--~:2.2L..J _1ü.08.3.L.__.....5..5291A.1!3 5953363.31· 10781.76 1 89.50 188.90 3603.45 i 6525.808 2556.79E' 0.69 1 6199.44 552901.16, 5953273.11 __-.10872.30 i _89.66 _~_188.3L-.L_36()4.11_L-ºº-&3.1$__~54~.20.L.l~_ 0.61 !...Q.:189,91__.........552888.1L_-+_ 59Q~ß3.5.£..J 10962.80 89.75 186.41· 3604.58 : 6705.058 2531.56E! 2.17 6380.39 552877.13· 5953093.71 i 11052.91 90.39 186.91 3604.47' 6794.558 2521.11E 0.90 6470.50 552867.28 5953004.15 11143.88 90.43 185.15 3603.82 6885.018 2511.55E 1.94 6561.46 552858.33 5952913.64 11235.80 90.43 185.03 3603.13 6976.578 2503.40E 0.13 6653.35 552850.79 5952822.04 11325.88 ,92.12 . 183.34. i 3601.13i 7066.388. . 2496.82E i . 2.65 ...' 6743.34 552844.82 1 5952732.20! 11376.581- 92.12 ---18Ù3!- 3599.25 --7116.96S----2493.88E - -O~02- -¡-6793.93 ~~ 55284221----;--5952681~60- ~.425.0º--j_...J12.1£.~_..J83..J3_.L____ª.~L4L_7165.268 __2.491.Q?J=_ L_.0.0º-_'_684.2.2'L._.2.5283$. 7L--L--.595.:2633.28~j 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 95.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7585.93 Feet on azimuth 160.83 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated .. ~ ConocoPhillips . ConocoPhil/ips Alaska, Inc.,Slot #112 Pad 1E, Kuparuk River Unit, North Slope, Alaska . SURVEY LISTING Page 3 Wellbore: 112 Wellpath: MWD w/Sag <7864 -11425'> Date Printed: 28-Jul-2004 .¡. BAKER HUGHES INTEQ Comments M~--1IVOfft! .~- \mhlftL_ ¡;~Jff!]~_~_Lç~!!1m.ªnL_____________________~__~____________j _~J42~.QCL-,__~~L~_. __]'~Q§,2Q~__ __Z'li)~.Qzç___-'.P_IQL~~<:LQmª=--"lQ~lJB.Y£Y._____ _ ____ ~___ ___~________ ~___~___ ------- - .--~------,--,-.~--.-~,--~--.,---------.-~---,-----,-.-------, Hole Sections Diameter I Start Start fin! ! MDrft! TVOrftJ __~1QJ>º-0_ ___ __Q.,QCL____ _Q.Qº-_~ 121/4 3045.00 2317.11 81/2 6933.00. I 3606.57 8 1/2 7864.00 3588.51 Start ¡Start End End End Start Wellbore Northfft! ! Eastrft! MOrft! TVOrft! Northfft! Eastfft! _JLQQI'!_ _~_JLQºE.__ ___ =iº!5~º-O_ _..ntZJL__ _1ßo.19JL _lsJº,-ili>£_ 11~2ßL_____._____ 180.46S 1516.D6E 6933.00 3606.57 2720.79S 3077.78E 112 PB1 272D.7~ 3077.78E 8023.0.0 3581.30 3789.49S 2889.92E 112 PB 1 3631.115 I 2902.94E 11425.00 3597.46 7165.265 2491.07E 112 CasinQs i I I Name ¡Top Top Top ¡TOP Shoe ________~lMQlf!l_____"f.YQfftL_.._1'J.QdÞlftl__,~ªs.!/JtL___ MQff!L__ 4Q"-kº-nduçtQL_~__QQCL__ __Q.Q.O___ _J)j)ON _~_-PJ>QE.__ __-.loMº- 133/8" Surface 0..00 0.00 O.OON D.DOE 3029.44 Shoe I Shoe Shoe I ;wellbore I IY.QIflL_~Jr.,lQ[ll!!ttL.-_~~tlftL__ _____________J -2~%~Of9 :--1%~.:S- --~~i3E }~~~~}--------- 3605.33 2712.715 3079.82E 112 PB1 casinQ i 9 5/8" Intermediate' 0..00 0..00 D.OON O.DDE 6924.58 casin I , 5 1/2" Liner 5839.0.0. 3410..0.5 1664.195 3277.46E 11241.0.0. 5 1/2" Liner 60.95.0.0. 3467.20 191D.78S 3239.96E 11252.0.2 5 1/2" Liner 6776.0.0. 3581.46 2570..0.95 3113.91E 11296.93 3338.07 3410..0.3 360.2.06 6997.575 69ß6.915 70.37.50.5 2499.52E 112 L2 2448.65E 112 L 1 2498.65E 1112 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig (Doyon #141 RKB 95.Dft above mean sea level) Vertical Section is from D.DDN O.ODE on azimuth 186.41 degrees Bottom hole distance is 7585.93 Feet on azimuth 160..83 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated '~ð1 . . Wellbore: 112 PB1 Wellpath: GSS <0-351'>MWD w/Sag<483 - 8023'> Date Printed: 28-Jul-2004 IIi. BAKER HUGHES INTEQ ../ ConocòPhillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit,North Slope, Alaska £CJ¥-o 9 ( Well bore Name ~£PB1 ______ I Created ____~~_ i27-JJJn-2004___ Last Revised 20-Jul-4004 -"--~'-----'- Well Name 112 I Govemment 10 ¡ 50-029-23211-00 I Last Revised 1 23-Jun-2004 Slot. Name _Slot #112 Grid Northina 5959781.0000 I Grid Eastina 1550301.0000 I Latitude N70 18 3.1987 Lonaitude W149 35 33.3560 I North 191.43N East 225.93W Installatión j'.Iame Pad~_ I I Eastin~ I Northina I Coord SyStem Name jNorth Alianment I _~.528.194~___ _5959~9J,~K-4 on NORTH_AMERICAN DATUM 1927 datu~ TrYfu ~--~._._-- I Coord SyStem Name I North Alianment I AK-4 on NORTH AMERICAN DATUM 1927 datu~ True Field Name _Kuparuk River Unit I Eastina 487754.6208 INort~ 5948985.8206 ---.- ------~._---- -_...__._.----_.~- _._.,._-------------,--_..._.~-- ---.-- 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 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 4766.66 Feet on azimuth 142.66 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocÓPhillips . ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . Wellbore: 112 PB1 Well path: GSS <0-351'>MWD w/Sag<483 - 8023'> Date Printed: 28-Jul-2004 .¡. BAKER HUGHES INTEQ I Wellpath (Grid) Report MD[ft] '11'nC[deg] Azi[deg] I TVD[ft] I Station 8tation i Dogleg 8everi~ Vertical Easting I Northing I Position(Y) Position(X) I ! Sectionfft~ 0.00 I 0.00 0.00 0.00' ---º,00N_~.9.00L-___9~---.L_JìQO__ 550301.ºº-1~!t59781,ºº-.-J 108.00-TO~OO---Õ.00 , 108.00 I O.OON O.OOE 0.00 0.00 550301.00 5959781.00 __~2ÆL ~_ 0.25__336.ºº--l-262·ºº--L o.31N----.!L14W ---º'.i6 -9~__550300~--L_._ 5959]81.3L_ _~.OO' 0.40 __72.0º---,--_351.9~-'---0.5~_--º.,~ 0.5L__~:0.5~_ 550301.0ª----i-- 5959781.QL i 483.00 3.47 85.65 I 482.91 1.03N 4.50E 2.34 -1.52 550305.49 i 5959782.06 1 573.70 6.25 89.22_L-l173.2L-_L--1.30~___ßJ 8E_ 3.08_~ -2.65 _!:150313.1L--i---_59597.82.38_~ 663.81 7.01 87.20' 662.78 I 1.64N 22.57E 0.88 -4.15 550323.56 i 5959782.79 753.48 10.79 90.02 751.36 1.90N 36.44E 4.24 -5.96 550337.42 5959783.14 845.02 15.39 91.81 840.49 1.51N 57.16E 5.04 -7.89 550358.14 5959782.90 934.55 14.93 89.68 926.91 1.20N 80.57E 0.81 -10.19 550381.55 5959782.74 ~,58 15.73 __92.4L_+_1014.Zº- 0.74N___~4.62E---L 1.20 -12.42 550405.60:_ 595!t782.4~! 1118.40 19.09 99.47! 1103.26 2.308 132.17E I 4.26 -12.47 550433.17' 5959779.58 , 1210.64 _~70 92.9:l----+-.1l!t0.2ª---c-_~.588.____162.!:1~_~]44 __----1.----=l2.&L _~_5M63.ºº---L--59597?6.51_.~ 1303.73 20.45 95.48! 1277.71 1--.L948 __ 194.44.L---.'_1~----L__ -13.83 550495.47 5959774.37 -J 1396.34 i ,24.50 ,95.52 1363.27' 11.338 229.67E I 4.37 '", -14.39 550530.72 ,,! 5959771.21 --1489.40._ I _ 29g0 ~_ 95.88 - 1446.28 T 15þ18 -~271.48E ï"---~.05 .-_ : ,. -14.90---550~72.55 .~ 5!t5976?::31-J 1583.48' 32.77 ~32 I 1526.92 ~238_.~19.68E____L 3.81 -15.60 550620.78' 5959762.92 ' 1676.18 37.86 94.6L---.J 1602.54 24.858 , 373.05E ,5.51 -16.97 550674.17----L 5959758.6U 1768.11 44.11 -----.94.0º--l_1671.9029.36S-~ 433.14E-¡ 6.81 -19.20 550734.29--.L_ 5959754.55 1860.44 50.21 94.60 1734.65 34.458 500.62E 6.62 -21.68 550801.79 1 5959749.91 ----19J>2.84 54.08 95.05 1791.34 40.598 ~ 573.30E ~_ 4.21 L-:.2_3.69_ 550874.50 59597_44.25~ 2046.26 56.34 93.17 1844.64 46.078 649.82E I 2.93 '-26.79 550951.05 5959739.29 2137.93 60.53 94.47 1892.62 51.298 727.73E' 4.73 -30.30 551028.98 5959734.59 2230.40 61.43 95.52 1937.48 58.348 808.28E 1.39 -32.30 551109.57 5959728.08 2324.25 63.51 95.36 1980.86 66.22S 891.12E 2.22 -33.71 551192.46 I 5959720.75 1 2417.68 62.70 95.81 2023.12 74.338 974.05E 0.97 -34.91 551275.43 i 5959713.20 ¡ - 2510.87 59.68 95.74 2068.02 82.558----:¡OSS.28E 3.24 -35.82 - 551356.71-1 5959705.531 2602.58 57.11 97.39 2116.08 91.468 1132.87E 3.19 ----+ -35.63 551434.34 ,: 5959697~ 2694.87 61.1~_ 100.48 21153.43 _--.1Q3~_-1211.()9E 5.24 -.----.L -32~10 - 5.~1512.'6<I-15_959685dLJ 2786.54 65.51 104.21 22.94.57 121.368 1291.07E 5.98 ----1-~~_!:1~1592.Z2__+--5.959668.30 ~ 2879.96 64.99 104.48 2243.68, ---.m.388_-----131'3.26E 0.62~_---.-11.J!L-~JQ75.05! 5959647.83..-' 2964.20 ----º.3~ 105.23 2280.271 161.838 __ 1446.60E_--.1J¡2:0.73 _551748.51---.L.. 5959628.87 j 3155.32 60.48 104.20 I ---.n..!19.99 204.718 j609.79E: 1.66 , 23~ 551911.ªº---L_~959587.09-.J 3248.55 62.49 105.49! 2414.49_--L--.n.5.708 1688.96E 2.48 I ~~_----.l1~_1991.2L-i 5~59566.63 ~ 3340.92 64.87 106.06: 2455.45 ,248.21S 1768.63E 2.64' 49.15 552071.08 15959544.65 i ~.OO 66.61 106.01--.L_--..M93.69---t-.----21J.658 1850.19E 1.87 1 ----º-3.33 __552152.78+---5959521.76_J, 3526.62 66.74 105.41 1 2530.36 '294.688 1932.06E 0.61 77.07 552234.80 5959499.29, 3618.75 66.81 104.87: 2566.69 1 316.808 2013.79E 0.54 89.92 552316.66 5959477.72 3712.58 i 66.74 104.68 2603.69 338.788 2097.16E 0.20 102.46 552400.17 5959456.29 3805.34: 67.24 103.98 2639.95 I 359.928 2179.88E 0.88 114.22 552483.03 5959435.72 3897.30 __L-66.&~ 104.53_ 2675. 85----!._-.---1aO. 768 2261.94E 0.72 125.77_552565.22 5959415.42 3991.43: 66.51 104.65 2713.14 I 402.538 2345.58E I 0.34 138.07 552648.99 5959394.22 4083.68 64.55 106.28 2751.35 1 424.918 2426.50E I, 2.66 -t-- 151.27 552730.05, 5959372.38 __ 4176.56 63.71 110.52 2791.89 I' 451.278- 25Q5.78E i ..-----:¡.~ . _168.61 552809.49 1-- 5959346·561 4269.43 64.15 115.70 2832.73, 484.018 2582.47E, 5.03 : 192.58 552886.39. 5959314.34 __ 436.2.66, 64.60 _J18.79 2873.06 T522~ 26_57.18E~~~---.L_)22.4L----. 5529t>1.36-+- 595~276.3ß-.-J 4455.71 +- 66.~_--...ß2.78 2911.51 565.868 2729.95E i 4.46 '257.45 553034.40 _-.:....-5959233.48_~ 4548.39, 67.88 128.29 2947.39 I 615.528 2799.45E 5.65 299.04___!:153104.23 -t---59591~~ 4641.60: 67.44 133.58 __ 2982.84-+~1.98~_---.--2864.55E 5.27 ~1!L---....---º_53169.70' 5959128.28_-, 4733.80 67.57 135.96 3018.12! 731.97S 2925.02E 2.39 400.73 553230.57 5959068.70 1 4827.25 ----º-6.80_~41 3054.36-L. 795,148 2983.56E 2,55 456.9L---...~32-ª9.52 5959005.~ 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 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 4766.66 Feet on azimuth 142.66 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ....' ConocoPhillips . ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . Wellbore: 112 PB1 Wellpath: GSS <0-351 '>MWD w/Sag<483 . 8023'> Date Printed: 28-Jul-2004 _i. BAKER HUGHES INTEQ Wellpath (Grid) Report MD[ft] Inc[deg] Azi[deg] I TVO[ft] I Station Station i Dogleg Severi.~ Vertical Easting I Northing _ PositionJYL Position(X) _I ,5ectionrftl _--1 : 4919.23 65.81 __~42.08 3091.33. i . 859.875. 3037.42E . L. 3.81. i. 515.28 553343.81, 5958941.56 · 5010.20 65.52 146.54 3128.83-927.17S--3085.76E- ----¡¡a-S7Ú(¡--S5339259-r-S958S74.60 ~ 5104.39 _65AL__ 152.79 _ ~ 3167.9-º--c-_1QQî,Q~_~29.0~_-'-__§J)-±---L---º,",5.38_~!)_3439~'~958890.9L~ 5196.86 _~4.83___~3.42_~º6.85_L 1075.90~__3166.97E L-_ 0.90 . _-I15.49__~~474~~5872~ 5289.22 i 66.27 157.16 3245.09 1152.265 3202.09E 4.00 i 787.46 553510.41 5958650.31 ~2.0ß_i__68.30 ___160~-T-_-ª280~....~232,245~232.68E--,-_4.35_l----863,~____55354.L5L-i--_5958570._~J 5475.20' 71.17 166.43· 3313.23 '1316.055 3257.16E I 6.32 . 944.07 553566.58 5958486.91 i 5567.35' 73.71 171.61 3341.05 1402.265 3273.86E 6.03 1027.87 553583.85 5958400.83· 5660.16 75.69 176.74 3365.55 1491.285 3282.92E 5.74 1115.33 553593.51 5958311.88 5753.40 75.59 182.10 3388.69 1581.575 3283.84E 5.57 1204.94 553595.03 5958221.61 5845.97 75.53... 187.11 3411.79 1670.895. ... 3276.64E .' . 5.24 ,1294.51 553588.43 5958132.25. 5939.66 75.90-W8.46--3434.91' 1760.845-- 3264.34E T----:¡-:¡s-11385.2S-553576.73 . 5958042.22' _6030.92-+_78.~__189K-+ 3455~--+__J848.76$__3250ß3E I 2Æ_-.L-1474.18__~~563.61.-L. 5957954.22 · _912~_80.4L__190.ZL-.L-.-3472.~-..l_ 1940.775_~234.~1E~_2.52__. 1567.42 553548.QL~ 5957862--1..L~ __ 6217.79 i----ªºJL_~89.5.9 ! 3487.4L-L-.2Q.29.975 _~18.43E-L_1~____L-1657.84 __ 553532.6L.L 595.z772.82~ 6311.82 i 81.QL._~90.0~ 3502.18 . 2121.4 75 3202.¡¡J1~L---ºÆL._-.--L....1750.~__553517 .4L~681.~-.J 6404.83 !_ 80.2fL_-.190.0L.~ 3517.31 i __ 2211.8~~86.5IE...-+----.J1,~--.-J-.--1.842.~_5535Q1.98 i 595Z!590.ILJ 6494.59 ! -.-l9.9L_ 190.7LL__3532.72 i 2298.8~_....ll70.57E L--º"'~..--L_~;30.3.4__5~3486.5Z__L 5957503.71 I _~_88.9~__~.99__-.N1. 73--L_3549.13 2389.96~ .3152.44E -.1,QQ_~ 2022.96 _ 553469.05 59!?7412.43 6681.58 i 79.86 191.84· 3565.33 2479.215 3133.82E 0.18 ¡ 2113.73 553451.03 5957323.07 6773.83 80.45 192.85 3581.10 2!568.~~m39E 1~_1_2204,13 5534~2.20 5957234.16 6867.49 80.79 193.46 3596.37 2657.985 3093.36E 0.74! 2295.90 553411.77 5957144.05 6897.53 80.83 193.99 3601.17 2686.795 3086.32E 1.75 I 2325.31 553404.93 5957115.20 6978.84 82.70 194.49 3612.81 2764.785 3066.52E 2.38 2405.03 553385.66 5957037.08 7073.70. 88.31 194.65 3620.24 2856.285 3042.74E 5.92 2498.60 553362.49 5956945.44 _7167.39_--i__88.§1 195A§.-f_.;3622.76_1--2946.72L 3018.42E _' 0.9~__L 2591.19 553338.77-+_---º-956854.85 7259.86 i 91.65 196.05· 3622.55 . 3035.705 2993.31E! 3.35 2682.43 553314.27 i 5956765.70 7353.24 i 92.49 192.45 3619.18 3126.135 2970.34E i 3.96 2774.86 553291.91 j 5956675.13 . = 7445.6JL-t__----ª3.00 = 1~0.17 - 361U5 32_16.595_ 2952.25E~..2.53-~2866.77_ 553274.42...L. 595.9584.56 ~ _ 7537.97, 93.8~_ 187.38_,- 3609.25 3307.705 29;38.19E I 3..1L i 2958.~_55326~! 5956493.~_~ 7631.44 1__93.72 __Jß1~_3603.103400.2~_~6.32E! 0..JJL___+~052JL_.!55324!UL¡ 5956400.79j 7724.42, 93.71 __186.1.4.--'-~Z.07 3492.375 2915.51E -.1.18 ,3144.92 _553239.53 1 5956308.57 j --.-1817.26 -1._~3.53_ 184.76_+ 3591.21 3584.605 2906.71E 1.50 3237.56._~;3231.~ 59562H;¡2!LJ 7910.20! 92.64 . 184.28 ,3586.21 3677.115 2899.40E 1.09 3330.32 553224.66 1 !)956123.74 7972.41 i 92.48 --184.011 3583.43 T 3739.1·OS--'2894.9~----o.50 3392.42 553220.58 ¡ 5956061.73 --ª023.0-º-L-.JL2.35__ 183.8Q_L 3581.30 _..1..... 3789.535 _~91.4º-E.....L---º.~ 3442.91 553217.48 5956011.29 j All data is in Feet unless otherwise stated Coordinates are from 510t MO's are from Rig and TVO's are from Rig ( Ooyon #141 RKB 95.0ft above mean sea level) Vertical 5ection is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 4766.66 Feet on azimuth 142.66 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated , i . y ConocoPhillips . ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . Wellbore: 112 PB1 Wellpath: GSS <0-351'>MWD w/Sag<483 - 8023'> Date Printed: 28-Jul-2004 .¡. BAKER HUGHES JNTEQ Comments MOfftL- I TVOfftl JNorthfftl East ft ~mmenL _-ªº2MO !~58Uº-~37a9.5~S_~891.46E_¡Pro~çted to Bit OeÆb_~__________ ----- -~ -----_..~--~--¡ Hole Sections Diameter 'I Start Start Start I Start finl , MOfftl TVDfftl Northfftl I Eastfftl 16.0.0.0 : 0..0.0. 0..0.0. D.DDN, D.DDE -.-.--.---..-r----.---.~---.---.-~_m_-~-. 121/4 . 30.45.0.0. 2317.11 18D.46S i 1516.D6E 81/2 6933.0.0. 360.6.57 272D.79S· 3077.78E End MOfftl 30.45.0.0. 6933.0.0. 80.23.0.0. End I End Start TVDfftl . Northfftl Eastfftl ~ 2317.1L-.-~D.46S_~!?16.D6E---112 PB1 _~_~__! 360.6.57 ¡ 272D.79S 3D77.78E 112 PB1 ! 3581.30. ! 3789.53S 2891.46E 112PB1 Wellbore Casings Name I¡TOP Top Top Top Shoe Shoe ¡Shoe - Shoe MOfftl _ TV-ºfftL__ Northf~~.. EastIf!}~--.M~~_DLº£f!L~__tNort.blftL_Eas!ffll )0." Conductor O.Q-º-__-.JJ.DD____D.OQr'-_+-D.ODE _~.-1Q8.Dº- 1 D8.QL~__D.DDN _D.DQL--..112-"'-e.L______ 133/8" Surface 0..0.0. 0..0.0. D.DDN i D.DDE 30.29.44 230.9.89 i 176.93S 15D2.73E 112 PB1 ~~ ! . ! -95/8"lntermediatel~-- 0..00. -a.DDN ~!-o.~-6924.58-36D5.33! 2712.71S 3D79.82E 112P~---- casinQ! i !___~J 51/2" Liner 5839.0.0. 341D.D5~ 1664.19S!3277.46E-11241.DÜ- 3338.0716997.57S - 2499.52E 112 L2 51/2" Liner 6095.0.0 3467.20. 191D.78S I 3239.96E 11252.0.2 3410..03 I 6996.91S 2448.65E 112 L 1 51/2" Liner 6776.0.0. 3581.46 257D.D9S! 3113.91E 11296.93 3602.0.6 i 7D37.5DS 2498.65E 112 Wellbore All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig (Doyon #141 RKB 95.Dft above mean sea level) Vertical Section is from D.DDN D.DDE on azimuth 186.41 degrees Bottom hole distance is 4766.66 Feet on azimuth 142.66 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Ke: 14 Day BOPE Test-lE-112 and lateral (204-091, 204-092, 204-093) . . Subject: Re: 14 Day BOPE Test-1E-112 and lateral (2(}4..091, 204-092, 204-093) From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Thu, 24 Jun 2004 15:02:14 -0800 To: "Shultz, Steven M" <Steven.M.Shultz@conocophillips.com> Steve, r concur with your assessment of the performance of Doyon 141. By copy of this email, a BOP test interval not to exceed 14 days is authorized for KRU 1E-112 and laterals. Tom Maunder, PE AOGCC Shultz, Steven M wrote: Tom, As you know we have permitted 1E-112 for "Drill and Complete" prior to the acceptance by AOGCC for the 14 day BOPE testing. r am requesting that 1E-112 be given permission from the state to also under the 14 day ruling for the following: 1. Doyon 141 has been the rig drilling all of the West Sak wells for the last 1 1/2 years and has a good record of BOP testing, of course at start up the rig had some issues with the variable rams but since then the tests have been good 2. The West Sak area being drilled is expected to be at or below normal formation pressures (8.4 to 8.6 ppg MWE) 3. There has been no injection of water or WAG in the areas to be drilled 4. Doyon 141 has an excellent record of compliance for state regulations and will continue to do so under the auspices of ConcoPhillips Thanks Steve Shultz I of I 6/24/2004 3 :02 PM Re: lE-112 next latest version e . Subject: Re: 1E-112 next latest version From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 02 Jun 200413:19:20 -0800 To: Steve Shultz <Steven.M.Shultz@conocophillips.com> CC: Steve Davies <steve _ davies@admin.state.ak.us> ~~09f Steve, As I continue to review questions come up. Sorry to clutter your in box. This question is "serious". We may have talked of this previously. Since this will be an injection well, one of the tasks we (CPAI and AOGCC) have to perform is what is called an "area of review". What it involves is assessing the isolation of existing wells lying within 1/4 mile radius of the well you plan to drill or convert. In the case of 1E-112 we have so far identified 2 wells (there may be more) that are within that distance, 1E-33 and 1E-22. \ ~ \ ~ ~<è:. c>.. \\~ c..."-. (ttJ ~ <YT~ What I am requesting is a proximity scan to determine all wellbores that are within 1/4 mile radius of lE-112 between the top of the D sand at 3379' tvd and the base of the A sand somewhere below 3630' tvd. The need is to verify that isolation (generally from cement and casing) is present over the proposed injection intervals in the wells determined to be within the area of review. As you well know, there are at least 3 vintages of wells at IE; 1980-1983 (lE-D1 - IE-3D), 1997-1998 (lE-31 -lE-36) and now. Most of the early vintage wells likely did not have casing set through the West Sak and even though most were likely down squeezed with arctic pak, it is probable that portions of the West Sak are not covered with cement. I think that Gary Targac has done some work on this issue with Mike Caseki(??) from Schlumberger and that can likely save a lot of work. Thanks in advance. Please call with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote: Hi Steve, I talked further with Steve Davies and I see that it is Section 16 rather than 21. Don't you hate pads that straddle section lines?? I also see that you are drilling the big bore. Been a while since 13-3/8" surface pipe was set at Kuparuk. Tom Steve, I have some more questions. CL..~o.\ \ ~ "<>\t-.:$ C( ~S ~ ~c... a Thomas Maunder wrote: Referring to your drawing, It appears that there will be tubing connecting to all laterals. Is that correct?? Does this completion provide pressure isolation for all the sands?? Are there any isolated annulus sections between the various sands?? If so, has the potential problem of,heating of trapped liquids been considered?? There is a DB nipple between the A and B laterals, but I do not see one between the Band D laterals. Is there to be one?? How will injection rates into the various laterals be controlled and determined?? What is the approximate depth of the upper zxp that will nominally function as your packer?? In the completion operation (- step 41), no mention is made of performing an MIT of the annulus. Regardless of the preproduction period, I would suggest that an lof2 6/2/2004 1 :23 PM Re: IE-II2 next latest version e MIT be conducted at this time while the rig is there. e Please call and we can discuss. Tom Maunder, PE AOGCC Thomas Maunder wrote: Steve, I am looking at the permit. Since this will be an injector, a bond log will be necessary. How/when do you proposed to run it?? Thanks, Tom Maunder, PE AOGCC 20f2 6/2/2004 I :23 PM ConocoPhil· s Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot#112 112 Wellbore: H2 Seale 1 em = 100 ft -> 1200 1400 1600 1800 2000 2200 2400 2600 3000 3200 3400 2800 3700 2500 4100 2900 4100 4500 3300 2900 5700 - 3.Z.QD 4900 '500 , 4500 2500 4100 2900 4900 ",,4500 ~ mips Created by: Pfáñner --- Date plotted Plot reference is 112. Ref wellpathis 112 Ver#3. Coordinates are in feet referenceSJot #112. True Verticai Depths ara reference Rig Datum Measured Depths are reference Rig Detum. Rig Datum: Doyon #141 RKB i Rig Datum to mean sealevel: 95.00 ft. LP~t North is aligned to TRUE North. 3600 4200 4400 3800 4000 2900 3300 i L 400 200 o -200 -400 -600 -800 -1600 , : I :- -1800 -2200 -2400 0 -2800 3 II 0 0 -3000 ;::1> ._~~~~-~~ ConocoPhiIlips Alaska., Inc. inips Kuparuk River Unit Installation: Pad 1E Well: 112 Wellbore: 112 Scale 1 cm:= 100 ft East (feet) -:> 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 2900 <~ , I [247r) -~-----../ 2900 5700 3700 4100 :.ßQQ 4900 '500 , 4500 2500 3700 4100 2900 4900 5300 2500 2900 4500 4100 ",4500 ~-- 400 -1600 -1800 -2000 e It a£ ïiiiiiõ·... Location: North Slope, Alaska Fie I d: Kuparuk RIver Unit Installation: Pad 1 E ConocoPhillips Alaska, Inc. L ,,:) "J ~ Slot: Slot #112 Well: 112 Wellbore: 112 conocJ'Phillips TRUE NORTH <.:reatecJ by : Plarrer Date plotted : 3-Jun-2004 -'IQ[ rererence IS 1 I L.. Ref wellpath is 112 Ver#3. Coordinates are in feet reference Slot #112. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Doyon #141 RKB Rig Datum to mean sea I : 95.00 It. Plot North is aligned to T E North. ~:'Õ "\ ?: ) Traveling Cyinder Depth Range: 5696' -11071'MD 10 ,)d- 340 20 330 30 320 310 50 300 60 290 70 80 1;;60 14ü0 90 110 240 120 230 130 220 140 210 1400 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well Kb. lb-11L e e Subject: RE: lE-112 From: "Shultz, Steven M" <Steven.M.Shultz@conocophillips.com> Date: Thu, 03 Jun 200411:08:15 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, We make the decision on whether to run the CEL after the intermediate cement operation by noting whether we were able to reciprocate pipe, pump good flow rates and circulate without losses. If we get all these operations in our favor then we wait until we run the A2 liner. The reason for waiting is to give the cement time to set up and give some compressive strength. What you and I have seen in the past is being to efficient and running a bond log within 12 to 18 hours after the cement job and "gee the bond looks suspect", we have waited on our last three injectors and had great results with definition on the CEL. In the event that the pipe could not be reciprocated, crummy flowrates or losses occur during the job, then the odds of a suspect cement job go way up and we elect to run the CEL which means we will probably have to wait on cement in order to get any kind of log at all, but that's the plan. Steve -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, JuneÕ"2-;--2-0 0·f-i2~Tò--PM---------------- To: Shultz, Steven M Subject: lE-112 Steve, I am looking at the will be necessary. Thanks, Tom Maunder, PE AOGCC permit. Since this will be an injector, a bond log How/when do you proposed to run it?? 1 of 1 6/4/2004 12:35 PM KE: 11:;,-112 e - Subject: RE: lE-112 From: "Shultz, Steven M" <Steven.M.Shultz@conocophillips.com> Date: Thu, 03 lun 2004 10:59: 1 0 -0800 To: Thomas Maunder <tom _ maunder@admin.state.ak.us> Tom, 1. Yes, tubing will be connected to all laterals with the new LEM system. 2. Yes, it will provide pressure isolation for each sand. 3. No, There will be no isolated annulus sections. Each section will be exposed to the lateral and therefore should not be subjected to trap pressures due to temperature differences or compressed fluid. 4. We have a nipple on bottom to isolate the A2 sand, to isolate the D and B sands requires a "LEM straddle" which is run into a profile in the LEM system that will isolate that particular sand but allow flow from the sand or sands below what ever may be the case. 5. You can plan on the upper ZXP being within ±150' of the top of the "D" sand liner top. 6. Good point about the MIT. Hey, this sounds like a good excuse for "Wings and Things" and I'll bring the drawings. Can't do it tomorrow but maybe next week. Steve -----Original Message----- From: Thomas Maunder [rnailto:torn rnaunder@adm.in.state.ak.usJ Sent: Wednesday, June 02, 2004 12:27 PM To: Shultz, Steven M Subject: Re: 1E-112 Steve, I have some more questions. Referring to your drawing, It appears that there will be tubing connecting to all laterals. Is that correct?? Does this completion provide pressure isolation for all the sands?? Are there any isolated annulus sections between the various sands?? If so, has the potential problem of heating of trapped liquids been considered?? There is a DB nipple between the A and B laterals, but I do not see one between the Band D laterals. Is there to be one?? How will injection rates into the various laterals be controlled and determined?? What is the approximate depth of the upper ZXP that will nominally function as your packer?? In the completion operation (- step 41) I no mention is made of performing an MIT of the annulus. Regardless of the preproduction period, I would suggest that an MIT be conducted at this time while the rig is there. Please call and we can discuss. Tom Maunder, PE AOGCC Thomas Maunder wrote: Steve, I am looking at the permit. Since this will be an injector, a bond log will be necessary. How/when do you proposed to run it?? Thanks, Tom Maunder, PE AOGCC ~ 6/4/2004 12:35 PM . . FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH 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 IE-I 12 ConocoPhillips Alaska, Inc. Permit No: 204-091 Surface Location: 191' FSL,225.5' FEL, SEe. 16, TIlN,RI0E, UM Bottomhole Location: 1407' FNL, 2983' FEL, SEe. 27, TIIN, RIOE, UM Dear Mr. Thomas: Enclosed is the approved application for pennit to drill the above referenced development well. In your application it was stated that this well and the subsequent multi-lateral wellbores would be pre-produced and then converted to injection service after approximately 6 months. Regulation 20 AAC 25.402(c)(15) requires determination of the mechanical condition of any well penetrating the injection zone within a one-quarter mile radius of a proposed injection well. In the case of IE-Il2, existing we1lIE-22 (182-214) is approximately 750' distant at the A-2 sand depth (-3700' tvd). The surface casing of IE-22 was set well above the West Sak sands (2600' md, 1845' tvd) and neither the Ugnu nor West Sak sands are covered with cement As currently planned, IE-112 and the laterals are designed to meet the requirements for injection wells as specified in 20 AAC 25.412. However prior to converting 1£-Il2 and laterals to injection service CPAI must provide information sufficient for the Commission to determine that the West Sak intervals in 1£-22 are or have been isolated to confine any fluids within zone. This pennit to drill does not exempt you from obtaining additional penn its 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. 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) 659-3607 (pa BY ORDER ~F ~E COMMISSION DATED this ~ of June, 2004 cc: Department ofFish & Game, Habitat Section wlo enc!. Department of Environmental Conservation wlo enc!. ·/ 1IÞ'l' ConocoÞhillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Steve Shultz Phone (907) 263-4620 Email: Steven.M.Shultz@conocophillips.com May 27,2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 1E-1l2, 1E-1l2 L1 and 1E-1l2 L2 Dear Commissioners: . . .6 . dl r'r, / d I'· - p)-1.-- to ~-' bLf VY'é:.- /prV .L(. e d· I t1J ¿<-./ . & /. ConocoPhillips Alaska, Inc. hereby applies for Permits tJ Drill fbr an onshore prodtICtion well, a multilateral horizontal well in the West Sak "A", "B" and "0" sands. The main bore of the well will be designated 1E-1l2, and the lateral bore of the well will be designated 1E-1l2L1 ("B" Sand) and 1E-1l2L2 ("0" 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-1l2 is 6/18/2004. If you have any questions or require any further information, please contact Steve Shultz at 263-4620. ]!~L Steve Shultz Greater Kuparuk Area Consulting Engineer '\{ii". .~;~"/ ,.·Þ.;'l·:~ i!··~·¡J~~~/L1 MAY.. ·7::D P. 82f1'O Gas VI "I- ~Con8.~'j> -.~ ~-"... 1a. Type .of Wark: Drill 0 Re-entry D 2. Operatar Name: ConocoPhillips Alaska, Inc. 3. Address: . . i-'e/'( RedrillU STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 pre... ,,¡rod u...>..i.c! '~,cìt?.J:f¡~ we.{( 5þ (" Î' 01 ExplarataryU Develapment Oil ~ Multiple Zane D servic~ Develapment Gas D Single Zane 0 5. Band: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-112 / 6. Praposed Depth: 12. Field/Pool(s): ., TVD: 3545' Kuparuk River Field 1b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Lacatian .of Well (Gavemmental Se¡tian): Surface: 191' FSL, 225.5' FEL, sec.~11N, R10E, UM Tap .of Productive Harizan: MD: 11071' t¡'bi 7. Property Designat!an: ALK 25651 & 25660 8. Land Use Permit: West Sak Pool 13. Approximate Spud Date: 6/18/2004 2562.5' FNL, 2515.5' FEL, Sec. 22, T11 N, R1OE, UM Tatal Depth: 1407' FNL, 2983' FEL, Sec. 27, T11N, R10E, UM . 4b. Lacatian .of Well (State Base Plane Caardinates): Surface: x- 550301 16. Deviated wells: Kickaff depth: 500 ft. 18. Casing Program Size Hale 42- 16- 12.25- 8.5- Casing 20"x34" 13-3/8- 9-5/8" 5.5" 19 Tatal Depth MD (ft): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee Praperty Plat ADL 469 & 470 9. Acres in Property: 2560 14. Distance ta Nearest Property: 15. Distance ta Nearest 10. KB Elevatian / Weight 94# 68# 40# 15.5# y- 5959781 Zone- 4 (Height above GL): 28 feet Well within Paal: 17. Anticipated Pressure (see 2.0 AAC 25..035) v' Maximum Hale Angle: 95° Max. Downhole Pressure: 1516 psig / Max. Surface Pressure: 1113 psig Setting Depth Quantity .of Cement Specificatians Tap Battam c. f. .or sacks Grade Caupling Length MD TVD MD TVD (including stage data) K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete L-80 BTC 3172' 28' 28' 3200' 2314' 616 sx AS Lite, 206.5 sx DeepCrete L-80 BTCM 6884' 28' 28' 6912' 3600' 638 sx DeepCrete L-80 DWC 4224' 6827' 3600' 11071 ' 3545' slotted liner PRESENT WELL CONDITION SUMMARY Tatal Depth TVD (ft): Plugs (measured) (Ta be campleted far Redrill and Re-Entry Operatians) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) CemontVolume rl'?ECf2fll121J TVD MAY 2 '.' AJ~ all & ' 6 2004 ~~ Comm~!¡ Length Size o D BOP Sketch U Diverter Sketch D IPerfOration Depth TVD (ft): Drilling Program~ Time v. Depth Plat U Seabed Repart D Drilling Fluid pragram 0 Date: Shallaw Hazard Analysis D 20 AAC 25.050 requirements 0 21. Verbal Appraval: Cammissian Representative: 22. I hereby certify that the faregaing is true and carrect ta the best .of my knawledge. Contact Steve Shultz @ 263-4620 Printed Name Randy Thomas Title Kuparuk Drilling Team Leader Signature ?~ iYI . _.J..~ fo~ KA"'PI ÍHOp..IIf~ Phone Z¡,.6-", JD Date t> 5/,. 7/04 , /~ Preoared bv Sharon Allsuo-Drake Commission Use Only Permit ta Drill '.' /. '. . I API Number: .. Permit Appraval Number: 2C.J7·- C9/ 50- 62Cì- 2-32.J (~CX") Date: Conditions of approval: Samples required DYes )&f No Mud log required Hydroge sulfide measures D Yes ~ No Directional survey required ~-~ ~~\?-\-E-.">~, \-'\\\9<:.st""~\~tJ.\~-\·~ \Q~ ~C8 ,,-- -\Ò '" ~\ ~ ~"- -\0, , '\ ,=";>.:) ,,,\·t~nD~:;" \- '6 ~~~\,I1t,£ ~ COMMISSIONER THE COMMISSION "'," i '1 ,1; o RIG 1 N A L Submit in duplicate Isee cover letter far ather requirements J8I' No D No DYes ßYes · .Plication for Permit to Drill, We1l1E-112 Revision No.O May 27,2004 Permit It - West Sak Well #1 E-112 ("A" Sand) Application for Permit to Drill Document Mo)xir'r'1izE W~II \[QII,J~ Table of Contents 1. Well Name .....................................................................................................................2 Requirements of 20 AAC 25.005 (f) ... ...... ......... ....... ................. ............. ......... ........ ...... ....... ........ ....... 2 2. Location Su m mary....................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ........................... ......... ..... ......... ........ .... ......... ........ ........ ......... 2 Requirements of 20 AAC 25.050(b) ...... ....... ........ ....... .......... ....... ........ ....... ....... ........ ....... ..... .... ......... 3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25.005(c)(3) ....... ....... ........ ........ ........ ....... .......... ..... ........ ....... ..................... 3 4. Dri II i ng Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .. ........ ........ ........ .............. ........ ............. .......... ...... .................. 3 5. Procedure for Conducting Formation Integrity Tests.............................................3 Requirements of 20 AAC 25.005 (c)(5) ...............................................................................................3 6. Casi ng an d Ceme nti ng Prog ra m................................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................4 7. Diverter System Information ......................................... ..... ........... ..................... ........4 Requirements of 20 AAC 25.005(c)(7) .. ..... ......... ...... ......................... .............. ........ ....... ....... ............. 4 8. Dri II i ng Flu id Prog ram................................................................................................. 5 Requirements of 20 AAC 25.005(c)(B) ..' ........ ......... ................. .............. ........ ...... ........ ...... ........... ...... 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................5 9. Abnormally Pressured Formation Information ........................................................5 Requirements of 20 AAC 25.005 (c)(9) ............................................................................................... 5 1 O. Seism ic Analysis.......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ....... ......... ......... ......... ..... .................. ... ......... ................. ....... 5 11. Seabed Condition Analysis ....................... ................................................................. 5 Requirements of 20 AAC 25.005 (c)(11) ............................................................................................. 5 12. Evidence of Bonding ............................ .......................................................................6 Requirements of 20 AAC 25.005 (c)(12) ............................................................................................. 6 PERMIT IT (Injector) RevO.doc Page 1 of 8 Printed: May 27,2004 ORIGINAL · .Plication for Permit to Drill, Well 1 E-112 Revision No.O May 27,2004 13. Proposed Dri lIing Program ........... ....... ....................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) .... ....... ....... ......... ...... ....... ....... ...................... ....... .......... ....... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................8 Requirements of 20 AAC 25.005 (c)(14) ............................................................................................. 8 15. Attach me nts.................................................................................................................. 8 Attachment 1 Directional Plan ...... .... ............. .................. ........ ..... ........ ........ ..... ................ ......... ......... 8 Attachment 2 Drilling Hazards Summary........ ........ ........ ......... ..... ........ ............. ......... ....... ..... ............. 8 Attachment 3 Cementing 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 branche~ 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 whieh this Application is submitted will be designated as 1E-112. 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 items, 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 surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the 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 FNL:5088.5', FEL:225.5', See 21, T11NjR10E, UM v ASP Zone 4 NAD 27 Coordinates I RKB Elevation I 94.3' AMSL Northings: 5,959,781' Eastings: 550,301 - Pad Elevation 66.3' AMSL Location at Top of Productive Interval (West Sak "AIf Sand) ASP Zone 4 NAD 27 Coordinates Northings:5,957,048 Eastings: 553,315 FNL:2562.5', FEL:2515.5, Sec 22, T11NjR10E, UM Measured Depth/ RKB: Total Vertical Depth/ RKB: Total Vertical Depth 55: 6827' 3600' 3505.7' Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings:5,952,921 Eastings: 552,883 FNL:1406.8', FEL2983', See 27, TllNjR10E, UM v Measured Depth/ RKB: 11071' Total Vertical Depth RKB: 3545' Total Vertical Depth 55: 3450.7' and (D) other information required by 20 MC 25.0S0(b); ORIGINAL PERMIT IT (Injector) RevO.doc Page 2 of 8 Printed: May 27,2004 · .Plication for Permit to Drill, Well 1 E-112 Revision No.O May 27,2004 Requirements of 20 AAC 25. 050 (b) If a well is to be intentionally deviateá the application for a Permit to Drill (Form 10-401) must (1) include a pla~ 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 we/~' 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 mai~' or (8) 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 (80PE) as required by 20 AAC 25.035, 20 MC 25.036, or 20 MC 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-1l2. 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 encountereá criteria used to determine i~ and maximum potential surface pressure based on a methane gradien~' The expected reservoir pressures in the West Sak sands in the lE-112 area vary from 0.0.41 to 0.0.44 v psi/ft, or 7.9 to 8.5 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 B sand formation is 1,422 psi, calculated thusly: MPSP =(3446 ft)(0.0.44 - 0.11 psi/ft) =1113.31 psi / (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. v 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 identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25. 030(f); The parent wellbore,lE-112, will be completed with 95/8" 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 (Injector) RevO.doc Page 3 of 8 Printed: May 27,2004 e .Plication for Permit to Drill, We1l1E-112 ~ Revision No.O May 27,2004 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 following items, 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 25.03~ 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 lE-112: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 20 X 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260d ArcticCRETE 13 3/8 16 68 L-80 BTC 3172 28 / 28 3200/2314 Cemented to Surface with 616 sx ASLite Lead, 206.5 sx DeepCRETE Tail 9 5/8 12 1/4 40 L-80 BTCM 6884 28 / 28 6912/3600 Cement Top planned @ 3400' MD / 2404'IVD. Cemented w/ 638 sx DeepCRETE 5 1/2 81/2" 15.5 L-80 DWC 4244 6827/3600 11071/3545 Slotted- no slotted "A" Lateral cement (lE-112) 51/2 81/2" 15.5 L-80 DWC 5066 5986/3446 11052/3370 Slotted- no slotted "B" Lateral cement ( lE-112 Ll) 5 1/2 81/2 15.5 L-80 DWC 5350 5696/3379 11046/3310 Slotted-no slotted "D" Lateral cement (lE-112 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 items, 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 MC 25. 035., unless this requirement is waived by the commission under 20 MC 25.035(h}(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of lE-112. Please see diagrams of the Doyon 141 diverter system on file with the Commission. PERMIT IT (Injector) RevO.doc Page 4 of 8 Printed: May 27,2004 ORIGINAL e .Plication for Permit to Drill, Well 1 E-112 Revision No.O May 27,2004 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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 fiuid program, including a diagram and description of the drilling fluid 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) 8.6-9.6 9.8-10 9 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. >' 9. 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 reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. 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 dolled from an offshore platform, mobile bottom-founded structure, jack-up rift or floating drilling vesse~ an analysis of seabed conditions as required by 20 AAC 25.061(b),· Not applicable: Application is not for an offshore well. ./ I V ORIGINAL PERMIT IT (Injector) RevO.doc Page 5 of 8 Printed: May 27,2004 . .Plication for Permit to Drill, Well 1 E-112 Revision No.O May 27,2004 11. Evidence of Bonding Requirements of 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 AAC 25.025 {Bonding}have been met/ Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. ./ 12. Proposed Drilling Program Requirements of 20 AAC 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 lE-112 is listed below. 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 +/- 3200' MD / 2314' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13 3/8", 68#, L-80, BTC casing to surface. Displace cement with mud and, pressure test casing to 250Qpsi 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 ó9tzMD / 3600' TVD. 9. Run 9 5/8", 40# L-80, BTCM Mod casing to surface. Pump cement and displace with mud and pressure test casing to3jtMJÐ fJ9ifór 30 minutes and record results. 10. Install wellhead 9 5/8" packoff and test to 5000 psi. 11. Flush 13 3/8" x 9 5/8" annulus with water, followed by diesel. 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. . \\J <~ 14. Directionally drill 8 1/2" hole to TD at +/- 11071' MD / 3545' TVD as per directional plan. 15. 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 and liner to weighted brine. POOH. (/)¡ote-i"'RêñíãininQ;perations a-;~ov;r~~der th~l E-112L1 Application for Permit to Drill, and are ~_~..Q~forJnf.Qrmation ~__ .____ 18. Run and set Baker WindowMaster whipstock system, at window point of 5'986'MD / 3446' TVD, the top of the B sand. -". ~\\d.. \ 'Ç- t ~ 19. Mill 8 1/2" window. POOH. ORIGINAL PERMIT IT (Injector) RevO.doc Page 6 of 8 Printed: May 27,2004 · .Plication for Permit to Drill, Well 1 E-112 Revision No.O May 27,2004 20. Pick up drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of B sand lateral at 11052' MD / 3370' ND, 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, latch into hook hanger, shea rout and POOH Note: Remaining operations are covered under the 1E-112L2 Application for Permit to Drill, and are provided here for information only. 28. Run and set Baker WindowMaster whipstock system, at window point of 56'96' MD / 3379' ND, the top of the D sand. 29. Mill 8 1/2" window. POOH. 30. Pick up drilling assembly with LWD and MWD and PWD. RIH. 31. Drill to TD of D sand lateral at 11046' MD /3310' ND, 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. PU "Lateral Entry Module", RIH, latch into hook hanger, shear out, POOH 38. POOH and lay down drill pipe 39. RU and run 4 h" tubing completion 40. Space out tubing and stab seals into PBR, land tubing, pressure up annulus and shear out GLM, set BPV 41. Nipple down BOPE, nipple up tree and test 42. Move rig off. 43. Freeze protect well with diesel by pumping into 4 1/2"" x 9 5/8" annulus, taking returns from tubing and allowing to equalize. 44. Rig up wire line unit. Pull BPV 45. Retrieve RP shear, set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. 46. Replace gas lift valves with blank dummy valves. 47. Place well on injection. PERMIT IT (Injector) RevO.doc Page 7 of 8 Printed: May 27,2004 ORIGINAL · .Plication for Permit to Drill, Well 1 E-112 Revision No.O May 27,2004 13. 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 well; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lE 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 lE 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. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cementing Data Attachment 4 Well Schematic ORIGINAL PERMIT IT (Injector) RevO.doc Page 8 of 8 Printed: May 27,2004 Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 5/21/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 20",91.5# casing at 120' MD ;llJi , ¿ .... < Base of Permafrost at 1,583' MD (1,506' TVD) < Top of Tail at 2,400' MD < 133/8",72.0# casing in 16" OH TD at 3,200' MD (2,314' TVD) Mark of Schlumberger Ichl þø~glJJI Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,400' MD. Lead Slurry Minimum pump time: 250 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (120') x 1.00 (no excess) = 0.4206ft3/ft x (1583' -120') x 3.50 (250% excess) = 0.4206 ft31ft x (2400' - 1583') x 1.35 (35% excess) = 122.3 ft3 + 2153.7 ft3+ 463.9 ft3 = 2739.9 ft3 14.45 ft3/sk = Round up to 620 sks 122.3 ft3 2153.7 ft3 463.9 ft3 2739.9 ft3 615.7 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 180 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.4206 ft3/ft x (3200' - 2400') x 1.35 (35% excess) = 0.8315 ft3/ft x 80' (Shoe Joint) = 454.2 ft3 + 66.5 ft3 = 520.7 ft31 2.52 ft3/sk = Round up to 210 sks 454.2 ft3 66.5 ft3 520.7 ft3 206.6 sks BHST = 46°F, Estimated BHCT = 63°F. (BHST calculated using a gradient of 2.6"F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) 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 7.0 488.0 69.7 103.0 DeepCRETE 5.0 92.7 18.5 121.5 Pause 0.0 0.0 5.0 126.5 Water 5.0 20.0 4.0 130.5 Pause 0.0 0.0 5.0 135.5 Mud 7.0 427.0 61.0 196.5 Mud 3.0 15.0 5.0 201.5 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 20, Ty < 20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv > 30, Ty > 20 Centralizers: Recommend 1 per joint throughout tail slurry ORIGINAL Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 5/21/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 em ail: martin13@slb.com Previous Csg. < 133/8",72.0# casing at 3,200' MD < Top ofTail at 3,450' MD . ;,1 Jlf/1U ¡',; ,,)/ ¿¿;Jeé < 95/8",40.0# casing in 121/4" OH TD at 6,912' MD (3,607' TVD) 1Gb Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 30% excess. Slurry is designed for SOO' MD above UGNU- (3462' MD annular length). Tail Slurry Minimum thickening time: 230 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 0.3132 ft3/ft x 3462' x 1.30 (30% excess) = 0.4257 ft3/ft x 80' (Shoe Joint) = 1409.6ft3 + 34.1 ft3 = 1443.7 ft3¡ 2.26 ft3/sk = Round up to 640 sks 1409.6 ft3 34.1 ft3 1443.7 ft3 638.8 sks BHST = 80°F, Estimated BHCT = 70°F. (BHST calculated using a gradient of 2.6"F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (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 MUDP USH II 6.0 40.0 6.7 24.7 Pause 0.0 0.0 5.0 29.7 DeepCRETE 5.0 257.1 51.4 81.1 Pause 0.0 0.0 5.0 86.1 Mud 7.0 500.0 71.4 157.5 Mud 3.0 18.0 6.0 163.5 MUD REMOVAL Recommended Mud Properties: 9.2 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 21-23, Ty = 25-28 Centralizers: Recommend 1 ~ per joint from TD to 5000' and 1 per jint above and below UGNU. ORIGINAL · . lE-112 Drillina Hazards Summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 16" Open Hole /133/8" Casina Interval Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Hole swabbing on trips Risk Level Low Low ,¡' Moderate Moderate Mitigation Strategy Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Trip speeds, Proper hole filling (use of trip sheets), pumping out 12 1/4" Open Hole / 9 5/8" Casing Interval Hazard Running Sands and Gravels Stuck Pipe Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Risk Level Moderate Low Low .j Low Moderate Mitigation Strategy Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, Decreased mud weight BOP training and drills, increased mud weight. Reduced pump rates, mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), pumping out 8 1/2" Open Hole / 5 1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Moderate High Mitigation Strategy \,/ Stripping drills, Shut-in drills, Increased mud weight. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weight Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out 1 E-112 Drilling Hazards Summary prepared by Steve Shultz 5/1/2004 2:00 PM 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 63.62 3100.55 553330.16 842.678 5.00 56 64.76 3144.11 553370.40 23.418 5.00 57 66.09 3185.73 553403.30 008.368 5.00 58 67.60 3225.08 553428.58 096.888 5.00 59 ~ 69.27 3261.86 553446.08 1188.298 5. 60 71.08 ;3295.79 553455.64 1281.898 5. 61 73.03 3326.62 553457.20 1376.998 5. 62 75.00 3353.12 553451.14 1469.168 5.00 63 .- 75.00 3354.11 553450.75 1472.848 0.00 64 75.00 3379.00 553441.00 565.148 0.00 65 75.00 3379.99 553440.61 1568.838 0.00 66 75.00 3405.88 553430.47 1664.828 0.00 67 75.00 3407.99 553429.64 1672.648 o. 68 78.00 3431.32 553419.43 1769.268 3.00 69 80.00 3444.00 553412.58 1834.078 3.00 70 80.00 3448.41 553409.95 1858.938 0.00 71 80.00 3465.78 553399.61 1956.808 0.00 72 80.00 3483.14 553389.27 2054.668 0.00 73 80.00 3500.51 553378.93 2152.538 0.00 74 80.00 3517.87 553368.59 2250.398 0.00 75 80.00 3535.24 553358.25 2348.268 0.00 76 80. 3552.60 553347.90 2446.128 0.00 77 80.00 3569.96 553337.56 2543.998 0.00 78 80.00 3587.33 553327.22 2641.858 0.00 79 80.00 3604.69 553316.88 2739.728 o. 80 80.00 3608.87 553314.39 2763.248 O. 81 83.04 3620.07 553306.51 837.898 4.00 82 87.04 3628.72 553296.05 2936.878 4.00 83 91.04 3630.40 553285.55 3036.228 4.00 84 91.15 3630.34 553285.27 3038.898 4.00 85 93.65 3626.16 553274.78 138.178 2.50 86 94.46 3623.86 553271 .37 3170.408 2.50 87 94.46 3618. 553264.59 3234598 0.00 88 94.46 3611. 553254.12 3333.678 0.00 89 94.46 3603. 553243.66 3432.748 0.00 90 94.46 3595. 553233.19 3531.818 0.00 91 94.46 3593.82 553230.92 3553.308 0.00 92 91.96 3588.22 553220.44 3652.518 2.50 93 91.15 3587.34 553217.02 3684.818 2.50 94 88.65 3587.52 553206.52 3784.188 2.50 95 87.80 3588.57 553202.97 3817.798 2.50 96 87.80 3589.03 553201.72 3829.668 0.00 97 87.80 3592.87 553191.23 3928.978 0.00 98 87.80 3596.71 553180.73 4028.278 0.00 99 87.80 3600.55 553170.24 4127.578 o. 100 87.80 3603.11 553163.24 4193.868 0.00 101 90.30 :3604.77 553152.74 4293.228 2.50 102 91.15 3604.34 553149.19 4326.848 2.50 103 93.65 3600.16 553138.70 4426.128 2.50 104 94.60 3597.42 553134.70 4463.958 2.50 105 94.60 3592.51 553128.29 4524.608 0.00 106 94.60 3584.49 553117.83 4623.668 0.00 107 94.60 3576.47 553107.36 4722.718 0.00 108 94.60 3568.45 553096.90 4821.778 0.00 109 94.60 :3566.60 553094.49 4844.598 0.00 110 92.67 3561.72 553086.46 4920.928 2.50 111 91.34 3559.85 553080.95 4973.788 2.50 112 88.84 3559.69 553070.61 5073.168 2.50 113 88.04 3560.57 553067.28 5105.278 2.50 114 88.04 3561.06 553065.78 5119.648 0.00 115 88.04 3564.49 553055.46 5218.978 0.00 116 88.04 3567.92 553045.13 5318.318 0.00 117 88.04 3571.35 553034.80 5417.648 0.00 f 118 88.04 3573.89 553027,15 119 90.54 :5575.1 553016.82 120 91.34 3574.61 553013.48 121 93.84 3570.09 553003.16 122 94.65 3567.70 552999.83 123 94.65 3562.73 552993.52 124 94 3554.62 552983.22 125 94.65 3546.51 552972.92 126 94.65 3538.4 552962.62 127 94.65 3536.29 552959.94 128 92.15 3530.36 552949.63 129 91.34 3529.38 552946.29 130 88.84 3529.22 552935.96 131 88.22 ~~529.86 552933 132 88.22 3530. 552931.66 133 88.22 3533. 552921.33 134 88.22 3536. 552911.00 135 88.22 3539. 552900.67 136 88.22 3542.79 552890.34 137/ 88.22 3545.00 552883.00 <= I.!) -350 "- II E 0 -0 Q) Iii 0 (f) 350 o 700 ::::tl. 1050 ~ ~1400 ;q. ~ 1750 I ~ :e 2100 ~ ~ 2450 ... ~ . V 2800 3150 3500 3850 4200 'II: !NTJ';¡l·-·-- A 20 00010 COO'""O' KOP 6.00 Bid 4/100 18.00 Bid 5/100 Bid 3/100 27.45 Bid 5/100 38.06 Base Permafrost 48.06 Top T-3 EOC ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #112 Well: 112 Well bore: 112 Top K-15 Trn 4/100 62.92 EOC .::; 13 3/8" Casing PI. To!) Ugnu C BldlTrn 5/100 DLS: 5.00 deg/100ft Top Ugnu B Top Ugnu A 66.09 K-13 61.93 61.47 61.49 -350 0 350 Scale 1 cm = 175 ft 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 Vertical Section (feet) -> Azimuth 104.04 with reference 0.00 N, 0.00 E from Slot #112 Conoc~illips I Created by : Planner I . Date plotted: 19-May-2004 Plot reference is 112. Ref well path is 112 Vel#3. Coordinates are in feet reference Slot #112. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Doyon #141 RKB Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. '--"" . . C~ I~ (¡') - z= I» ß 2400 I. § I 1ir 2700 I ~ 3000 I. .. Q. CD C 3300 ns (,) :e ~ CD ::::s L. I- 3600 3900 I V 4200 4500 .£ iNTF.Q~ ~.._~ Point Tie on End of Hold End of BuildlTurn End of Build End of Build End of Build End of Build KOP End of Turn End of Hold End of BuildiTurn Target WS 1 E D4 D TOP End of Hold End of Build End of Hold End of BuildlTurn End of Build End of Hold End of Drop End of Drop End of Hold End of Build End of Build End of Hold End of Drop/Turn End of Drop End of Hold End of Build End of Build End of Hold End of Drop KOP T.D. & Target WS 1 E D4 ~ ..... ':;<>R> 0<¡,,\~,,Çj c.!l>'f. ~Å-:' 1I." Oç ~\I.> (, ~0'fj -<,. V,<;-O-<,.oç ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Slot: Slot #112 Field: Kuparuk River Unit Well: 112 Installation: Pad 1E Well bore: 112 WELL PROFILE DATA MO Ine Azi 1VD North East dog/100ft 0.00 0.00 0.00 0.00 0.00 000 0.00 500.00 0.00 0.00 soo.oo 0.00 0.00 0.00 833.33 10.00 95.00 831.64 -2.53 26.90 3.00 1063.33 20.00 95.00 1072.82 ·8.16 93.28 4.00 1112.40 21.45 95.00 1100.00 -9.06 103.53 5.00 1332.76 28.06 95.00 1300.00 -17.10 195.41 3.00 2030.08 62.93 95.00 1781.27 -59.78 683.25 5.00 2808.85 62.93 95.00 2044.66 .104.69 1196.65 0.00 2810.00 62.93 104.04 2136.35 .134.27 1373.04 4.00 4064.37 62.93 104.04 2707.17 ·405.20 2456.65 0.00 5596_17 75.00 186.41 3:353_12 -146916 3140.69 5.00 569616 75.00 186.4'1 3379.00 -156514 3129.90 0.00 580815 75.00 186.41 3407.99 -1672_64 3117.82 0.00 5974.60 80.00 186.41 3444.00 .1834.07 3099.68 3.00 6924.04 80.00 186.41 3608.87 -2763.24 2995.26 0.00 7202.69 91.15 186.41 3630.34 ·3038.89 2984.29 4.00 7335.21 94.45 186.41 3623.86 ·3170.40 2949.51 2.50 7721.68 94.46 186.41 3593.82 ·3553.29 2906.49 0.00 7854.20 91.15 186.41 3587.34 ·3684.81 2891.71 2.50 7988.04 87.80 186.41 3588.57 ·3817.79 2876.77 2.50 8368.76 87.80 186.41 3803.11 -4193.86 2834.51 0.00 8500.60 91.15 186.41 3604.34 -4326.84 2819.57 2.50 8638.76 94.60 186.41 3597.42 -4453.95 2804.16 2.50 9023.04 94.60 186.41 3566.60 -4844.59 2761.39 0.00 9153.22 91.34 186.32 3559.85 -4973.78 2745.99 2.50 9285.54 88.04 186.32 3560.57 -5105.27 2732.44 2.50 9674.11 88.04 186.32 3573.89 -5491.26 2689.72 0.00 9806.43 91.34 186.32 3574.61 -5622.76 2675.17 2.50 9938.71 94.65 186.32 3567.70 -5754.04 2660.64 2.50 10326.06 94.65 186.32 3536.29 -6137.77 2618.17 0.00 10458.34 91.34 186.32 3529.38 -6269.05 2603.64 2.50 10583.22 88.22 186.32 3529.86 -6393.16 2589.91 2.50 11071.07 88.22 166.32 3545.00 -6877.81 2536.27 0.00 ~"\ Ç¡r¡,.. ~ ----v '\. \)b< (, . ~ « \)\)'ò-:'. ,<;-0 S~ þ,\^' ,'V'?>'~\Ò ~'ò \Ç¡ ~r¡,. 600 900 1200 1500 Scale 1 cm = 150 ft 1800 2100 2400 V. Sect 0.00 0.00 ·0.71 -2.31 ·2.56 -4.83 -16.90 -29.60 ·19.91 128.31 1109.23 '12058"1 1313.99 1476.44 2411.45 2688.84 2821.18 3206.48 3338.82 3472.64 3851.08 3984.90 4122.86 4505.90 4635.89 4768.19 5156.53 5288.83 5420.91 5806.99 5939.07 6063.93 6551.55 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 Vertical Section (feet) -> Azimuth 186.41 with reference 0.00 N, 0.00 E from Slot#112 Conoc~illips Created by 1 Planner Date plotted: 19-May-2004 Plot reference is 112. - Ref well path is 112 Ver#3. Coordinates are in feet reference Slot #112. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datuml Doyon #141 RKB Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. . .~0<" v~ \'i>ç. <:," -<,.<:) 112L2 --"'I ~<:) 112L 1 . ,^0<" v" \'i>ç. <:," 5700 6000 6300 6900 6600 7200 · .- ,~-~--- 4: ÌNTEÒ ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #112 Well: 112 Well bore: 112 Conoc~illips Created by: Planner Date plotted: 18-May-2004 Plot reference is 112. Refwellpath is 112 Ver#3. Coordinates are in feet reference Slot #112. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Doyon #141 RKB Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. p' Scale 1 em = 250 ft -2500 -2000 -1500 -1000 -500 o 500 East (feet\ -> 1000 15ðo 2600 2500 3000 3500 4000 4500 5000 5500 ESTI MATED SURFACE LOCATION: 191' FSL, 226' FEL SEC. 16,T11N, R10E ~\"()~()() 95 Az ~o%\~\Ò&\\"~"~c, 't./~"()() -.-L:J ~ <Q\Ò ~ ~ o'¥;.~~<;,oc, ::::r--~ ----<J os\. ~:~ ~q}.~ ~ o"Q ~0~ <Qø.S0 500 «0 iP~ "c,'Õ- ,,:>\'õ ",,:> \:l£~:~\" ()() ~o\\òI \ 104.04 A.z o -500 Top U9nu B Top U9nu A K-13 ~ -1000 TOP WEST SAK 0 LOCATION: 1375' FNL, 2379' FEL SEC. 22, T11N,R10E EOC Top West Sak D Bid 3/100 Top West Sak B EOC A-4 A-3 ~ -1500 ~ -2000 9 5Iff' Casing ptJ - -2500 TOP WEST SAK B LOCATION: 1655' FNL, 2411' FEL SEC. 22, T11N, R10E A-2 Bid 4/100 EOC - -3000 TOP WEST SAK A2 LOCATION: 2562' FNL, 2515' FEL SEC. 22, T11N, R10E - -3500 !' Z o - -4Ooo::+' ::r ~ -4500 ~ - > N - -5000 - -5500 - -6000 ~ -6500 LTD 5 112in Liner - -7000 1 E-112/1E-112L 1/1 E-112L3 TO LOCATIONS: 1407' FNL, 2296' FWL v SEC. 27, T11N, R10E - -7500 en o II) ëÐ - -8000-; 3 II - -8500 ~ o ;::I! ORIGINAl . Baker Hughes Incorpo.led Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 0.00 to 11066.33 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive Wellpath Date: 12/9/2003 Validated: No Planned From To Survey ft ft 0.00 11066.33 Planned: 1E-112 VerS#3V17 Version: 0 Toolcode Tool Name MWD+SAG MWD + Sag correction Summary 112,1E-112,1E-112 Ver 11066.33 11066.33 0.00 338.18 -338.18 FAIL: Major Risk Pad 10 113 10-113 V1 4700.00 6175.00 4964.81 362.99 4601.82 Pass: Major Risk Pad 10 114 1D-114VO 4900.00 5950.00 5149.06 299.16 4849.91 Pass: Major Risk Pad 10 116 10-116 V1 5000.00 6150.00 3829.01 269.06 3559.95 Pass: Major Risk Pad 10 122 10-122 VO 5252.80 5428.00 4262.98 177.39 4085.59 Pass: Major Risk Pad 10 124 10-124 VO 5459.19 5025.00 5014.42 134.77 4879.64 Pass: Major Risk Pad 10 125 10-125 V1 5808.15 5779.00 4109.68 169.25 3940.44 Pass: Major Risk Pad 10 126 10-126 VO 6543.27 6700.00 3055.80 220.10 2835.70 Pass: Major Risk Pad 10 127 10-127 VO 8282.71 7416.00 3033.49 339.32 2694.17 Pass: Major Risk Pad 10 128 10-128 VO 7128.03 6564.00 3985.79 256.25 3729.54 Pass: Major Risk Pad 10 129 10-129 VO 6437.92 5100.00 5178.35 205.55 4972.81 Pass: Major Risk Pad 1 D 131 10-131 VO 7833.32 6455.00 4965.71 297.66 4668.06 Pass: Major Risk Pad 1 D 3 1 D-03 VO 5300.00 6375.00 4899.16 150.97 4748.19 Pass: Major Risk Pad 1 D 7 10-07 VO 7744.53 7900.00 4956.02 346.34 4609.68 Pass: Major Risk Pad 1 E 10 1E-10 VO 555.83 575.00 1030.47 8.33 1022.13 Pass: Major Risk Pad 1 E 102 102 B-Lateral VO Plan: 349.99 350.00 300.53 4.97 295.56 Pass: Major Risk Pad 1 E 102 102 D-Lateral VO Plan: 349.99 350.00 300.53 4.97 295.56 Pass: Major Risk Pad 1 E 103 103 VO Plan: 1E-103 VE 374.98 375.00 260.85 5.47 255.38 Pass: Major Risk Pad 1E 104 104 VO Plan: 1E-104 VE 1068.43 1075.00 249.10 22.50 226.60 Pass: Major Risk Pad 1E 105 105 A2-Lateral VO Plan 549.28 550.00 202.21 9.22 192.99 Pass: Major Risk Pad 1E 105 105 B-Lateral VO Plan: 549.28 550.00 202.21 9.22 192.99 Pass: Major Risk Pad 1E 105 105 D-Lateral VO Plan: 549.28 550.00 202.21 9.22 192.99 Pass: Major Risk Pad 1E 11 1E-11 VO 499.99 500.00 937.52 7.36 930.15 Pass: Major Risk Pad 1E 112 1 E-112L 1 VO Plan: 1 E-1 4350.00 4350.00 1.09 270.55 -269.46 FAIL: Major Risk Pad 1E 112 1E-112L2 VO Plan: 1E-1 4350.00 4350.00 1.09 270.55 -269.46 FAIL: Major Risk Pad 1E 114 114 A2-Lateral VO Plan 499.63 500.00 101.57 8.16 93.41 Pass: Major Risk Pad 1E 114 114 B-Lateral VO Plan: 499.63 500.00 101.57 8.16 93.41 Pass: Major Risk Pad 1E 114 114 D-Lateral VO Plan: 499.63 500.00 101.57 8.16 93.41 Pass: Major Risk Pad 1E 117 117 A2-Lateral VO Plan 275.00 275.00 180.17 3.36 176.81 Pass: Major Risk Pad 1E 117 117 B-Lateral VO Plan: . 275.00 275.00 180.17 3.36 176.81 Pass: Major Risk Pad 1E 117 117 D-Lateral VO Plan: 275.00 275.00 180.17 3.36 176.81 Pass: Major Risk Pad 1 E 119 119VO Plan: 1E-119Ve 275.00 275.00 220.18 3.35 216.83 Pass: Major Risk Pad 1 E 1 1 E-01 VO 520.59 525.00 412.18 7.72 404.46 Pass: Major Risk Pad 1 E 1 1 E-01A VO 520.59 525.00 412.18 7.72 404.46 Pass: Major Risk Pad 1 E 121 121 B-Lateral VO Plan: 499.95 500.00 881.65 8.07 873.58 Pass: Major Risk Pad 1E 121 121 D-Lateral VO Plan: 499.95 500.00 881.65 8.07 873.58 Pass: Major Risk Pad 1E 12 1 E-12 VO 537.50 550.00 847.46 8.02 839.44 Pass: Major Risk Pad 1 E 123 1 E-123 L1 V1 Plan: 1 E- 862.13 950.00 785.57 15.99 769.59 Pass: Major Risk Pad 1 E 123 1 E-123 V8 862.13 950.00 785.57 16.60 768.97 Pass: Major Risk Pad 1 E 126 126 A2-Lateral VO Plan 3675.68 4025.00 385.29 235.11 150.18 Pass: Major Risk Pad 1 E 126 126 B-Lateral VO Plan: 3675.68 4025.00 385.29 235.11 150.18 Pass: Major Risk Pad 1 E 126 126 D-Lateral VO Plan: 3675.68 4025.00 385.29 235.11 150.18 Pass: Major Risk Pad 1 E 13 1 E-13 VO 537.65 550.00 765.53 8.02 757.51 Pass: Major Risk Pad 1 E 14 1 E-14 VO 537.82 550.00 692.65 8.02 684.62 Pass: Major Risk Pad 1 E 15 1E-15 VO 518.95 525.00 640.94 7.69 633.25 Pass: Major Risk Pad 1E 16 1E-16 VO 538.10 550.00 601.34 8.03 593.31 Pass: Major Risk Pad 1E 166 166 A2-Lateral VO Plan 11062.53 8925.00 954.85 533.63 421.22 Pass: Major Risk Pad 1 E 166 166 B-Lateral VO Plan: 11059.01 8900.00 971.90 500.99 470.91 Pass: Major Risk Pad 1 E 166 166 D-Lateral VO Plan: 11066.33 8900.00 984.94 495.58 489.36 Pass: Major Risk Pad 1 E 168 168 A2-Lateral V3 Plan 6093.69 5950.00 590.65 119.12 471.53 Pass: Major Risk Pad 1E 168 168 B-Lateral VO Plan: 6093.69 5950.00 590.65 119.11 471.54 Pass: Major Risk ORIGINAL · Baker Hughes Incorporled Anticollision Report Summary Pad 1 E 168 168 D-Lateral VO Plan: 6093.69 5950.00 590.65 119.12 471.54 Pass: Major Risk Pad 1E 170 170 A2-Lateral VO Plan 374.84 375.00 604.01 5.21 598.80 Pass: Major Risk Pad 1E 170 170 B-Lateral VO Plan: 374.84 375.00 604.01 5.21 598.80 Pass: Major Risk Pad 1E 170 170 D-Lateral VO Plan: 374.84 375.00 604.01 5.21 598.80 Pass: Major Risk Pad 1E 17 1E-17 VO 519.10 525.00 591.22 7.69 583.53 Pass: Major Risk Pad 1E 18 1E-18 VO 720.57 725.00 343.47 11.16 332.32 Pass: Major Risk Pad 1 E 19 1E-19 VO 745.60 750.00 282.86 11.63 271.24 Pass: Major Risk Pad 1E 20 1E-20 VO 697.51 700.00 219.98 10.72 209.25 Pass: Major Risk Pad 1 E 21 1 E-21 VO 747.39 750.00 160.42 11.66 148.76 Pass: Major Risk Pad 1 E 2 1 E-02 VO 520.51 525.00 423.05 7.72 415.33 Pass: Major Risk Pad 1 E 22 1 E-22 VO 1100.72 1100.00 61.03 19.35 41.68 Pass: Major Risk Pad 1 E 23 1 E-23 VO 649.58 650.00 42.54 9.92 32.63 Pass: Major Risk Pad 1E 24 1 E-24 VO 0.00 0.00 20.28 0.00 20.28 Pass: Major Risk Pad 1E 24 1 E-24A VO 0.00 0.00 20.28 0.00 20.28 Pass: Major Risk Pad 1E 25 1 E-25 VO 774.19 775.00 80.67 12.19 68.47 Pass: Major Risk Pad 1E 26 1 E-26 VO 550.25 550.00 140.50 8.23 132.27 Pass: Major Risk Pad 1E 26 1 E-26A VO 550.25 550.00 140.50 8.23 132.27 Pass: Major Risk Pad 1 E 27 1 E-27 VO 541.89 550.00 649.14 8.09 641.06 Pass: Major Risk Pad 1E 28 1 E-28 VO 541.73 550.00 559.03 8.09 550.94 Pass: Major Risk Pad 1 E 29 1E-29 VO 520.70 525.00 491.75 7.72 484.03 Pass: Major Risk Pad 1 E 30 1E-30 VO 541.35 550.00 435.83 8.08 427.75 Pass: Major Risk Pad 1 E 31 1 E-31 V1 537.81 550.00 687.76 8.52 679.23 Pass: Major Risk Pad 1E 31 1E-31PB1 VO 537.81 550.00 687.76 8.52 679.23 Pass: Major Risk Pad 1E 3 1E-03 V1 865.85 950.00 458.49 13.82 444.67 Pass: Major Risk Pad 1E 32 1 E-32 VO 537.34 550.00 589.88 8.65 581.22 Pass: Major Risk Pad 1 E 33 1 E-33 VO 876.06 875.00 72.59 16.10 56.49 Pass: Major Risk Pad 1 E 33 1E-33PB1 VO 876.06 875.00 72.59 16.10 56.49 Pass: Major Risk Pad 1 E 34 1 E-34 VO 540.51 550.00 603.09 8.56 594.53 Pass: Major Risk Pad 1 E 35 1 E-35 VO 560.33 575.00 432.46 8.65 423.81 Pass: Major Risk Pad 1 E 35 35A VO Plan: 35A ST Ve 560.33 575.00 432.46 8.65 423.81 Pass: Major Risk Pad 1E 36 1 E-36 VO 299.99 300.00 1022.40 3.71 1018.69 Pass: Major Risk Pad 1E 4 1E-Q4 VO 540.67 550.00 534.63 8.07 526.56 Pass: Major Risk Pad 1E 5 1 E-05 VO 560.81 575.00 614.84 8.42 606.41 Pass: Major Risk Pad 1 E 6 1 E-06 VO 540.32 550.00 713.96 8.06 705.90 Pass: Major Risk Pad 1E 7 1 E-07 VO 560.30 575.00 809.68 8.42 801.26 Pass: Major Risk Pad 1E 8 1 E-08 V1 600.00 625.00 913.24 9.10 904.14 Pass: Major Risk Pad 1 E 9 1E-09 VO 537.09 550.00 1134.16 8.01 1126.15 Pass: Major Risk Pad 1E WSR#2 WS2 V1 3641.41 2575.00 1385.32 167.37 1217.96 Pass: Major Risk Pad 1J 10 1J-10 VO Out of range Pad 1J 1J-DQ 1J-L6 A Lateral V1 Pia 8745.86 11640.58 4942.81 452.14 4490.67 Pass: Major Risk Pad 1J 1J-DS 1J-L5 A Lateral V1 Pia 8882.94 12531.63 3706.53 452.75 3253.78 Pass: Major Risk Pad 1J 1J-DU 1J-L4 A Lateral V1 Pia Out of range Pad 1J 1 J-DW 1J-L3 A Lateral V1 Pia Out of range Pad 1J 9 1J-09 VO 11062.60 9650.00 4557.32 373.94 4183.38 Pass: Major Risk ORIGINAL Scale 1 em = 30 ft -120 0 120 180 240 ConoeoPhillips Alaska, Inc.. Conoc~Phillips 360 300 240 2300 180 2600 120 500 800 ^ 60 . 500 0 -60 -120 Location: North Slop~, Alas(~ Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #112 Well: 112 WeHbore: 112 Created Planner Date 20-May-2004 Plot reference is 112 Ver#3, Datum are oJ PROJECTED error ellipsoid 300 East (feet) -> 420 480 540 600 960 1020 1080 1140 1200 360 660 ï~)r, ;:;:..u 780 840 900 Scale 1 cm = 50 ft 1100 1200 1300 1400 ~ ~~ 1500 3000 2600 2600 1800 1600 HOO ConocoPhiHips Alaska, Inc. 'II1i1W/ ConocoPhillips Location: North Slope, Alaska Field: KlJparuk River Unit Installation: Pad 1E Slot: Slot#112 Well: 112 Wellbore: 112 Created by Planner Date plotted: 20"May~2004 Plot reference ìs 112. is 112 Ver#3 Measured reference Rig Datum Datum RK8 Datum to mean sea leve!: :95,00 ft. are scaled to 99.01 % (1 D) confidence 1800 East (feet}-> 2'100 2200 2300 2400 2500 3300 1900 2000 2600 2700 2800 2900 3000 3"100 3200 100 0 -100 2600 -200 1!2~) -300 2200 ^ 3800 -400 4000 -500 - 4200 ~ tÞ "'" -600 - -700 3400 -800 (J) 3600 -900 ("1 m (j) ("1 - -1000 3 II O"t 0 - -1100 ;::t> 3200 2800 3000 3200 . . c:onocri'Phillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 1 Well bore: 112 Well path: 112 Ver#3 Date Printed: 19-May-2004 ... awa. INTEQ Wellbore Name 112 'Well Name 112 Installation Name ~_~_ Pad 1 E I --~ EastinQ Northina 550528 1946 5959591.1090 Coord...ßystem Name ~ Alianment ÃK="4 on NORTH AMERICAN DATUM 1927 datu True Field Name: Kuparuk River Unit .--~----,,------. Eastinq ! _ 487754g208 - - ~ Northina Coord Svstem Name North AJianment I 5948985_820~~AK-4 on NORTH AMERICAN DATUM 1927 datu True -~-~- -~ -- 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 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ~illips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 2 Well bore: 112 Well path: 112 Ver#3 Date Printed: 19-May-2004 ... ~~ INTEQ 0.00 0.00 0.00 0.00 -95.00 O.OON O.OOE 5959781.00 550301.00 0.00 0.00 Tie on 100.00 0.00 0.00 100.00 5.00 O.OON O.OOE _5959781.00 55030100 0.00 0.00 120.00 0.00 0.00 120.00 2500 O.OON O.OOE 5959781.00 550301.00 0.00 000 20.000in Conductor 200.00 0.00 0.00 200.00 105.00 O.OON O.OOE 5959781.00 550301.00 0.00 0.00 300.00 0.00 0.00 300.00 205.00 QQ1JN O.OOE 5959781.00~ _~~º-:iQ~.00 0.00 400.00 0.00 0.00 400.0~0 305.00 _n_ O.O~~ O.OOE 5959781~_55º-:iQ.Lºº--0.00 _-ºÆ!___ 500.00 0.00 0.00 500.00 405.00 O.OON O.OOE ~597-ª-~550301.00 0.00 0.00 KOP. End of Hold 600.00 3.00 95.00 599.95 504.95 0.23S 261E 5959780.79 550303.61 3.00 -0.06 700.00 6.00 ~_95.00 699.63 604.63 0.Jl1 8 10.42E 59..597-ªü..1L 550311.4l...-3.00__ -0.26 800.00 9.0.0 95.00 --.798.77 703.77 .. 2.058 23.42E 5959779.11 550324.43 3.00 -0.58 833.33 10.00 95.00 831.64 736.64 2.53S 28.91 E 5959778.66 550329.92 3.00 -0.71 Bid 4/100. End of BuildfTurn 933.33 14.00 95.00 929.44 83444 4.348 49.61E 5959776.99 550350.64 4.00 -1.23 1033.33 18.00 95.00 1025.55 930.55 6.748 77.07E 5959774.77 550378.10 4.00 -1.91 1083.33 20iJO 95.00 1072.82 977.82 .. ..8.168 93.28E 5959773.46 550394.32 4.00 -2.31 Bid 5/100. End of Build 1112.40 21.45 95.00 1100.00 1005.00 9.068 103.53E 5959772.64 550404.58 5.00 -2.56 Bid 3/100. End of Build 1212.40 24.45 95.00 1192.07 1097.07 12.468 142.37E 5959769.50 550443.44 3.00 -3.52 1312.40 27.45 95.00 1281.98 1186.98 .16.278 185.97E 5959765.98 550487.05 3.00 -4.60 1332.76 28.06 95.00 1300.00 1205.00 17.108 195.41E 5959765.21 550496.51 3.00 -4.83 Bid 5/100. End of Build _1432.76 33.06 95.00 1386.08 1291.08 2.L5~38 246.06E . 5959761.12 550547 .J.L..J1.00 -6.09 1532.76 38.06 95.00 1467. 40 1372.40 26.598 303.981;: 5959756.44 550605.12 5.00 -7.52 1582.66 40.5Ç. 95.00 .1906.00 1411.00 .. 29.358 335.46E 5959753.90 550636.62 5.00 -8.30 Base Permafrost 1632.76 43.06 95.00 1543.34 144~34 32.268 368.74E 5959751.2L 550669.91 200_____.:U2......... 1732.76 48.06 95.00 1613.33 1518.33 38.48S 439.85E 5959745.47 550741.05 5.00 -10.88 1832.76 53.06 95.00 1676.83 158.L83 45.218 516.76E 5959739.25 550818.00 2....ºº-------.:.12~ _1926.43 57.75 ...95.00 1730.00 1635.00 .51.938 593.56E 5959733.05 550894.83 5.00 -14.68 Top T-3 1932.76 58.06 95.00 1733.36 1638.36 52.408 598.90E 5959732.62 550900.18 5.00 -14.81 ~-~ _2030.08 62.93 95.00 1781.27 1686.27 5.9.788 683.25E 5959725.80 550984.57 5.00 -16.90 EOC. End of Build 2100.00 6293 95.00 1813.09 1718.09 65.208 745.27E 5959720.79 551046.62 0.00 -18.43 2200.00 62.93 95.00 1858.60 176~QO~ 72.968 833.98E 5959713.63 551135.37 0.00 -20.63 2300.00 62.93 9500 1904.11 1809.11 80.728 922.68E 5959706.46 551224.11 0.00 -22.82 2400.00 62.93 95.00 1949.§2 1854.62 88.488 1011.39E 5959699.30 _~51312.8~ -25.02 2500.00 62.93 95.00 1995.13 1900.12 96.258 1100.10E 5959692.13 551401.61 0.00 -27.21 2600.00 62.93 95.00 2040.63 1945.63 104.018 1188.80E 595968496 551490.36 0.00 -29.41 2605.20 62.93 95.00 2043.00 1948.00 . .104.418 1193.42.E 5959684.59 551494.97 0.00 -29.52 Top K-15 2608.85 62.93 95.00 2044.66 1949.66 104.698 1196.66E 5959684.33 551498.21 0.00 -29.60 Trn 4/100. 30X8 Kick off Point --2700.00 62.86 99.10 2086.20 1991.21 1.14.658..J277.16E 595~9.z<l.92 ~157fU7 4.00 -28.70 2800.00 62.92.. 103.59 2131.80 2036.80 . J32.158 1364.40E 5959658.00 551666.12 4.00 -21.05 ------ 2810.00 62.93 104.04 2136.35 2041.35.. 134.278 1373~.04E 5959655.94 551674.77 4.00 -19.9LEOC. End otTurn ....2900.00 62.93 104.04 2177.30 2082.31 153.718 1450.79E 5959637.02 551752.64 0.00 -9.27 3000.00 62.93 104.04 2222.81 2127.81 175.318 1537.18E 5959616.00 55183917 000 2.54 3100.00 62.93 104.04 2268.32_ 2173.32 196.918 1623.57E 5959594.98----.9_51925.69 0.00 14.36 3169.62 62.93 104.04 2300.00 2205.00 211.948 1683.70E 5959580.35 551985.92 0.00 22.59 133/8" CasinQ pt. 3200.00 62.93 104.04 2313.83 2218.83 218.518 1709.95E 5959573.97 552012.21 0.00 26.18 ~300.00 62.93 104.04 2359.33 2264.33 240.108 179634E _5959552.95 552098.73 0.00 37.99 .-ª-400.00 62.93 104.04 2404M...._2.309.84 261.7.QS... 1882.72E 5Jt59531.93__.552185.25 0.00 49.81 3500.00 62.~_ 104.04 2450.35 2355.35 .283.308 196911E 5959510.91 552271.77 0.00 61.63 3600.00 62.93 104.04 2495.85 2400.85 304.908 2055.50E 5959489.89 552358.29 0.00 73.44 3700J!O 62.93 104.04 2541.36 2446.3.9 ... 326.508 214H!.SE 595946888 552444.81 0.00 85..2§.._ --- 3800.00 62.93 104.04 25812.87 2491.87 348.108 2228.27E 5959447.86 552531.33 0.00 97.07 All data is in Feet unless otherwise stated Coordinates are from 810t MO's are from Rig and TVO's are from Rig ( Ooyon #141 RKB 95.00 above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINl\L . . Conocdíhillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 3 Wellbore: 112 Wellpath: 112 Ver#3 Date Printed: 19-May-2004 ... WII.J INTEQ 39.0.0..0.0 62.93 1.04..04 2632.38 2537.38 369.7.08 2314.66E 5959426.84 552617.85 .0..0.0 1.08.89 3973.89 62.93 1.04..04 2666..0.0 2571.0.0 385.668 2378.49E 5959411.31 552681.78 .oDD 117.62 Top l,)qnu C 4.0.0.0..0.0 62.93 1.04..04 2677. 88 2582.88 391.3.08 24D1.D4E 59594.05.82 5527.04.37 .0..0.0 12.0.71 4.064.37 62.93 1.04..04 27.07. 18 2612.17 4.05.2.08 2456.65E 5959392.29 55276.0..06 .0..0.0 128.31 BldlTrn 511.0.0, End of Hold -.A1QD. .0.0 62.63 1..06..01 2723.47 2628.47 413.41S 248725E 5959384.29 ._ 55279.0.71 ..J1JJD 133 Dº--------- 42.0.0. .0.0 61.93 111.6~77D.02 2675..02 . 441J128 2571.DDE 5959356.34 552874.65 5..0.0 152.04 --ÆDD.DD 61.47 117.26 2817.45 2722..45 ..A78.31S 265t..12E 5959.32.0..49 552955.0.0 5..0.0 -----.1I9~ 44.0.0. .0.0 61.24 122.95 2865.43 277.0.43 522.3.08 2727. .oDE 5959277..01 553.031.16 5..0.0 214.49 45.0.0..00 61.25_128.66 2913~2818..Q7 (573.56S 2798.D5E 5959226.24 5531.02.55 5..0.0 257.49 .---- 46.00. .0.0 61.49 134.35 2961.51 2866.51 . B31.698 2863.75E 5959168.56 553168.63 5..0.0 3.07.92 47.0.0..0.0 61.98 14.0..0.0 3.0.08.9.0 2913.9.0 696.25S 2923.58E 59591.04.4.0 553228.88 5..0.0 365.4.0 4788.34 62.59 144.94 3.050..0.0 2955,QD -. 758.258 297Uß~ 59~D42 7~ 553276.9.0 5..0.0 421.69 Top Uqnu B 48.0.0..0.0 62.69 145.59 3.055.36 --.2.00..0.36 766.76S 2977.D9E 5959.034.26 553282.86 5~~29.49 4869.67 6;3.31 149.43 3.087..0.0 2992.JJ0 ª19.11~D1D.43E 595898£14 553316.;;~DD 477.79 Top Uqnu A ~"~- 49.0.0..0.0 63.62 151..09 31.0.0.55 3.0.05.55 842.678 3D23.88E 5958958.67 55333.0.16 5..0.0 499.7.0 5.0.0.0. .0.0 64.76 156.5.0 3144.11 3.049.11 923.418 3D63.59E 5958878.21 55337.0.4.0 5..0.0 575.5.0 _510.0..0.0 6609 161.8.0 3185Z3_3D9DZ3 10.08.368 3D95J12E 5958793.49 5534.P3 3D 5..0.0 656~_ 52.0.0. .0.0 67.6.0 166.99 3225. .08 313.0..08 1DOO.88S 312D.62E 59587.05.14 553428.58 5..0.0 741.51 5231.62 68.11 168.6.0 3237..0.0 _ 314200 JJ25.5DS 3126.81E - 5958676.57 _553434.97 5..0.0 769.27 K-13 53.0.0. .0.0 69.27 172..06 326186 ~1668º .111!8.298 3137.-º.DE 59581113.86 553446.º-8 5..0.0 83.0.47 54.0.0..0.0 ....l1Jlli...--.iZLQ.1 3295.79 32.0.0.79 .. 1281.898 3146.44E 595852.0.32 553455. 6~ºº------ß22.49_~ 55.0.0. .0.0 73..03 181.85 3326.62 3231.62 1376.99S 3147.37E 5958425.25~3457.2L 5..0.0 1.016.88 5596.17 75.0.0 186.41 335312 3258.12 1469.168 314D.69E 5958333..04 55345114 5..0.0 11.09.23 EOC, End of BuildfTurn 56.0.0. .0.0 75..0.0 186.41 3354.11 3259.11 .. 1472.84S 314D.28_E 5958329.36 55345.0.75 .0..0.0 1112.93 5696 16 75..0.0 186.41 3379..0.0 3284..0.0 1565.148 3129.9DE 5958237..0.0 553441..0.0 .0..0.0 12.05.81 Top West Sak 0, WS 1 E 04 0 TOP _~ RV80D421 .04, End of Hold 57.0.0..0.0 75..0.0 186.41 337999 3284.99 1568.83S 3129.49E 5958233.31 55344.0.61 .0..0.0 12.09.52 58.0.0. .0.0 75..0.0 186.41 34.05.88 331.0.88 1664.828 3118.7DE 5958137.26 55343.0.47 .oDD 13.06.11 58.08.15 75,ºº---....J 86.41 34.07.99 3312.99 ..19.72.648 3117.82E 5958129.44 553429.64 .0..0.0 131399 Bid 3/1.0.0, End..Qfliold 5856.9.0 76.46 186.41 3420. .0.0 3325..0.0 1719.59S 3112.55E 5958.082.45 553424.68 3..0.0 1361.23C 59.08.15 78..0.0 186.4L...M;3132__ 3336.~2 1769.268 31D6.97E 5958.032.76 553419.43 3..0.0_ 1411.21 -- 5974.6.0 8.0..0.0 186.41 3444..0.0 3349.Q0 1834.D7S 3D99,68E 5957967.9.0 5534125-ª--3JJD 1476.44 EOC, End of Build 5986.12 8.0..0.0 186.41 3446..0.0 3351..0.0 1845.358 3D91L41 E 5957956.62 553411.;39 .0..0.0 Î-487.78 Top West 8akB 6.0.0.0. DO 80..0.0 186.41 3448.41 3353.41 lB58.93S 3D96.89E 5957943..02 5534.09.95. .0..0.0. 15.01.45 61.0.0..0.0 8.0..0.0 186.41 3465.78 337.0.78 1956.8.08 3D85.89E 5957845.1.0 553399.61 .0..0.0 1599.93 62.0.0. .0.0 8.0..0.0 186.41 3483.14 338.!U4 . 2054.66S 3D74.89~ 5957747.17 553389.27 _ .0..0.0 1698.41 6227.99 8.0..0.0 186.41 3488..0.0 3393.00 ._.20112..058 _3D7Jß1 E 5957719.76 55338638 .0..0.0 1I25.97 A·4 -~_._~ 63.0.0. .0.0 8.0.0.0 186.41 35.0.0.51 34D5,º1 .... 2152.53S 3D63.89E 5957649.24 5533711.93 .0..0.0 179689 ~-~-- 64.0.0. .0.0 8.0. DO-----.1lli?~517. 87 3422.87 225.0.398 3D52.9DE 5957551.32 553368.59 .0.00 1895.38 ~~-~~- 65.0.0. .0.0 8.0.0.0 186.41 3535.24 344.0.23 2348.268 3D41.9DE 5957453.39 553358.25 .0..0.0 1993.86 ~21.68 8.0..0.0 186.41 3539..0.0 3444..0.0 2.369.48.s.. 3.039. Q1£.. 5957432.16 553356..0.0 .0..0.0 2.015.21 A-3 66.0.0. .0.0 8.0.0.0 186.41 3552.6.0 3457.6.0 2446.12S 3D3D.9DE 5957355.46 553347.9.0 .0..0.0 2.092.34 67.0.0..0.0 8.0..0.0 186.41 3569.96 347496 2543.998 3D19.9DE 5957257.54 553337.56 .0..0.0 219.0.82 68.0.0..0.0 8.0..0.0 186.41 3587.33 3492.33 2941.858 3DD8.9DE 5957159.61 55332722 .oDD 2289.3.0 69.0.0..0.0 8.0..0.0 186.41 36.04.69 35.09.69 .2739.728 2997.91 E 5957.061.69 553316.88 _.0..0.0 2387.78 6913.28 8.0..0.0 186.41 36.07..0.0 3512..0.0 2152.718 2996.45E 5957.048.68 55331551 .0..0.0 24.0.0.86 A-2 19 5/8" Casinq Pt. 6924..04 8.0..0.0 186.41 36.08.87 351387 2763.248 2995.26E 5957.038.14 553314.39 .0..0.0 2411.45 Bid 4/1.0.0, End of Hold 7.0.0.0. .0.0 83..0-1 186.41 362.0..07 3525.07 2837.898 2986.87E 5956963.45 5533.06.51 4DQ__21.86.57 ~--- 71.0.0..00 87..04 186.41 362872.. 3533.72 ..2936.878 2975.75.£ 5956864.4.0 553296..05 4..0.0 2586JJ!__ All data is in Feet unless otherwise stated Coordinates are from 810t MO's are from Rig and TVO's are from Rig ( Doyon #141 RKB 95.Dft above mean sea level) Vertical 8ection is from D.DDN D.DDE on azimuth 186.41 degrees Bottom hole distance is 733.0.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGr~tAL e . Cor1ocÒPhillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 Wellbore: 112 Wellpath: 112 Ver#3 Date Printed: 19-May-2004 8.. ~7f= INTEQ 7200.00 91.04 186.41 3630.40 3535.39 3036.22S 2964.59E 5956765.00 553285.55 4.00 2686.15 7202.69 91.15 186.41 3630.34 3535.34 3Q38.898 2964.29E 5956762..32 553285.27 4.00 2688.84 EOC. End of BuildfTurn 7302.69 93.65 186.41 3626.16 3531.16 3138.178 2953.13E 5956662.98 553274.78 2.50 2788.74 7335.21 94.46 186.41 3623.86 3528.86 3170.408 2949.51E 5956630.73 553271.37 2.50 2821.18 End of Build ~OO.OO 94.46 186.41 3618.83 3523.83 .3234.598 2942.30L5956566.49 55326459 0.00 2885.77 7500.00 94.46 18Q,41_q,611.05~ 3516.05 .3333678 2931"j§E 5956467.36 553254 12 0.00 2985.47 --- -- 7600.00 94.46 186.41 3603.28 3508.28 . 3432.7 4S 2920 03E 5956368.22 _ 553243.66 0.00 3085.17 7700.00 94.46 186.41 3595.50 3500.50 3531.818 2908.90E 5956269.09 553233.19 0.00 3184.86 7721.68 94.46 18§.41 3593~~98.82 --. 3553308 2906.491;: 5956247.59 5532309~00 3206.48_End of Hold 7821.68 91.96 186.41 3588.22 3493.22 . 3952.!2.lli. 2895.34E 5956148.32 553220.44 2.50 .- 3306.31 7854.20 91.15 186.41 3587.34 3492.34 3684.818 289171E 5956115.99 553217.02 2.50 3338.82 End of Drop 7954.20 88.65 18~587.52. 3492.52 3784.188 2880.54E 5956016.56 553206.52 2.50 3438.81 7988.04 ----ª7Jill... 186Al 3588.57 3493.57 3..B17.798 2876.77E 5955982.93 553202.97 _ 2.50 3472.64 End of DroQ...._ 8000.00 87. 80 186.41 3589.03 __ 3494.03 3$29.668 2875.4,3E 5955971.05 553201.72 0.00 ...M845!L...._ 8100.00 87.80 186.41 3592.87 3497.87 3928.978 2864.28E 5955871.68 553191.23 0.00 3584.51 8200.00 87.80 186.41 3596.71 3501.71 4028.278 2853.12E 5955772.32 553180.73 0.00 3684.44 8300.00 87.80 186.41 3600.55 3505.55 4J27.578 2841.96E 5955672.96 553170.24 0.00 ....3784.37 8366.76 87.80 186.41 3603.11 3508.11 4193.868 2834.51 E 5955606.62 553163.24 0.00 3851.08 End of Hold - 8466.76 90~º----1.§.~3604. 77 3509.7í' .0'1293.228 2ßZ3 35E 59QQ507.20 553152.74 2.50 395106 --- 8500.60 91.15 186.41 3604.3~9.c34 432.9.848 2819.57E 5955473.56 553149.19 2.50 3984.90 End of Build 8600.60 93.65 186.41 3600.1º---~505.19 .4,426.128 2808.41 E 5955374.21 553138.70 2.50 4084.80 _8638.76 94.60 186.41 3597.42 3502.42 .4463.95S 2804..1QE 5955336.37 _553J34.N.. 2.50 4122.86 End of Build 8700.00 94.60 186.41 3592.51 3497.50 4524.608 2797.35E 5955275.67 553128.29 0.00 4183.90 _8800.00 94.60 186.41 3584.49 ~...3..489 .49 49.23.668 2786.22E 5955176.;;5 553117.83 0.00 4283.58 ~ 8900.00 94.60 186.41 3576.47 348HZ ..4722.718 2775.09E 5955077.44 553107.~_0.00 4383.26 9000.00 94.60 186.41 3568.45 3473.4:; 4$21.778 2763.96E 5954978.32 553096.90 0.00 4482.93 . 9023.04 94.60 186.41 3566.60 3471.60 4$44.598 2761.39E 5954955.48 553094.49 0.00 4505.90 End of Hold -~~- 9100.00 92.67 186.35 3561.72 3466.72 4920.92S 2752.86E 5954879.11 553086.46 2.50 4582.70 ..Jli53.22 91.34 186.32 3559.85 3464.&5 .4W3.788 2746.99E 5954826.22 ~3080c95 2.5º---A.635.89 End 91 DropfTurn _ 9253.22 88.84 186.32 3559.69 3464.69 5073.168 273599E 5954726.77 553070.61 2.50 4735.88 9285.54 88.04 186.32 3560.57 3465.57 _ Q195.27S 2732.43E 5954694.64 553067.28 2.50 4768.19 End of DrQJL 9300.00 ~º-4 186.32 3.961.06 3466.06.. .5119.648 2730.85E 5954680.26 553065.78 0.00 4782.64 9400.00 88.04 186.32 3564.49 3469A!:L 5218.978 2719.85E 5954580.87 553055.46 0.00 4882.58 -- 9500.00 88.04 186.32 3567. 92 3472.92 ..5.318.31S 2708.86E 5954481.47 55~045.13 0ºº---4982.52 9600.00 88.04 186.32 3571.35 3476.35 5417.64S 2697.87E 5954382.08 553034.80 0.00 5082.46 ~7 4.11 88.04 186.32 3573.89 ...M78.8g ..Q4.91.268 _2689.72E 5954308.41 553027.15 0.00 5156.53 End of Hold 9774.11 90.54 186.32 3575.14 3480.14. _5.590.648 2678.72E 5954208.97. 553016.82 2.50 5256..51 9806.43 91.34 186.32 3574.61 3479.61 5622.76S 2675.17E 5954176J~~ 553013.48 2.50 5288.83 End_of Build _9906.43 93.84 Jl!§~---3§70.09 3475.09 5722.048 2664.18E 59~077.49 553003.16 2.50 5388.72 9938.71 94.65 186.32 3567.70 3472.70 5754.048 2660.64E 5954045.47 552999.83 2.50 5420.91 End of Build 10000.00 94.65 186.32 3562.73 346773 Qß1475S 2653.92.L5953984.72 552993.52 OQº--_Q482.00 10100.00 94.65 186.32 3554.62 3459.62 5913.828 2642.96E 5953885.59 552983.22 0.00 5581.67 10200.00 94.65 186.32 3546.51 3451.51 6012.898 2631.99E 5953786.46 552972.92 0.00 5681.34 10300.00 94.65 186.32 3538.41 3443.4J 6111.95S 2621.03E 5953687.34 552962.62 0.00 5781.01 10326.06 94.65 186.32 3536.29 3441 .29 9J37.77S 2618.17E 5953661.50 552959.94 0.00 5806.99 End of Hold .J.Q426.06 92.15 186~530.36 3435.36 6236.988 2607.19E 595356223 552949.63 2.50 5906.80 10458.34 91.34 186.32 352938 3434.38 6269.05S 2603.65E 5953530.14 552946.29 2.50 593907 End of Drop 10558.34 88.84 186.32_3529.22 3434.2.2 .6368.448 2592.65E 5953430.69 552935.96 2.50 6039.06 .J.Q583.22 88.22 186.32 352986 3434.86 ...6393.168 2589.91 E 5953405.,,$6 552933.39 2.50 6063.93 8/C Kick off Point ______ 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 95.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . c:onocòPh¡ll¡ps ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 5 Wellbore: 112 Well path: 112 Ver#3 Date Printed: 19-May-2004 ... udt ..:u..;. INTEQ 10600.00 88.22 186.32 3530.38 3435.38 6409.828 2588.07E 5953389.28 552931.66 0.00 6080.70 10700.00 88.22 186.32 3533.48 3438.48 6509.178 2577.07E _5953289.87 5529~33 0.00 6180.65 10800.00 88.22 186.32 3536.59 3441.58 6608.518 2566.08E 5953190.47 552911.00 0.00 6280.60 10900.00 88.22 186.32 3539.69 3444.69 6707.868 2555.08E 5953091.06 552900.67 0.00 6380.55 11000.00 88.22 186.32 3942.79 3447.79 6807.20S 2544.09E 5952991.65 552890.34 0.00 6480.51 11071.07 88.22 186.32 3545.00 3450.00 6877.818 2536.27E 595292100 552883.00 0.00 6551.55 TD - Casing Pt., W8 1E D4 Þ:2. TOE RV8D042104, 5 1/2in Uner, End otTurn 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 95.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . -...,/ . ConocòPhillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 6 Wellbore: 112 Well path: 112 Ver#3 Date Printed: 19-May-2004 ... ..,. INTEQ 500.00 500.00 833.33 831.64 ~-~--~~ 1083.33 1072.82 1112.40 1100.00 103.53E 9.068 Bid 3/100 1332.76 1300.00 195.41 E 11108 Bid 5/100 1582.66 1506.00 335.46E 29.35S Base Permafrost 1926.43 1730.00 593.56E 51.938 Top T-3 2030.08 1781.27 68325E 59.788 EOC -~ --~-- 2605.20 2043.00 1193.4~ JQ4.418 Top K-15 .~-~-."~ ~8.85 _ 2044.66 -.1196.66E 104.698 Trn 4/100 -- 2810.00 2136.35 1373.04E 134.278 EOC _ 3169.62 2300.00 1683.70E 2Jl~~~ 3/8" Casino pt. -~ 3973.89 2666.00 _---------.n78.49E _385.668 Top Uonu ç -- 4064.37 2707.18 2456.65E 405.208 BldlTrn 5/100 4788.34 3050.00 2971.19E 758.258 Top Uo n u_-ª----------_ 4869.67 3_087. 00 3010.4~ ..8J9.118 Top Uonu A 5231.62 3237.0Q 312681E . ..JJ25.508 K-13 --- -~ 5596.17 3353.12 3140.69E 1469.168 EOC 5696.16 ~.OO 3129.90E 1565.148 1'0J)-MW-Sâtc D 5808.15 3407.99 3117.82E 1$72.648 Bid 3/100_ 5856.90 3420.00 3112.55E 1719.59S C 5974.60 3444.00 309968E .. 1834.078 E.oC ~6~ 3446.00 3098.41 E J.845.358 Top West 8~__~ --~ 6227.99 3488.00 3071.81E 208205S A-4 6521.68 ~539.00 3039.51E .2369.488 A-3 --~~- ~--~ 6913.28 3607.00 2996.45E 2752.718 A-2/9 518" Casino pt. 6924.04 3608.87 2995.26E 2793248 Bid 4/100 -- 7202.69 _~.34 296429E 3Q3ß898 __ EOC __ n~_ 11071.07 3545.00 2536.27E 9877.818 . TD - Casino pt. -- __42.000 n 0.00 000 _ DOON__ O.OOE 12000 120.00 16.000 0.00 0.00 O.OON O.OOE 3169.62 2300.00 121/4 2949.87 2200.00 164.488 1493.ß7E n_6913.2ª--~7.00 81/2 6913.28 3607.00 2752.718 2996.45E 1:1071.07 3545.00 O.OON O.OOE 211.948 1683.70E 2752.71L_ 2996.45E 6877.818 _~~6.27E 112 112 112__ 112 20.000in 0.00 0.00 O.OON O.OOE 120.00 120.00 O.OON O.OOE 112 Conductor ._----~~ 13 3/8in 8urface 000 0.00 O.OON O.OOE 3169.62 2300.00 211.948 1683.70E 112 casino ~_. -- 9 518i n 0.00 0.00 O.OON O.OOE 6913.28 3607.00 2752.71S 2996.45E 112 Intermediate casino -~--- --~. ~--~- ~- 5 112in Liner 5696.16 3379.00 1565.148 3129.90E 11045.90 3310.00 6877.818 2536.27E 112L2 All data is in Feet unless otherwise stated Coordinates are from 810t MO's are from Rig and TVD's are from Rig ( Doyon #141 RKB 95.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . Con()(.~tillips ConoeoPhillips Alaska, Ine.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 7 WeJlbore: 112 WeJlpath: 112 Ver#3 Date Printed: 19-May-2004 ... ..,. INTEQ 5986.11 6913.28 344600~ 184534S~8.42E 11051.76 3607.00 __ 2Z52~ 2996.45E_~1107j.07 3370.00 3545.00 6877.81S 6877.81S 2536.27E 112L 1 . 2536.27E 112 -~~ 5 112in Liner 5 112in Liner WS 1E 04 A2 TOE 6877.81S RVS0042104 WS 1E D4 0 TOP 1565.14S 2536.27E 3545.00 N70 16 55.5517 W149 34 19.4806 552883.00 5952921.00 3129.90E 3379.00 N70 17 47.7993 W149 34 21252 553441.00 5958237.00 660118 Planned All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Doyon #141 RKB 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL · Baker Hughes IncorpOIted Anticollision Report NO GLOBAL SCAN: Using user defined setection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 5986.11 to 11051.74 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive WeIlpath Date: 1/12/2004 Validated: No Planned From To Survey ft ft 0.00 5986.11 Planned: 1E-112 VerS#3 V17 (0) 5986.11 11051.74 Planned: 1E-112L1 Vers#3V7 Version: 0 Toolcode Tool Name MWD+SAG MWD+SAG MWD + Sag correction MWD + Sag correction Summary 112,1E-112L1,1E-112L1 11051.74 11051.74 0.00 304.15 -304.15 FAIL: Major Risk Pad 10 113 10-113 V1 Out of range Pad 10 114 10-114 VO Out of range Pad 1D 116 10-116 V1 Out of range Pad 10 122 10-122 VO Out of range Pad 10 124 1D-124 VO Out of range Pad 10 125 10-125 V1 Out of range Pad 10 126 10-126 VO 6440.84 6700.00 3071.64 211.67 2859.98 Pass: Major Risk Pad 10 127 10-127 VO 8264.13 7416.00 3063.00 323.31 2739.69 Pass: Major Risk Pad 1D 128 1D-128 VO 7080.98 6564.00 4014.17 244.19 3769.98 Pass: Major Risk Pad 10 129 10-129 VO 6405.36 5000.00 5179.72 199.77 4979.95 Pass: Major Risk Pad 10 131 10-131 VO 7790.40 6325.00 4984.41 283.07 4701.35 Pass: Major Risk Pad 10 3 1 D-03 VO Out of range Pad 10 7 1 D-07 VO 7675.81 7775.00 5047.54 329.55 4717.99 Pass: Major Risk Pad 1E 10 1E-10 VO Out of range Pad 1E 102 102 B-Lateral VO Plan: Out of range Pad 1 E 102 102 D-Lateral VO Plan: Out of range Pad 1E 103 103 VO Plan: 1E-103 VE Out of range Pad 1E 104 104 VO Plan: 1E-104 VE Out of range Pad 1E 105 105 A2-Lateral VO Plan 5992.11 8850.00 2132.16 187.21 1944.95 Pass: Major Risk Pad 1E 105 105 B-Lateral VO Plan: 5998.68 8875.00 2122.37 177.45 1944.92 Pass: Major Risk Pad 1E 105 105 D-Lateral VO Plan: 5994.06 8875.00 2121.30 178.67 1942.62 Pass: Major Risk Pad 1E 11 1E-11 VO Out of range Pad 1E 112 1E-112 VO Plan: 1 E-112 5999.99 6000.00 0.23 100.26 -100.03 FAIL: Major Risk Pad 1E 112 1E-112L2 VO Plan: 1E-1 6000.05 6000.00 38.18 99.32 -61.14 FAIL: Major Risk Pad 1E 114 114 A2-Lateral VO Plan Out of range Pad 1E 114 114 B-Lateral VO Plan: Out of range Pad 1E 114 114 D-Lateral VO Plan: Out of range Pad 1E 117 117 A2-Lateral VO Plan 11029.82 7850.00 1283.57 505.00 778.57 Pass: Major Risk Pad 1 E 117 117 B-Lateral VO Plan: 11029.82 7850.00 1283.57 504.99 778.58 Pass: Major Risk Pad 1 E 117 117 D-Lateral VO Plan: 11029.82 7850.00 1283.57 504.99 778.58 Pass: Major Risk Pad 1 E 119 119VOPlan: 1E-119Ve 10216.16 7242.30 2017.05 451.57 1565.47 Pass: Major Risk Pad 1E 1 1 E-01 VO 6167.41 4425.00 3427.74 182.47 3245.26 Pass: Major Risk Pad 1E 1 1E-01A VO 6167.41 4550.00 3250.37 137.61 3112.76 Pass: Major Risk Pad 1 E 121 121 B-Lateral VO Plan: Out of range Pad 1 E 121 121 D-Lateral VO Plan: Out of range Pad 1 E 12 1E-12 VO Out of range Pad 1E 123 1E-123 L1 V1 Plan: 1E- Out of range Pad 1 E 123 1E-123 V8 Out of range Pad 1 E 126 126 A2-Lateral VO Plan 10805.50 12054.87 1077.27 523.21 554.06 Pass: Major Risk Pad 1 E 126 126 B-Lateral VO Plan: 10803.71 12066.71 1105.88 508.09 597.80 Pass: Major Risk Pad 1 E 126 126 D-Lateral VO Plan: 10804.87 12062.49 1104.94 509.97 594.97 Pass: Major Risk Pad 1 E 13 1E-13 VO Out of range Pad 1 E 14 1E-14 VO Out of range Pad 1 E 15 1E-15 VO Out of range Pad 1 E 16 1E-16 VO Out of range Pad 1 E 166 166 A2-Lateral VO Plan 11044.45 8925.00 971.25 508.77 462.48 Pass: Major Risk Pad 1 E 166 166 B-Lateral VO Plan: 11040.29 8900.00 954.72 492.05 462.68 Pass: Major Risk Pad 1 E 166 166 D-Lateral VO Plan: 11047.78 8900.00 957.15 491.51 465.64 Pass: Major Risk Pad 1 E 168 168 A2-Lateral V3 Plan 6289.92 5775.00 558.77 142.65 416.12 Pass: Major Risk ORIGINAL · Baker Hughes Incorpo.ed Anticollision Report Summary Pad 1E 168 168 B-Lateral VO Plan: 6289.92 5775.00 558.77 142.65 416.12 Pass: Major Risk Pad 1E 168 168 D-Lateral VO Plan: 6289.92 5775.00 558.77 142.65 416.12 Pass: Major Risk Pad 1 E 170 170 A2-Lateral VO Plan 11035.28 7325.00 2305.08 502.40 1802.67 Pass: Major Risk Pad 1 E 170 170 B-Lateral VO Plan: 11035.28 7325.00 2305.08 502.39 1802.69 Pass: Major Risk Pad 1 E 170 170 D-Lateral VO Plan: 11035.28 7325.00 2305.08 502.39 1802.69 Pass: Major Risk Pad 1 E 17 1E-17 VO Out of range Pad 1 E 18 1E-18 VO Out of range Pad 1 E 19 1E-19 VO Out of range Pad 1E 20 1 E-20 VO Out of range Pad 1E 21 1 E-21 VO Out of range Pad 1E 2 1 E-02 VO 6959.31 5850.00 1956.90 172.98 1783.92 Pass: Major Risk Pad 1 E 22 1E-22 VO 6134.51 5400.00 447.54 121.49 326.05 Pass: Major Risk Pad 1 E 23 1E-23 VO 6200.00 5350.00 1240.18 135.24 1104.94 Pass: Major Risk Pad 1 E 24 1E-24 VO 5986.11 5800.00 2903.95 99.27 2804.68 Pass: Major Risk Pad 1 E 24 1 E-24A VO 6002.61 6875.00 2701.04 86.31 2614.73 Pass: Major Risk Pad 1E 25 1 E-25 VO Out of range Pad 1 E 26 1 E-26 VO 6009.44 3400.00 3566.96 146.26 3420.69 Pass: Major Risk Pad 1E 26 1 E-26A VO 6006.50 3500.00 3619.70 134.32 3485.37 Pass: Major Risk Pad 1E 27 1 E-27 VO Out of range Pad 1E 28 1 E-28 VO 6003.48 3675.00 4433.76 129.56 4304.20 Pass: Major Risk Pad 1E 29 1 E-29 VO 5986.11 4825.00 4280.13 116.59 4163.54 Pass: Major Risk Pad 1 E 30 1 E-30 VO 5986.11 4850.00 4930.46 122.90 4807.56 Pass: Major Risk Pad 1 E 31 1 E-31 V1 9522.41 10005.00 3335.94 264.86 3071.08 Pass: Major Risk Pad 1 E 31 1E-31PB1 VO 9271.41 8800.00 3971.55 317.89 3653.66 Pass: Major Risk Pad 1E 3 1 E-03 V1 Out of range Pad 1E 32 1 E-32 VO 9582.20 7550.00 2651.59 362.84 2288.76 Pass: Major Risk Pad 1E 33 1 E-33 VO 5986.11 8225.00 3073.88 164.88 2909.00 Pass: Major Risk Pad 1E 33 1E-33PB1 VO 5986.11 8225.00 3073.88 164.88 2909.00 Pass: Major Risk Pad 1E 34 1 E-34 VO 8248.42 7350.00 2066.69 274.46 1792.23 Pass: Major Risk Pad 1E 35 1E-35 VO 9630.36 7425.00 1246.50 298.20 948.30 Pass: Major Risk Pad 1E 35 35A VO Plan: 35A ST Ve 9666.56 7475.00 1236.24 289.96 946.28 Pass: Major Risk Pad 1E 36 1E-36 VO 11035.52 10975.00 4407.33 469.49 3937.84 Pass: Major Risk Pad 1 E 4 1 E-Q4 VO 6009.48 3850.00 4427.22 146.25 4280.97 Pass: Major Risk Pad 1 E 5 1 E-05 VO Out of range Pad 1 E 6 1 E-06 VO Out of range Pad 1 E 7 1 E-07 VO Out of range Pad 1E 8 1 E-08 V1 Out of range Pad 1 E 9 1 E-09 VO Out of range Pad 1 E WSR#2 WS2 V1 5986.11 3825.00 1440.55 129.79 1310.76 Pass: Major Risk Pad 1J 10 1J-10 VO Out of range Pad 1J 1J-DQ 1J-L6 A Lateral V1 Pia 8728.34 11640.58 4952.35 436.19 4516.16 Pass: Major Risk Pad 1J 1J-DS 1J-L5 A Lateral V1 Pia 8865.29 12531.63 3717.27 435.81 3281.47 Pass: Major Risk Pad 1J 1J-DU 1J-L4 A Lateral V1 Pia Out of range Pad 1J 1J-DW 1J-L3 A Lateral V1 Pia Out of range Pad 1J 9 1J-09 VO 11033.49 9675.00 4664.32 352.11 4312.21 Pass: Major Risk ORIG\NAL . . ¥ ConocoPhillips ConocoPhilJips Alaska, Inc.,Slot #112 Pad 1E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Wellbore: 112L1 Wellpath: 112L1 Ver#3 Date Printed: 19-May-2004 _i. BAKER HUGHES INTEQ Wellbore Name 112L 1 I Created 26-Apr-2004 I Last Revised 6-May-2004 Well Name 112 I Govemment ID Last Revised 2-Feb-2004 Slot Name Slot #112 I Grid NorthinQ 5959781.0000 EastinQ .0000 I Latitude N70 18 3.1987 W149 35.33.3560 I North 191.43N lEast 225.93W Installation Name Pad 1E I Eastino 550528.1946 I Northino · 5959591 .1090 I Coord Svstem Name . I North Alionment AK-4 on NORTH AMERICAN DATUM 1927 datum . True Field Name Kuoaruk River Unit I Eastina 487754.6208 Northino 5948985.8206 I Coord Svstem Name I North AlianrneOt AK-4 on NORTH AMERICAN DATUM 1927 datum· . True 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 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGiNAL . . Conoc6'Phillips ConocoPhillips Alaska, Inc., Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 2 Wellbore: 112L 1 Well path : 112L 1 Ver#3 Date Printed: 19-May-2004 .¡. BAKER HUGHES INTEQ We II path Report MD[ft] Inc[de Azi[deg] TVD[ft] Vertical North[ft] East[ft] 8tation 8tation Dogie Vertical 8tation Comment g] Depth 85 Position(Grid Position(Grid g 8ection[ North) East) [deg/1 ft] OOff1 5986.11 80.00 186.41 3446.00 3351.00 1845.348 3098.42E, 5957956.63 553411.39 0.00 1487.77 Top Whipstock Face, Tie on 6002.61 82.24 186.41 3448.55 3353.55 1861.548 3096.59E.. 5957940.42 553409.68 13.60 1504.07 Base Whiostock Face. End of Build 6022.61 82.24 186.41 3451.24 335£.24 1881.238 3094.38F 5957920.71 553407.60 0.00 1523.89,End Milled Ooenhole. KOP. End of Hold 6100.00 86.11 186.41 3459.09 3364.09 1957.738 3085.78E, 5957844.17 553399.51 5.00 1600.87 6167.41 89.48 186.41 3461.68 3366.68 2024.668 3078.26F 5957777.20 553392.44 5.00 1668.24 EOC. 2DX8 Kick off Point 6267.41 92.48 186.41 3459.96 3364.96 2124.018 3067.09F 5957677.78 553381.94 3.00 1768.2QEnd of Build 6300.00 92.48 186.41 3458.55 3363.55 2156.368 3063.45E, 5957645.41 553378.52 0.00 1800.7~ 6330.15 92.48 186.41 3457.24 3362.24 2186.298 3060.09F 5957615.46 553375.35 0.00 1830.87 End of Hold 6430.15 89.48 186.41 3455.53 3360.53 2285.648 3048.92E 5957516.04 553364.85 3.00 1930.8~End of Droo 6500.00 89.48 186.41 3456.16 3361.16 2355.058 3041.12E, 5957446.59 553357.51 0.00 2000.6~ 6600.00 89.48 186.41 3457.06 3362.06 2454.428 3029.94F 5957347.16 553347.00 0.00 2100.6~ 6700.00 89.48 186.41 3457.96 3362.96 2553.798 3018.77E 5957247.73 553336.50 0.00 2200.6~ 6704.75 89.48 186.41 3458.00 3363.00 2558.518 3018.24E 5957243.00 553336.00 0.00 2205.44 W8 1E D4 B-MDPT#1 RV8D042104, 3DJ Kick off Point 6761.91 9120 186.41 3457.66 3362.66 2615.318 3011.86F; 5957186.17 553330.00 3.00 2262.6QEnd of BuildlTurn 6800.00 91.20 186.41 3456.86 3361.86 2653.158 3007.61 E 5957148.30 553326.00 0.00 2300.67 6900.00 91.20 186.41 3454.77 3359.77 2752.518 2996.44E 5957048.89 553315.50 0.00 2400.65 7000.00 91.20 186.41 3452.68 3357.68 2851.868 2985.28E, 5956949.47 553305.01 0.00 2500.6:?¡, 7100.00 91.20 186.41 3450.59 3355.59 2951.215 2974.12E, 5956850.06 553294.51 0.00 2600.61 7200.00 91.20 186.41 3448.49 3353.49 3050.565 2962.95E, 5956750.64 553284.01 0.00 2700.59, 7300.00 91.20 186.41 3446.40 3351.40 3149.928 2951.79E, 5956651.22 553273.52 0.00 2800.57 7400.00 91.20 186.41 3444.31 3349.31 3249.278 2940.63E, 5956551.81 553263.02 0.00 2900.54 7500.00 91.20 186.41 3442.22 3347.22 3348.628 2929.47E 5956452.39 553252.53 0.00 3000.52- 7600.00 91.20 186.41 3440.13 3345.13 3447.988 2918.30E 5956352.98 553242.03 0.00 3100.5Q 7700.00 91.20 186.41 3438.03 3343.03 3547.338 2907.14E 5956253.56 553231.53 0.00 3200.48 7800.00 91.20 186.41 3435.94 3340.94 3646.688 2895.98F 5956154.15 553221.04 0.00 3300.46. 7900.00 91.20 186.41 3433.85 3338.85 3746.038 2884.82F 5956054.73 553210.54 0.00 3400.4~ 8000.00 91.20 186.41 3431.76 3336.76 3845.398 2873.65E 5955955.31 553200.04 0.00 3500.41 8100.00 91 .20 186.41 3429.67 3334.67 3944.748 2862.49E, 5955855.90 553189.55 0.00 3600.3~ 8200.00 91.20 186.41 3427.57 3332.57 4044.098 2851.33E 5955756.48 553179.05 0.00 3700.37 8300.00 91.20 186.41 3425.48 3330.48 4143.458 2840.17E, 5955657.07 553168.56 0.00 3800.35 8400.00 91.20 186.41 3423.39 3328.39 4242.808 2829.00E 5955557.65 553158.06 0.00 3900.32 8500.00 9120 186.41 3421.30 3326.30 4342.158 2817.ß4E. 5955458.24 553147.56 0.00 4000.3Q 8600.00 91.20 186.41 3419.21 3324.21 4441.518 2806.68E, 5955358.82 553137.07 0.00 4100.28 8700.00 91.20 186.41 3417.11 3322.11 4540.868 2795.51 E 5955259.41 553126.57 0.00 4200.26, 8705.44 91.20 186.41 3417.00 3322.00 4546.268 2794.91 E 5955254.00 553126.00 0.00 4205.69W8 1E D4 B-MDPT#2 RV8D042104, 3DJ Kick off Point 8708.62 91.15 186.33 3416.93 3321.93 4549.428 2794.56F 5955250.84 553125.67 3.00 4208.87 End of DroolTurn 8800.00 91.15 186.33 3415.10 3320.10 4640.238 2784.48!;, 5955159.97 553116.20 0.00 4300.24 8900.00 91.15 186.33 3413.10 3318.10 4739.608 2773.46E 5955060.54 553105.85 0.00 4400.22- 9000.00 91.15 186.33 3411.10 3316.10 4838.97S 2762.441'; 5954961.11 553095.49 0.00 4500.2Q 9100.00 91.15 186.33 3409.09 3314.10 4938.348..2751.41F 5954861.68 553085.13 0.00 4600.1€ 9200.00 91.15 186.33 3407.09 3312.09 5037.718 2740.39E, 5954762.25 553074.78 0.00 4700.16 9300.00 91.15 186.33 3405.09 3310.09 5137.088 2729.37E 5954662.81 553064.42 0.00 4800.14 9400.00 91.15 186.33 3403.09 3308.09 5236.458 2718.34E.. 5954563.38 553054.07 0.00 4900.12- 9500.00 91.15 186.33 3401.08 3306.08 5335.828 2707.32E, 5954463.95 553043.71 0.00 5000.1Q 9600.00 91.15 186.33 3399.08 3304.08 5435.198 2696.30E, 5954364.52 553033.35 0.00 5100.0f;. 9700.00 91.15 186.33 3397.08 3302.08 5534.568 2685.28E 5954265.08 553023.00 0.00 5200.0Q 9800.00 91.15 186.33 3395.07 3300.07 5633.938 2674.25E. 5954165.65 553012.64 0.00 5300.04 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 95.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . conoc~illips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit,North Slope, Alaska We II path Report MD[ft) Inc[de Azi[deg). TVD[ft) g] 9900.00 91.15 186.33 3393.07 10000.00 91.15 186.33 3391.07 10100.00 91.15 186.33 3389.06 10200.00 91.15 186.33 3387.06 10300.00 91.15 186.33 3385.06 10400.00 91.15 186.33 3383.05 10500.00 91.15 186.33 3381.05 10600.00 91.15 186.33 3379.05 10700.00 91.15 186.33 3377.05 10800.00 91.15 186.33 3375.04 10900.00 91.15 186.33 3373.04 11000.00 91.15 186.33 3371.04 11051.76 91.15 186.33 3370.00 Vertical Depth 58 3298.07 3296.07 3294.06 3292.06 3290.06 3288.06 3286.05 3284.05 3282.05 3280.04 3278.04 3276.04 3275.00 North[ft] East[ft] 5733.305 2663.23E" 5954066.22 5832.675 2652.21E. 5953966.79 5932.045 2641.18F 5953867.36 6031.415 2630.16E" 5953767.92 6130.785 2619.14E 5953668.49 6230.155 2608.11 E 5953569.06 6329.525 2597.09E" 5953469.63 6428.905 2586.07E 5953370.20 6528.27S 2575.05E 5953270.76 6627.64S 2564.02E" 5953171.33 6727.01 S 2553.00F 5953071.90 6826.38S 2541.98E. 5952972.47 6877.81 S 2536.27E 5952921.00 . PROPOSAL LISTING Page 3 Wellbore: 112L1 Wellpath: 112L1 Ver#3 Date Printed: 19-May-2004 -¡¡. BAKER HUGHES INTEQ 553002.28 552991.93 552981.57 552971.21 552960.86 552950.50 552940.14 552929.79 552919.43 552909.07 552898.72 552888.36 552883.00 5400.02 55oo.0Q 5599.98. 5699.96 5799.94 5899.92.. 5999.90 6099.88. 6199.8& 6299.84 6399.82- 6499.8Q 6551.55 TO 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 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum CUNature method Prepared by Baker Hughes Incorporated Station Station Dogie Vertical Station Comment Position(Grid Position(Gridg Section[ North) East) [deg/1 ft] 00ftJ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O R I ~ ~i 1\ . i 01 ~\LI-\ . . conoc~illips ConocoPhil/ips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 4 Wellbore: 112L1 We/lpath: 112L1 Ver#3 Date Printed: 19-May-2004 Bi. BAKER HUGHES INTEQ Comments MDfftl WDrftl Eastrftl Northfftl Comment 5986.11 3446.00 3098.42E 1845.348 Too Whiostock Face 6002.61 3448.55 3096.59E 1861.548 Base Whipstock Face 6022.61 3451.24 3094.38E 1881.238 End Milled Ooenhole. KOP 6167.41 3461.68 3078.26E 2024.668 EOC 11051.76 3370.00 2536.27E 6877.818 TO Hole Sections Diameter Start 8tart 8tart Start End End End E nd\nEast[ft] Wellbore linl MDfftJ TVDfftJ NorthfftJ ..EasHftJ MorftJ worftJ NorthrttJ 16.000 0.00 0.00 O.OON O.OOE 3169.62 2300.00 211.94S 1683.70E 112 42.000 0.00 0.00 O.OON O.OOE 120.00 120.00 O.OON O.OOE 112 121/4 2949.87 2200.00 164.488 1493.87E 6913.28 3607.00 2765.708 2994.96~ 112 81/2 5986.11 3446.00 1845.34S 3098.42E 11051.76 3370.00 6877.81 S 2536.27E 112L 1 Casings Name Top Top Top Top Shoe Shoe Shoe Shoe Wèllbore MDfftJ worftl NorthfftJ Eastrftl MDfft1 WDfftJ NorthfftJ EastrftJ 20.000in 0.00 0.00 O.OON O.OOE 120.00 120.00 O.OON O.OOE 112 Conductor 13 3/8in Surface 0.00 0.00 O.OON O.OOE 3169.62 2300.00 211.94S 1683.70E 112 casinQ 9 5/8in 0.00 0.00 O.OON O.OOE 6913.28 3607.00 2752.71S 2996.45E 112 Intermediate casinQ 5 1/2in Liner 5696.16 3379.00 1565.148 3129.90E 11045.90 3310.00 6877.81 S 2536.27£ 112L2 5 1/2in Liner 5986.11 3446.00 1845.348 3098.42E 11051.76 3370.00 6877.81S 2536.27E 112L1 TarQets Name Northfftl Eastfftl rvorft1 Latitude Lonoitude Eastino Northino WS 1E D4B TOE 6877.818 2536.27E 3370.00 N70 16 55.5517 W149 34 19.4806 552883.00 5952921.00 RVSD042104 WS 1E D4 4546.26S 2794.91 E 3417.00 N70 17 18.4815 W149 34 11.9219 553126.00 5955254.00 B-MDPT#2 RVSD042104 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 95.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORiC'H,¡ J~... ., n; ~ 1\, ,,. ",,! .1~oJ'.I~" ·l_ . . conocJ'Phillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 5 Wellbore: 112L 1 Wellpath: 112L1 Ver#3 Date Printed: 19-May-2004 Ri. BAKER HUGHU INTEQ TarQets Name WS 1E D4 B-MDPT#1 RVSD042104 Northrftl Eastfftl TVDffU Latitude Lonaitude Eastioa 2558.51S 3018.24E 3458.00 N70 17 38.0300 W149 34 5.3915 553336.00 Northino 5957243.00 Survey ToolProaram Reference Survey Name 660082 Planned 660118 Planned 5986.11 3446.00 ISCWSA MWD Error Model MWD+SAG . ISCWSA - 28 Jan 03 OJH MWD+SAG - ISCWSA - 28 Jan 03 OJH MDfftl 11051.76 TVDfftj 3370.00 Survey Tool ISCWSA MWD 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 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORJGI~tAL ConocoPhillipsAlaska, Inc. 3400 -1600 -1800 -2000 ^ , -2200 -2400 -2600 -2800 -3000 -3200 -3400 -3600 (j) 0 -3800 * 0 3 - -4000 \I 0 0 -4200 ;:I! North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1 liE Scale 1 em" 100 ft 2200 2400 East (feen -> 2600 28ðo 3ÓOO 5500 5800 Slot: Well: 112 Well bore: 112 3200 3400 3600 -200 -400 -600 -800 -1000 -1200 ~1400 Alaska Field: Kuparuk River Unl! Installation: Pad 1 IE 112 Well bore: 112 Scale 1 em 100ft East Ifeet\ 2000 2200 2400 26ðo 2800 3000 3200 3400 ~_l....I 3600 3560 5820 5860 3540 -3200 -3400 -3600 -4000 -4200 -4400 -4600 -4800 I -5600 -5800 -6000 -6200 -6400 -6600 (j) o -6800 ~ o :3 - -7000 II o o -7200 ;:¡, ConocoPhillips Alaska., Inc. l,)cation: North Slope, Alaska Field: Kuparuk Rive, Unit Installation: Pad 1 E Slot: Slot#112 Well: 112 Well bore: 112 Created by : Date plotted. 21-May-2004 Plot reference ìs 112. Ref weIJpath is 112 Ver#3< CQordinates are in feet reference Slot#112. True Vertical Depths are reference: Rig Datum. Measured Depths are reference Rig Datum, Rig Datum: Doyon #141 RI<B Datum to mean sea level: 95,00 ft. North. TRUE NORTH 350 o 10 340 20 70 80 90 100 110 200 170 160 All depths shown are Measured depths on Reference Well Normal Plane Travelling Cylinder - Feet · Baker Hughes Incorporled Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 5696.16 to 11045.84 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive WelIpath Date: 1/12/2004 Validated: No Planned From To Survey ft ft 0.00 5696.15 Planned: 1E-112 Vers#3 V17 (0) 5696.15 11045.84 Planned: 1E-112L2Vers#3V9 Version: 0 Toolcode Tool Name MWD+SAG MWD+SAG MWD + Sag correction MWD + Sag correction Summary Pad 10 116 10-116 V1 Out of range Pad 10 122 10-122 VO Out of range Pad 10 124 10-124 VO Out of range Pad 10 125 10-125 V1 5762.82 5779.00 4110.60 166.86 3943.74 Pass: Major Risk Pad 10 126 10-126 VO 6434.70 6700.00 3084.07 209.59 2874.48 Pass: Major Risk Pad 1D 127 10-127 VO 8256.34 7416.00 3074.49 324.02 2750.47 Pass: Major Risk Pad 10 128 10-128 VO 7073.04 6564.00 4024.72 243.77 3780.95 Pass: Major Risk Pad 10 129 10-129 VO 6400.74 4950.00 5180.96 197.95 4983.01 Pass: Major Risk Pad 1 D 131 10-131 VO 7773.22 6275.00 4990.38 283.47 4706.91 Pass: Major Risk Pad 10 3 1 D-03 VO Out of range Pad 10 7 1 D-07 VO 7646.41 7725.00 5076.12 328.25 4747.87 Pass: Major Risk Pad 1E 10 1E-10 VO Out of range Pad 1 E 102 102 B-Lateral VO Plan: Out of range Pad 1E 102 102 D-Lateral VO Plan: Out of range Pad 1E 103 103 VO Plan: 1E-103 VE Out of range Pad 1E 104 104 VO Plan: 1E-104 VE Out of range Pad 1E 105 105 A2-Lateral VO Plan 5703.40 8525.00 2101.02 170.25 1930.77 Pass: Major Risk Pad 1E 105 105 B-Lateral VO Plan: 5698.37 8550.00 2084.16 159.61 1924.56 Pass: Major Risk Pad 1E 105 105 D-Lateral VO Plan: 5708.74 8575.00 2083.98 160.47 1923.51 Pass: Major Risk Pad 1E 11 1E-11 VO Out of range Pad 1 E 112 1E-112 VO Plan: 1E-112 5700.00 5700.00 0.02 145.14 -145.12 FAIL: Major Risk Pad 1E 112 1E-112L1 VO Plan: 1E-1 5700.00 5700.00 0.02 145.14 -145.12 FAIL: Major Risk Pad 1 E 114 114 A2-Lateral VO Plan Out of range Pad 1 E 114 114 B-Lateral VO Plan: Out of range Pad 1E 114 114 D-Lateral VO Plan: Out of range Pad 1 E 117 117 A2-Lateral VO Plan 11000.00 7825.00 1274.02 512.23 761.79 Pass: Major Risk Pad 1E 117 117 B-Lateral VO Plan: 11000.00 7825.00 1274.02 512.22 761.80 Pass: Major Risk Pad 1E 117 117 D-Lateral VO Plan: 11000.00 7825.00 1274.02 512.22 761.80 Pass: Major Risk Pad 1 E 119 119 VO Plan: 1E-119 Ve 10208.70 7242.30 2028.46 452.02 1576.43 Pass: Major Risk Pad 1E 1 1E-01 VO 6050.68 4300.00 3428.04 173.72 3254.32 Pass: Major Risk Pad 1 E 1 1E-01A VO 6087.35 4500.00 3260.27 134.43 3125.84 Pass: Major Risk Pad 1 E 121 121 B-Lateral VO Plan: Out of range Pad 1E 121 121 D-Lateral VO Plan: Out of range Pad 1 E 12 1E-12 VO Out of range Pad 1E 123 1E-123 L1 V1 Plan: 1E- Out of range Pad 1 E 123 1E-123 V8 Out of range Pad 1 E 126 126 A2-Lateral VO Plan 10798.16 12054.87 1090.90 519.77 571.13 Pass: Major Risk Pad 1E 126 126 B-Lateral VO Plan: 10796.52 12066.71 1110.03 508.93 601.10 Pass: Major Risk Pad 1 E 126 126 D-Lateral VO Plan: 10797.73 12062.49 1105.96 512.10 593.86 Pass: Major Risk Pad 1 E 13 1E-13 VO Out of range Pad 1E 14 1E-14 VO Out of range Pad 1 E 15 1E-15 VO Out of range Pad 1 E 16 1 E-16 VO Out of range Pad 1 E 166 166 A2-Lateral VO Plan 10987.15 8875.00 983.02 502.50 480.52 Pass: Major Risk Pad 1 E 166 166 B-Lateral VO Plan: 10983.15 8850.00 955.18 491.01 464.17 Pass: Major Risk Pad 1E 166 166 D-Lateral VO Plan: 10990.70 8850.00 953.88 492.15 461.73 Pass: Major Risk Pad 1 E 168 168 A2-Lateral V3 Plan 6259.88 5800.00 514.77 145.70 369.07 Pass: Major Risk Pad 1E 168 168 B-Lateral VO Plan: 6259.88 5800.00 514.77 145.69 369.07 Pass: Major Risk Pad 1 E 168 168 D-Lateral VO Plan: 6259.88 5800.00 514.77 145.69 369.07 Pass: Major Risk Pad 1 E 170 170 A2-Lateral VO Plan 10981.72 7275.00 2303.95 504.02 1799.93 Pass: Major Risk ORIGINAL · Baker Hughes Incorpo~ed Anticollision Report Summary Pad 1E 170 170 B-Lateral VO Plan: 10981.72 7275.00 2303.95 504.01 1799.94 Pass: Major Risk Pad 1E 170 170 D-Lateral VO Plan: 10981.72 7275.00 2303.95 504.01 1799.94 Pass: Major Risk Pad 1 E 17 1E-17 VO Out of range Pad 1 E 18 1E-18 VO Out of range Pad 1 E 19 1E-19VO Out of range Pad 1E 20 1 E-20 VO Out of range Pad 1 E 21 1E-21 VO Out of range Pad 1 E 2 1 E-02 VO 6923.06 5800.00 1984.16 171.22 1812.94 Pass: Major Risk Pad 1 E 22 1 E-22 VO 6076.15 5350.00 489.96 129.06 360.91 Pass: Major Risk Pad 1E 23 1 E-23 VO 6129.58 5275.00 1273.98 135.42 1138.55 Pass: Major Risk Pad 1E 24 1 E-24 VO 5750.00 5300.00 2855.70 95.13 2760.57 Pass: Major Risk Pad 1 E 24 1 E-24A VO 5868.56 6900.00 2725.23 85.91 2639.32 Pass: Major Risk Pad 1 E 25 1 E-25 VO Out of range Pad 1E 26 1 E-26 VO 5720.93 3125.00 3536.58 131.69 3404.88 Pass: Major Risk Pad 1E 26 1 E-26A VO 5716.90 3175.00 3568.21 123.45 3444.76 Pass: Major Risk Pad 1E 27 1 E-27 VO Out of range Pad 1 E 28 1 E-28 VO 5725.10 3275.00 4278.10 118.47 4159.63 Pass: Major Risk Pad 1E 29 1E-29 VO 5698.65 3925.00 4027.08 109.50 3917.58 Pass: Major Risk Pad 1 E 30 1 E-30 VO 5697.36 4150.00 4574.63 111.71 4462.92 Pass: Major Risk Pad 1 E 31 1 E-31 V1 9512.91 10005.00 3384.41 263.40 3121.01 Pass: Major Risk Pad 1E 31 1E-31PB1 VO 9254.67 8725.00 4012.16 320.41 3691.75 Pass: Major Risk Pad 1E 3 1 E-03 V1 5696.15 7950.00 2694.29 129.67 2564.62 Pass: Major Risk Pad 1E 32 1 E-32 VO 9513.03 7475.00 2679.67 360.49 2319.18 Pass: Major Risk Pad 1 E 33 1 E-33 VO 5696.15 6550.00 1529.11 160.53 1368.58 Pass: Major Risk Pad 1E 33 1E-33PB1 VO 5696.15 6550.00 1529.11 160.53 1368.58 Pass: Major Risk Pad 1E 34 1 E-34 VO 8200.73 7300.00 2104.81 272.33 1832.48 Pass: Major Risk Pad 1 E 35 1 E-35 VO 9562.80 7350.00 1285.99 296.72 989.27 Pass: Major Risk Pad 1 E 35 35A VO Plan: 35A ST Ve 9600.59 7400.00 1277.94 289.71 988.23 Pass: Major Risk Pad 1E 36 1 E-36 VO 10982.19 10925.00 4440.29 467.59 3972.70 Pass: Major Risk Pad 1E 4 1 E-Q4 VO 5724.71 3575.00 4380.33 133.84 4246.50 Pass: Major Risk Pad 1 E 5 1 E-05 VO Out of range Pad 1 E 6 1 E-06 VO Out of range Pad 1E 7 1 E-07 VO Out of range Pad 1E 8 1 E-08 V1 Out of range Pad 1 E 9 1E-09 VO Out of range Pad 1E WSR#2 WS2 V1 5922.62 3425.00 1387.76 130.68 1257.09 Pass: Major Risk Pad 1J 10 1J-10VO Out of range Pad 1J 1 J-DQ 1 J-L6 A Lateral V1 Pia 8720.89 11640.58 4956.78 437.73 4519.05 Pass: Major Risk Pad 1J 1J-DS 1J-L5 A Lateral V1 Pia 8857.87 12531.63 3722.57 437.14 3285.43 Pass: Major Risk Pad 1J 1J-DU 1J-L4 A Lateral V1 Pia Out of range Pad 1J 1J-DW 1J-L3 A Lateral V1 Pia Out of range Pad 1J 9 1J-09 VO 10983.45 9725.00 4704.83 349.96 4354.87 Pass: Major Risk OR'G'~J.A\L. . . Conoc~illips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Wellbore: 112L2 Wellpath: 112L2 Ver#3 Date Printed: 19-May-2004 Bi. BAKER HUGHES INTEQ Wellbore Name 112L2 I Created 26-Apr-2004 I Last Revised 14-May-2004 Well Name 112 I Govemment ID I Last Revised 2-Feb-2004 Slot Name Slot #112 I Grid Northinq 5959781.0000 Eastinq .0000 ILatitude N70 18 3.1987 W149 35 33.3560 I North 191.43N lEast 225.93W Installation Name Pad 1 E I Eastina 550528.1946 I Nbrthina 5959591 .1090 coord Svstem Name/North Alianment AK-4 on NORTH AMERICAN DATUM 1927 datum True Field Name Kuoaruk River Unit I Eastina · 487754.6208 Northina 5948985.8206 I Coord Svstem Name INorth Alionment AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig (Doyon #141 RKB 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . Conoc<>Phillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 2 Well bore: 112L2 Well path; 112L2 Ver#3 Date Printed: 19-May-2004 .¡. BAKER HUGHES INTEQ Wellpath Report MD[ft] Inc[de Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station 8tation . Dogie Vertical Station Comment g] Depth 88 Position(Grid Position(Grid g 8ection[ North) East) [deg/1 ft] OOftl 5696.16 75.00 186.41 3379.00 3284.00 1565.148 3129.90E 5958237.00 553441.00 0.00 1205.81 Top Whipstock Face, Tie on 5712.66 77.24 186.41 3382.96 3287.96 1581.06S 312B.11E 5958221.07 553439.32 13.60 1221.83Base Whiostock Face. End of Build 5732.66 77.24 186.41 3387.37 3292.37 1600.448 3125.94F 5958201.68 553437.27 0.00 1241.34 End Milled Oœnhole. KOP. End of Hold 5800.00 81.28 186.41 3399.92 3304.91 1666.188 3118.55E, 5958135.90 553430.32 6.00 1307.48 5900.00 87.28 186.41 3409.87 3314.87 1765.018 3107.44E 5958037.00 553419.88 6.00 1406.94 5937.61 89.54 186.41 3410.91 3315.91 1802.378 3103.24E 5957999.62 553415.93 6.00 1444.54 EOC. 2DX8 Kick off Point 6037.61 92.54 186.41 3409.09 3314.09 1901.718 3092.07E, 5957900.22 553405.43 3.00 1544.50 End of Build £100.00 92.54 186.41 3406.33 3311.33 1963.658 3085.11 E 5957838.24 553398.88 0.00 1606.83- 6200.00 92.54 186.41 3401.90 3306.89 2062.938 3073.95E. 5957738.90 553388.39 0.00 1706.74 6224.32 92.54 186.41 3400.82 3305.82 2087.088 3071.24E, 5957714.73 553385.83 0.00 1731.04 End of Hold 6324.32 89.54 186.41 3399.00 3304.00 2186.388 3060.07E 5957615.37 553375.34 3.00 1830.97 End of Droo 6400.00 89.54 186.41 3399.61 3304.61 2261.588 3051.62E 5957540.12 553367.39 0.00 1906.64 6500.00 89.54 186.41 3400.41 3305.41 2360.958 3040.45E, 5957440.68 553356.88 0.00 2006.64 6600.00 89.54 186.41 3401.21 3306.21 2460.328 3029.28E. 5957341.25 553346.38 0.00 2106.63- 6698.81 89.54 186.41 3402.00 3307.00 2558.518 3018.24E 5957243.00 553336.00 0.00 2205.44 W8 1E D4 D-MDPT#1 RV8D042104, 3DJ Kick off Point 6700.00 89.58 186.41 3402.01 3307.01 2559.708 3018.11 E. 5957241.82 553335.88 3.00 2206.63 6755.98 91 .26 186.41 3401.60 3306.60 2615.328 3011.86E. 5957186.16 553330.00 3.00 2262.6QEnd of BuildfTum 6800.00 91.26 186.41 3400.64 3305.64 2659.068 3006.94E, 5957142.39 553325.38 0.00 2306.62- 6900.00 91.26 186.41 3398.45 3303.45 2758.418 2995.78E. 5957042.98 553314.88 0.00 2406.5~ 7000.00 91.26 186.41 3396.25 3301 .25 2857.768 2984.62E. 5956943.57 553304.38 0.00 2506.57 7100.00 91.26 186.41 3394.06 3299.06 2957.118 2973.46E, 5956844.15 553293.89 0.00 2606.54 7200.00 91.26 186.41 3391.87 3296.87 3056.46S 2962.29E. 5956744.74 553283.39 0.00 2706.52- 7300.00 91.26 186.41 3389.68 3294.68 3155.818 2951.13E. 5956645.33 553272.90 0.00 2806.5~ 7400.00 91.26 186.41 3387.49 3292.49 3255.168 2939.97E 5956545.91 553262.40 0.00 2906.47 7500.00 91.26 186.41 338529 329029 3354.518 2928.81F 5956446.50 553251.90 0.00 3006.45 7600.00 91.26 186.41 3383.10 3288.10 3453.868 2917.64F 5956347.09 553241.41 0.00 3106.4? 7700.00 91.26 186.41 3380.91 3285.91 3553.218 2906.48E, 5956247.67 553230.91 0.00 3206.40 7800.00 91.26 186.41 3378.72 3283.72 3652.57S 2895.32E. 5956148.26 553220.42 0.00 3306.38- 7900.00 91.26 186.41 3376.53 3281.53 3751.928 2B84.16~ 5956048.85 553209.92 0.00 3406.35 8000.00 91.26 186.41 3374.33 3279.33 3851.278 2872.99E, 5955949.43 553199.42 0.00 3506.33 8100.00 91.26 186.41 3372.14 3277.14 3950.628 2861.831'; 5955850.02 553188.93 0.00 3606.3Q 8200.00 91.26 186.41 3369.95 3274.95 4049.97S 2850.67E 5955750.60 553178.43 0.00 3706.28, 8300.00 91.26 186.41 3367.76 3272.76 4149.328 2839.51 E, 5955651.19 553167.94 0.00 3806.26 _ 8400.00 91.26 186.41 3365.57 3270.57 4248.678 2828.34E.. 5955551.78 553157.44 0.00 3906.23- 8500.00 91.26 186.41 3363.37 3268.37 4348.028 2817.18E 5955452.36 553146.94 0.00 4006.21 8600.00 91.26 186.41 3361.18 3266.18 4447.378 2806.02E 5955352.95 553136.45 0.00 4106.1 eo 8699.53 91.26 186.41 3359.00 3264.00 4546.268 2794.91E 5955254.00 553126.00 0.00 4205.69 W8 1 E D4 D-MDPT#2 RV8D042104, 3DJ Kick off Point 8700.00 91.25 186.40 3358.99 3263.99 4546.728 2794.86E, 5955253.54 553125.95 3.00 4206.16 8702.87 91.20 186.33 3358.93 3263.93 4549.588 2794.54E 5955250.68 553125.65 3.00 4209.03End of DroofTurn 8800.00 91.20 186.33 3356.90 3261.90 4646.098 2783.83F 5955154.11 553115.59 0.00 4306.14 8900.00 91.20 186.33 3354.81 3259.81 4745.468 2772.81E, 5955054.68 553105.24 0.00 4406.12- 9000.00 91.20 186.33 3352.72 3257.72 4844.83S 2761.79E 5954955.25 553094.88 0.00 4506.0~ B100.00 91.20 186.33 3350.64 3255.64 4944.208 2750.76E 5954855.82 553084.52 0.00 4606.07 9200.00 91.20 186.33 3348.55 3253.55 5043.578 2739.74E. 5954756.39 553074.17 0.00 4706.05 9300.00 91.20 186.33 3346.46 3251.46 5142.948 2728.72E 59?4656.96 553063.81 0.00 4806.0:?a 9400.00 91.20 186.33 3344.37 3249.37 5242.30S 2717.70E 5954557.52 553053.46 0.00 4906.0t 9500.00 91.20 186.33 3342.28 3247.28 5341.678 2706.67E. 5954458.09 553043.10 0.00 5005.9E All data is in Feet unless otherwise stated Coordinates are from 810t MO's are from Rig and TVD's are from Rig (Doyon #141 RKB 95.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGIN1~tð . . Conoc6Phillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Wellbore: 112L2 Wellpath: 112L2 Ver#3 Date Printed: 19-May-2004 _i. BAKER HUGHES INTEQ Well path Report MD[ft] Inc[de Azi[deg] TVD[ft] Vertical North[ft] East[ft] 8tation 8tation Dogie Vertical 8tation Comment g] Dépth 88 Position(Grid Position(Grid g 8éction[ North) East) [deg/1 ft] OOftl 9600.00 91.20 186.33 3340.19 3245.19 5441.048 2695.65E. 5954358.66 553032.74 0.00 - 5105.96 9700.00 91.20 186.33 3338.11 3243.11 5540.418 2684.63E 5954259.23 553022.39 0.00 5205.94 9800.00 91.20 186.33 3336.02 3241.02 5639.788 2673.60F 5954159.80 553012.03 0.00 5305.9? 9900.00 91.20 186.33 3333.93 3238.93 5739.158 2662.58E. 5954060.37 553001.67 0.00 5405.90 10000.00 91.20 186.33 3331.84 3236.84 5838.528 2651.56E 5953960.94 552991.32 0.00 5505.87 10100.00 91.20 186.33 3329.75 3234.75 5937.888 2640.53E. 5953861.51 552980.96 0.00 5605.8f:\ 10200.00 91.20 186.33 3327.67 3232.66 6037.258 2629.51E. 5953762.08 552970.60 0.00 5705.83 10300.00 91.20 186.33 3325.58 3230.58 6136.628 2618.49E 5953662.65 552960.25 0.00 5805.81 10400.00 91.20 186.33 3323.49 3228.49 6235.998 2607.47E. 5953563.22 552949.89 0.00 5905.7~ 10500.00 91.20 186.33 3321.40 3226.40 6335.368 2596.44E 5953463.79 552939.54 0.00 6005.77 10600.00 91.20 186.33 3319.31 3224.31 6434.738 2585.42F 5953364.36 552929.18 0.00 6105.74 10700.00 91.20 186.33 3317.22 3222.22 6534.108 2574.40E. 5953264.93 552918.82 0.00 6205.72. 10800.00 91.20 186.33 3315.14 3220.14 6633.478 2563.38E. 5953165.50 552908.47 0.00 6305.7C 10900.00 91.20 186.33 3313.05 3218.05 6732.838 2552.35E. 5953066.07 5528.98.11 0.00 6405.6& 11000.00 91.20 186.33 3310.96 3215.96 6832.208 2541.33F 5952966.64 552887.75 0.00 6505.6Q 11045.90 91.20 186.33 3310.00 3215.00 6877.818 2536.27E 5952921.00 552883.00 0.00 6551.55 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig (Doyon #141 RKB 95.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIG" . . Conoc6';"illips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 4 Well bore: 112L2 Well path: 112L2 Ver#3 Date Printed: 19-May-2004 ... BAKER HUGHES INTEQ Comments MDrftl TVDfftl Eastrft 1 Northfftl Comment 5696.16 3379.00 3129.90E 1565.148 Top Whipstock Face 5712.66 3382.96 3128.11E 1581.068 Base Whipstock Face 5732.66 3387.37 3125.94E 1600.448 End Milled Openhole, KOP 5937.61 3410.91 3103.24E 1802.378 ..EOC 11045.90 3310.00 2536.27E 6877.818 TO Hole Sections Diameter 8tart 8tart Start 8tart End End End End\nEast[ft] Wellbore finl MDfftl TVDfftl Northrftl Eastrftl MDrftl TVDrftl Nbrthrftl 16.000 0.00 0.00 O.OON O.OOE 3169.62 2300.00 211.948 1683.70E 112 42.000 0.00 0.00 O.OON O.OOE 120.00 120.00 O.OON O.OOE 112 12 1/4 2949.87 2200.00 164.488 1493.87E 6913.28 3607.00 2771.608 2994.30E 112 81/2 5696.16 3379.00 1565.148 3129.90E 11045.90 3310.00 6877.818 2536.27E 112L2 Casinas Name Top Top Top Top 8hoe 8hoe Shoe Shoe Well bore MDfftl TVDfftl Northrftl Eastrft 1 MDrftl TVDJftl Northfftl Eastrftl 20.000in 0.00 0.00 O.OON O.OOE 120.00 120.00 O.OON O.OOE 112 Conductor 13 3/8in 8urface 0.00 0.00 O.OON O.OOE 3169.62 2300.00 211.948 1683.70E 112 casino 9 5/8in 0.00 0.00 O.OON O.OOE 6913.28 3607.00 2752.718 2996.45E 112 Intermediate casino 5 1/2in Liner 5696.16 3379.00 1565.148 3129.90E 11045.90 3310.00 6877.818 2536.27E 112L2 Targets Name Northfftl -Eastrftl TVDrftl Latitude Lonoitude Eastino Northino WS 1E D4 2558.518 3018.24E 3402.00 N70 17 38.0300 W149 34 5.3915 553336.00 5957243.00 D-MDPT#1 RVSD042104 WS1ED4DTOE 6877.818 2536.27E 3310.00 N70 16 55.5517 W149 34 19.4806 552883.00 5952921.00 RV80042104 WS 1E D4 4546.268 2794.91 E 3359.00 N70 17 18.4815 W149 34 11.9219 553126.00 5955254.00 D-MDPT#2 RV8D042104 All data is in Feet unless otherwise stated Coordinates are from 810t MO's are from Rig and TVD's are from Rig (Doyon #141 RKB 95.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated n f) I ",-.J f'é . . ConocJ'Phillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 5 Wellbore: 112L2 Well path: 112L2 Ver#3 Date Printed: 19-May-2004 Ri. BAKER HUGHES INTEQ Survey ToolProqram Reference Survev Name 660051 Planned MDrftl 11045.90 TVDrftl 3310.00 Survev Tool ISCWSA MWO 660118 Planned 5696.16 3379.00 ISCWSA MWD Error Model MWD+SAG - ISCWSA - 28 Jan 03 OJH MWD+SAG - ISCWSA - 28 Jan 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig (Doyon #141 RKB 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated OR'hLNJA " v ., r "~"J j g ~, lb"" *Tublng Head Assy, 20" X 13·3/S" X 9-6/S" X 4-1/2", 13·6/S" API 6M flange up. *Tublng Hanger, concentric, no penetrations ·Conductor, 20" X 34" Insulated, set at SO'. Tubing, Special Drift ConocJ'Pí, ill ips DB Nlpple,for Possible SSSV, set at +/_ 600' MD GLM, Camco 1-1/2" MMG 1 E West Sak 9-5/8" Injector Tri-Lateral Completion Well #: 1 12 13-3/S" Surface CasIng Shoe 61#, J-66, BTC 3200' MD, 2314' TVD. GLM, Camco 1" KBMG Casing Sealbore Receptacle / / Seal Assembl/' Tubing Swivel, 4~i/2" Lateral Entry Module(LEM} Orienting Profile D-sand Window / at 6696' MD, 4379' TVD 'D' Sand Latëral 6·112" Casing Shoe @ 11048' MD, 3310' TVD 7" X 9-5/8" Modol '8' HOOK Hano.r Seal Bores Pack-off Bushing Lateral Entry Module{LEM) Orîenting Profile Casing Sealbore Receptacle B-sand Window at 69S8' MD, 3446' TVD '8' Sand Latëral 7" X 9-5/8" Model '8' HOOK Hanaer 5-1/2" 15.5#, L·BO Slotted Liner 5-1/2" Bent Joint ¡ 5-1/2" Guide Shoe \ Pack-off Bushing 6-1/2" Casing Shoe @ 11062' MD, 3370' TVD 4-1/2" 12.6# Tubing Undulatina 'A' Sand Lateral 5~1/2" Eccentric Guide Shoe 6-1/2" Casing Shoe @ 11071' MD, 3646' TVD Baker Oil Tools 9·6/S" Casing Shoe 40.0#, L-SO BTC 12-1/4" Hole @ 8912' MD, 3600' TVD Pack-off Bushing .. KRU1 1 PTD 204...091 N ~ SFD 6/1/2004 ! 0 '1 ,3 \ ! ¡ o 1 ,ODD . . SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G STREET ANCHORAGE AK 99501 1061 DATE 2t3tf I '2£O'f 62-14/311 ~~~~~¿;~E 51l1fe-oftJUfStA !IfCX:::rLL $/00.00 -:-()þ¿ W~ ~~ ~Þ~JOo- ..... CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars . , 200 White Clay Center Dr., Newark. DE 19111 .: -~y~_.dI4~7JL .: 0 3 . .00 . I. I.': 2 . B I. ? . q 0 ? q 2 ? bill .0 b . uOLLARS ß . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /<I?¿p /E~/I¿ PTD# ¿ó L/ -01' / X / Development /V Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn The permit is for a new wellboresegment of existing well Permit No, API No. Production. should continue to be reponed as a function' of the original API number. stated above. HOLE In accordance with 20 AAC 2S.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance with 20 AAC 25.0S5~ Approval to perforate and produce is contingent upon issuance of $i conservation order approving a spacing eneption. (Company Name) assumes the JiabiUty of any protest to tbe spacing. e:Jception tbat may occur. AU dry ditcb sample sets submitted to tbe Commission must be in no greater ·than 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and ] 0' sample intervals through target zones. Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1 E-112 Program DEV PTD#: 204091 0 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 On/Off Shore On 1 PelJY1itfee attached . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ .Yes.. . . . . . _ . . . . _ . . . . _ . . . . . . . . _ . . . . . . 2 .Leasenumber <lppropJiate. . . _ . . . . _ . . . . . . . . . _ . .Yes. . . . . . _ . _ . . . . . . . . . _ _ . . . . . _ _ . . . . . _ . . . . . . . 3 .UJli~ue well_n.ame .aod oUJl'!b~r . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Yes _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeJllocatedin_a_d_etil'!edpool. _.... _ _.. . .Yes .Con.servatiooO(d~rNo.,406A,KupaJukRillerUoit.We.stSa_k.OJIPp01... .............. 5 WeJI Jocated proper distance. from driJling ul1itbpUl1d<lry. . . . . . . . . . . . . .Yes. . . Nomioal spa.ciJlg withil1 the po oJ is.1 0 <leres. WeJI wjlllie entirely withjn.uniti~ed State Je<lsesAD.L.02565:1 . 6 WeJIJo.catedproperdistancefromotheJwel!s... ...... ............. .Yes ... <lodAOl02~660.whicharecommitted.toth.eWestSak.=)articipating.Area,a.ndwi/l be Jo.cated rnore. . 7 .5!Jfficiel1t <lereaQ.eayailable in.driUiOQ.uniL . . . . . . . . . . . . . . . . . . . . . .Yes. . . . th.an 300 feetJrorn.aJlY property Jioe.swhere.owoershJp ch<loge.s..Ne.are.stprod.uctionor injection 8 Jfdeviated, iswellboJe plaUl1cluded . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . . . . well open to.the pool will be -:-t,90.0Jeetaway, . . . . . . . . . . . . . . . . 9 .oper.ator onJy affected pa.rty. . . . . . . . . . . . . . . . . . . . . . . .Yes . . . . . . . . . . . . . . . . . . . . . 10 .oper<ltor has.appropriate.b.Qod iJl Jorce. _ . . . . . . _ . . . . . . _ _ . . . . . . . . . . _ . . . . . . .Yes. . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . 11 Permit~o be i.ssu.ed witho.ut conservatiOI1 order. . . . . . . . .Yes. . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . _ . . . . . . . . 12 Permitc<lo be i.ssu.ed witho.ut admil1istr.atille.approvaJ . . . . . . . . . . . . . . . . . . . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6/1/2004 13 Can permit be approved before 15-day wait Yes 14 WeJI Jo.cated withil1 area an.d.strata <lutl10rized byJojectioo Order"# (puUO# in.comrneotS) (for . .Yes. . f'roposed tri:lateraUojectiol1 wellgovemed .by Are<l Jl1jectiol'l Order No, 26 . . . . . . . . . 15 AJlwells.within.1l4.mil~.are.a.ofreyiewideotlfied(ForserviceweUOl1ly). _.......... _.' .Yes...... .Is:BU 1E-33,J<RUJ.E:2.2............ _........................ _................ 16 Pre-produçed. injector; duration of pre-productioo less than 3 mOl'lths. (For .seryiçe welt only) . . .Yes. . . . . Will.be pre:PJoduce.dJorabout .180 days perSte.ve Shultz,.611/2004.. . . . . . . . . 17 AÇMPFjndlng.ofCon.si.stency.h<lsbeeJlJs.sued.forthisproiect . NAWelldriJledfro.mexjstiogpad... ....... ............ _......' 18 .CooductJ:>r strin.9.prQvided . . . . . . . .Yes. . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 .5!Jrfacecasil1gprotectsall.knownUSQWs....... ... _.. . NA .Altaq!Jifersexernpted40CE'H147.102(b)(3). 20 .CMT.vota.dequateto circ!Jl<lteoJl.cOl1d!Jctor& surtcsg . . .Yes. '..... . . . . . . . . . . . . . 21 .CMTvota.dequ.ateto tie-iJlJong .string to.surf cs.g. . . . . . . . . . . N.o. 22CMT.wil!coy~ralll<oownproductiYehori~on.s... ....... No . Slotted Jioerptaooed, Intermediate casingwill.be cemented above.a.ny hydrocarboo.. '...... 23C<lSiogdesignsad.equateforC,T. B.&permaJrost. . .Yes. . . . . . . . .. . . . . . . . . . . .. . . . . . .. . . . . . . 24 Adequate tanJ<age.orre.serve pit . . . . . . . . . . . . . . . . . . .Yes. . . Rig is.e.quipped.with steel pits. NOJeseNe.pjt ptanoe.d. Wa.steto al'l approved. annulus or .dispos<lt well. 25 Itare-drill. has.a 10-4.03 for aba.ndonment beeo approved. NA. . . . . . . . . . . . . 26 Adequate.w.ellbore.separationproposed.... _ _.... _...... _............ _.' .Yes.. _... _I?ro~imity_analysisperforme.d, Ç!oseªppro.açhe.sjd.entified..TralleJiOQ.cyUn.der.pJotproyided, .Qyro.spossible. 27 If.diveåer req!Jire.d, does it meet regulatiOl1s . . . . . . . . . . . . . . . .Yes. . . . . . . 28 .DriUiog fluid. program schemªtic& equip Jist.adequate. . . . . . . . . . . . . . . . _ .Yes. . . . BH=) expected betwe~o 7.9.- 8.5EMW.. Plaon.ed MW -to.ppg in 12:113" hole aod. 9.0 in West Sak. . . . 29 BOPEs,.dothey meetJeguJa.tiOI1 . . .Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 .BOPEpre.ss ratiog appropriate; test to .(put psig in .comrnel1ts). . . . . . . . . . .Yes. MAS=) caJculatedat 1113 psi.. 3500.p$Î.appropriate,CPAJ likely to tesUo 50.00 psi.. . . . . . . 31 Ç.hokema.nifold complies. w/API.R=)-53. (May 84). . . . . . . . . . . . . . . . . . . . . . . .Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 WOJkwilloccurwithouLoperation.shutdowJl...... ...... .....' .Yes. .... .furthertoAOR,.tE-33.h<lscasing.setaJldce.mented.throu.ghWe.stSak, ...... 33 IS.presence.oJH2Sgas.prob.able. .......'.... _. '.....'...... N.o ... .H2Sis!JoliJ<eIY..Mud.s.houldpreelude.H2.5.on.the.rig. Rig.isequippedwith.seosorsa.nd<ltarms.. 34 Mechanicalcoodjtion of weJls withJI1 AOR verified (for. service welJ onJy). . . . . . . . . . .Yes. . 1E-22 does oot .ha,,-e.cernel1tacross West Sak. . C=)AI is.aware.aJld will.address.p[ior.to conyertin.g.weJl to. wioj.. . . Administration Appr SFD Date I. Engineering Appr Date TEM 6/7/2004 J9.~ Geology Appr SFD Date 6/1/2004 Geologic Commissioner: OTS Well bore seg Annular Disposal o o - - - - - ~ - - - - - - - 35 Permitc<ln be Lssu.ed wlo. hYdrogen.s.ulfide rneaS!Jres. . . . . _ . . . . . . . . 36D<ltapreseoted on.poteJltial overpressure ZOl1es. ...... 37Sei$rniC .analysjs. oJ shallow gas.zooes. 38 .Seabed conditioo survey (if off-shore). ....... . . . . . . . . . . . . 39 . Contact l1am.elphOl'leJorweekly progress reports [e~ploratory .only] . . . . · .Yes. · .Yes. . NA. · NA · NA . . . . Is:RU WestSal< welJs.1/2 miJe. to eas.t measured JeS$ than 7 ppm H2S jn.August 2003, . . Expected. rese.rvoir pressure i.s 7.9.- .8,5ppg EMW; will.be drilled with 9.0 ppg mud.. . . . . . Hydrates and shallow gas.arel1o.t expected in thJs.area. . . . . . . . - - - - - -- - - - - - - - ~ - - - - - - ~ - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - &/'1/r Engineering Commissioner: ~\~ Proposed tri-Iateral injection well. Initially classified as a development well as it will be pre-produced for about 180 days. Prior to conversion to injection, the operator must satisfy the requirements of regulation 20 AAC 402 (e) concerning integrity of wells within Area of Review. Public CO~ Date Geologic Commissioner: Date: Engineering Commissioner: Date Public Commissioner Date 35 36 37 38 39 _S~abep _condJtipo !Hlrvey CQnta_ct namelphoneJorweelsly progre!;sreport$ [exploratpryonlYl Y~$ Y~$ NA NA NA Appr SFD Date 6/1/2004 S~Lsmicanalysis_ Qf shaJlow gas_zpoes -(if off -$ hwe) _D_atapreseoted Qn pote_ntial pveJpres_s~re _zone.s Hydratesa_nd shaJlow gas_are oo_t exp~cted in KBU West Sak w~iJs_ 112 miJe_ to ~ast Expected re$ervoJr J)re_SSUJe Ls] ,9_ _MpJ)g _EMW; wJII thj!; area. Geology Mecha_nica/cpodillon p{ /' P~rmitcao be LS$ued wlo_ hYdrogen_s_ulfide meaS]Jres in Augu$t2003, b~drilled wJth 9.0 ppg mud 31 32 33 34 service welJ onJy) JnGmpt JnGmpJ JoGmpJ JnGmpJ JnGmpt m~a!;uredJess than 7 ppmH2S . Appr Date 8 9 20 21 22 23 24 25 26 27 28 29 30 WQrls will pcc_ur with put BOPEs,_d_o _BOP_Epress JtdJveder req_uired, dQes Jt me~t reguJatioos_ _Drilliog fJuJd_ program schematic_& eq]Jip ratiog appropriate; they meet reguJatioo JnGmpt JnGmpt 10Gmpt nGmpt JtaJe-prilL has_a_ tOA03 fQr abandonJT!e_nt Adeq uate JI\(ellbore !;eparatjo_n _proJ)o!;ep AdequateJankageor re_serye pit Surface knQwn USDW$ _CMT vol adeQ uate to çirc_u Late _ oncood_uctO( & $U_rf_ (;$g _CMT vol adeQuate_ to tie-LnJQng _string to_surf ç¡;g_ CMT will coyer all Casing design$ ade~ua_te fpr C._T" B&_permafr_ost koown -Pfo_ductiye bQrizon_s be~o aPPJQved nGmpt JnGmpt _ca$ing_pJotect!; all nGmpt nGmpt In Engineering . 15-day wait WellJQcat~d within area and_strata authorized by lojectipo in cpmm_ents)_ (For Appr SFD 6/1/2004 Date only affeçted party _S_uffiçient Jfd~viated, js_ weJlbQre plat iocJuded _açreage_ayailable in_dJilliog unjt Well JQcat~d in a d_efioed J)ool WellJQcat~d proper _distance from driJling ~oitb9uodary_ WellJQcat~d prpperdlstance_ from otber wells PTD#: 204091 0 Administration Company CONOCOP : ASKA P~rmit fee atta _Leas~ number _~..'"'. .,....), "_-_ n_am~_and oumb_er 12 13 14 15 16 17 2 3 4 5 6 7 8 9 10 11 Condu_ctor $tringprQvided Ord_er # (put 10# AJI weUs_ withLn J l4_mile _area_of reyiew jd~otified (Fpr !;ervic.e .well ooly>- _ _ Pre-produced injector; J:iuratio_nof pre-J)ropuctioo I~$s than_ 3 months (Forserylce well Qnly) ACMPJ=indingof CQn_sLstency_h_a$ been i!;sued_ forJhi$ pr_oleçt _OJ)erator _OJ)erator P~rmit can be issued wjtbQut P~rmit can be lssu_ed wjtbQut be approved before Can permit bas_appropriate_ bond LnJQrce conservation order _U_n¡que welt Field & Pool ad_mini$tratÌl(e_ apprpvaJ ""nn..nnrir"'O KUPARUK RIVER, WEST SAK OIL INC 490150 Initial ClassfType Yes Y_es _Y~$ Y~$ Y~$ Y~$ Y_e$ Y~$ Y~$ Y~$ Y~$ Yes Yes Yes Y~$ Y~$ NA _ _ Area [njectio_n_Qrder Np._2B ~U :1 E-33,KRU_ tE~~ _ _ WH/be pre~prQd_uçedJO( aþouU Well drilled d___:_{;\:'~ ~'<1! \ j 70'\ \~ - ~? --- Steve Shul~, 6/1J2004. th_an ;300 f~etJroma_ny prpperty CQnseryatipo Ord_er NQminal spacing withio the PQQI isJOacre$. and ADl 02_5660" wbich are cQmmitted_ to Sak F'aJlicipatjngArea,and wH/be JQq¡ted more_ Jioeswhere_ownership change.s._ Neare_st wellwiILbe_-1 ,900 {eetaway. UOit, West Wellwjll theWest SakQiWool ie _entirely withjn_ unJtized State Je_ases_AQL_025651 f'JQ. 406A, KupaJuk_ River Well Name: KUPARUK RIV U WSAK 1E-112 SER I PEND GeoArea 890 Unit 11170 Program SER On/Off Shore On Well Annular Disposal bore seg o o e e Well Histol)' 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 infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. I D / fer **** REEL HEADER **** LDWG 04/10/14 AWS 01 **** TAPE HEADER **** LDWG 04/10/14 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 S. TUFTON F. HERBERT MWD RUN 4 4 D. GONZALES D. GLADDEN # 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 . ~Dt.f-ð7( i J~7S/ lE-112 500292321100 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 14-0CT-04 MWD RUN 2 2 D. GONZALES F. HERBERT MWD RUN 16 11N 10E 95.00 67.00 MWD RUN 3 3 S. TUFTON D. GLADDEN MWD RUN OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 13.375 3031.0 . . # REMARKS: 3RD STRING 12.250 PRODUCTION STRING 8.500 9.625 6926.0 11425.0 Tape Subfile: 1 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE 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' 03.199" LONG: W149 DEG 35' 33.356" LOG MEASURED FROM D.F. AT 95.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ runs 1 and 2 utilized a Gamma Ray Directional service from 108 - 3045 feet MD (108 - 2316 TVD). (2) Baker Hughes INTEQ run 3 utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity, and Gamma Ray services from 3045 - 6933 feet MD (2316 - 3607 TVD). (3) Baker Hughes INTEQ run 4 utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity, Gamma Ray, Caliper, and Modular Annular Pressure (MAP) services from 6933 - 11425 feet MD (3607 - 3597 TVD). REMARKS: (I) Depth of 13 3/8" Casing Shoe - Logger: 3031 feet MD (2311 TVD) Depth of 13 3/8" Casing Shoe - Driller: 3031 feet MD (2311 TVD) (2) Depth of 9 5/8" Casing Shoe - Logger: 6925 feet MD (3605 TVD) Depth of 9 5/8" Casing Shoe - Driller: 6926 feet MD (3606 TVD) (3) This wellbore was sidetrack at 7863 feet MD (3589 TVD) from 1E-112PB1. (4) The interval from 11394 to 11425 feet MD (3599 - 3597 TVD) was not logged due to sensor-bit offset at TD. $ 84 records... Minimum record length: Maximum record length: 8 bytes 132 bytes LDWG .001 **** FILE HEADER **** 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and LDWG File Version 1.000 Extract File: FILEOOl.HED 1 clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ . . .5000 START DEPTH 154.0 STOP DEPTH 11425.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 1R 2 3 MERGE BASE 2130.0 2995.0 6917.0 11425.0 MERGE TOP 154.0 2130.0 2995.0 6917 . 0 MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN le-112 5.xtf LCC 150- CN ConocoPhillips Alaska, Inc. WN lE-112 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ---------------------------------------------------- ODEP GR GR GRAM 0.0 RPD RPD RPD 0.0 RPS RPS RPS 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 CAL CAL CALM 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 RPS MWD 68 1 OHMM 4 4 4 ROP MWD 68 1 FPHR 4 4 5 FET MWD 68 1 HR 4 4 6 MTEM MWD 68 1 DEGF 4 4 7 CAL MWD 68 1 IN 4 4 ------- 28 Total Data Records: 728 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 154.000000 11425.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 772 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: FILEOll.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 154.0 STOP DEPTH 2130.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 27-JUN-04 MSB 18655 8.25 GAM MEMORY 2180.0 . 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 GRAM $ BOTTOM) 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) ROPS - RATE OF PENETRATION (FPHR) TCDM - TEMPERATURE (DEGF) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1e-112.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1E-112 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM ROPS GRAM ROPS 0.0 0.0 GRAM ROPS . 154.0 2130.0 o 0.0 60.5 TOOL NUMBER DHA 6437 SRIG 8017 16.000 108.0 SPUD 9.50 .0 .0 500 .0 .000 .000 .000 .000 78.0 .0 .0 .0 .00 .000 .0 o . . TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 16 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: 63 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 3 Curves: Name Tool Code Samples Units 1 GRAM MWD 68 1 GAPI 2 ROPS MWD 68 1 FPHR 3 TCDM MWD 68 1 DEGF Size Length 4 4 4 4 4 4 ------- 12 Total Data Records: 126 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 154.000000 2130.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 201 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 FI LE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # 3 log header data for each bit run in separate files. lR .2500 . FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 2130.0 $ STOP DEPTH 2995.0 # 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 GRAM $ BOTTOM) 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 1R (MWD Run 2). GR/Dir. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPS - RATE OF PENETRATION (FPHR) TCDM - TEMPERATURE (DEGF) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1e-112.xtf LCC 150 CN ConocoPhìllìps Alaska, I . 28-JUN-04 MSB 18655 8.25 GAM MEMORY 3045.0 2130.0 2995.0 o 60.5 63.5 TOOL NUMBER DHA 6437 SRIG 8017 16.000 108.0 SPUD 9.45 .0 .0 400 .0 .000 .000 .000 .000 78.0 .0 .0 .0 .00 .000 .0 o . . WN FN COUN STAT 1E-112 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM ROPS TCDM GRAM ROPS TCDM GRAM ROPS TCDM 0.0 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 16 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: 63 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 3 Curves: Name Tool Code Samples Units 1 GRAM MWD 68 1 GAP I 2 RaPS MWD 68 1 FPHR 3 TCDM MWD 68 1 DEGF Size Length 4 4 4 4 4 4 ------- 12 Total Data Records: 55 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2130.000000 2995.000000 0.250000 feet **** FILE TRAILER **** Tape Sub file: 4 130 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: FILEOI3.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. 2 .2500 START DEPTH 2995.0 STOP DEPTH 6917.0 # 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): # REMARKS: BIT RUN 2 (MWD Run 3). GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) 02-JUL-04 MSB 18655 8.25 ATK MEMORY 6933.0 2995.0 691 7.0 o 63.5 80.8 TOOL NUMBER ATK 23702 RNT 2058 RNT 2058 12.250 3031. 0 SPUD 9.40 .0 .0 200 .0 .000 .000 .000 .000 120.0 .0 .0 .0 .00 .000 .0 o . . RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-1l2.xtf 150 ConocoPhillips Alaska, I lE-1l2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 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: 28 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 8 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 RACL MWD 68 1 OHMM 4 4 . 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 561 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2995.000000 6917.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 651 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: FILEOI4.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. 3 .2500 START DEPTH 6917 . 0 STOP DEPTH 11425.0 # 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 BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL 08-JUL-04 MSB 18655 6.75 ATK MEMORY 11425.0 6917.0 11425.0 o 80.8 93.8 TOOL NUMBER ATK 17834 RNT 6728 . GRAM $ 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: . RNT 6728 8.500 6926.0 OBM 9.25 .0 .0 46000 .0 .000 .000 .000 .000 132.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3 (MWD Run 4). GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) CALM - ACOUSTIC CALIPER (IN) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN le-112.xtf LCC 150 CN ConocoPhillips Alaska, I WN lE-112 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL GRAM RPD 0.0 0.0 GRAM RPCL . . RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 RaPS RaPS RaPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 CALM CALM CALM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 40 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: 25 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 9 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 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 9 CALM MWD 68 1 IN 4 4 ------- 36 Total Data Records: 722 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6917.000000 11425.000000 0.250000 feet **** FILE TRAILER **** Tape Sub file: 6 814 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/10/14 01 ~ "" **** REEL TRAILER **** LDWG 04/10/14 AWS 01 Tape Subfile: 7 Minimum record length: Maximum record length: . . 2 records... 132 bytes 132 bytes