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204-155
STATE OF ALASKA • AOKA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon f Plug Perforations E Fracture Stimulate r Pull Tubing r Operations Shutdown Performed: Suspend 1- Perforate IT Other Stimulate IT Alter Casing r Change Approved Program Plug for Redd!!r Perforate New Pool nRepair Well I Re-enter Susp Well Other:Crystal Seal MBE TreetmnF 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory I 204-I65 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service ® 50-029-23220-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651,25660 KRU 1E-166L2 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 9417 feet Plugs(measured) None true vertical 3259 feet Junk(measured) None Effective Depth measured 9400 feet Packer(measured) 0 true vertical 3259 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108 108 0 0 SURFACE 2982 10.75 3012 2393 0 0 INTERMEDIATE 5987 7.625 6014 3502 0 0 D-SAND LINER 4606 4.5 9402 3256 0 0 0 0 0 Q. 0 0 Perforation depth: Measured depth: 4822-9363 True Vertical Depth: 3286-3259 y� RECEIVED Tubing(size,grade,MD,and ND) 4.5, L80,4712 MD, 3256 TVD SCANNED "..;. 1 j ,,,°r FEB 1 7 2015 Packers&SSSV(type,MD,and ND) PACKERS: N/A AOGCC NIPPLE-Camco 4 1/2"X 3.875 "DB"Nipple @ 509 MD and 508 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pregsure Prior to well operation shut-in - - - - Subsequent to operation shut-in - - - - l 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory IT Development F Service f Stratigraphic Copies of Logs and Surveys Run r' 16.Well Status after work: Oil F Gas IT WDSPL 1"- Printed Printed and Electronic Fracture Stimulation Data r GSTOR WINJ r WAG GINJ IT SUSP I- SPLUG I- 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-426 Contact John Peirce as 265-6471 Email John.W.PeirceOconocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature Phone:265-6471 Date 2/16/1. Form 10-404 Revised 5/20 5 k72- Z11511jRBDMS �. FEBSubmit Original Only 741 8 1016 KUPD dik 1E-166L2 ConocoPhiiiips rliAlg Well Attribu Max AngINPED TD AIE:LTket,int::. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(kKB) CarwooDhip9ps 500292322061 WEST SAK PROD 92.76 6,556.43 9,417.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date 1E-166L2,2/16/20168:W:49 AM SSSV:NIPPLE 120 8/24/2012 Last WO: 2/9/2009 35.29 9/24/2004 Verbal schematic(antual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW osborl 10/23/2013 II1 Casing Strings ; I. Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) 'Set Depth(ND)... WtJLen(I...Grade Top Thread • iili— it' D SAND LINER I 4121 3.9581 4,795.71 9,402.01 3,258.81 12601 L-80 IDWC ■[w° , Liner Details """�""".'."""HANGER;22.0' l .,:: Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Corn (in) IF : ) 'iti 4,795 71 3,279.8 74.49 HANGER BAKER B-1 FLANGED HOOK HANGER 4.500 Perforations&Slots CONDUCTOR;30.0-108.0-4 Shot Den Top(ND) Btm(TVD) (shots/ 111 Top(kKB) Otto(ftKB) (ROB) (ftKB) Zone Date ft) Type Cole 4,822.0 9,363.0 3,286.2 3,259.2 WS D,1E- 9/22/2004 32.0 SLOTS Slotted Liner,32 spf NIPPLE;509.1 .1 166L2 2.5"Lx.125'W,4 • circumferential rows HEAT TRACE;22.0 Notes:General&Safety End Date Annotation 9/24/2004 NOTE:TRI-LATERAL WELL:1E-166(A-SAND),1E-166L1(B-SAND),1E-166L2(D-SAND) 11/17/2005 NOTE:WORKOVER TO RECONNECT ESP CABLE-NO OTHER CHANGES 2/17/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 2/17/2009 NOTE:WORKOVER TO CONVERT FROM ESP TO GAS LIFT SURFACE,29.8-3,012.0 GAS LIFT;3,029.2 GAS LIFT;4,542.7 f 111 II 4 NIPPLE;4,624.6 III GAUGE;4,632.0 ice iii ill LOCATOR,4,684.8 In III a 14a! SEAL ASSY;4,693.9 1Wr1 Il di r 1 11 D-SAND WINDOW,4,799.0- 4,811 0 -4,811.0 1 Vii. li , I INTERMEDIATE;26 9-6,014.0 0-SAND LINER LEM,4,676.5- 5,034.0 SLOTS;4,822.0-9,383.0 1 ,....... D-SAND LINER;4,795.75,402.0 Well History 1E-119 500292319800 Page 1 of 3 • • lips ' �' P111 Well History 1E-119 : 500292319800 : 2/16/2016 Date Event 02/11/2016 INJECTIVITY TEST 1E-119, PUMP 30 BBL DIESEL DOWN TBG DNE 1000PSI AND .75 BPM START PUMPING, RATE @ .75 BPM TBG PSI= 1000, PUMPED 30 BBLS SHUT DOWN PUMP, RATE @ .75 BPM, TBG PSI=600 JOB COMPLETE 10/15/2015 LOGGED 24 ARM CALIPER FROM TUBING TAIL @ 6135' TO SURFACE. LOG CORRELATED TO TUBING TALLY DATED 13-APR-2004. JOB COMPLETE. 09/29/2015 PUMPED 30 BBLS OF DSL DOWN TBG FOR INJECTIVETY TEST JOB COMPLETE 09/19/2015 PUMPED FULLBORE MBE TREATMENT PLACING 275 BBLS 3%KCL, 36 SW w/ 1-2-4 & 4 MIL CRYSTAL SEAL (495# 124 & 2695#4 mil, 3190#s total) SURRY INTO FORMATION. WELLFREEZE PROTECTED W/35 DIESEL.Note: Do not bring well back on injection or offset producer 1E-166 on prod until after 20:00, 9/20. 09/17/2015 INJECTIVITY TEST W/S/W PUMPED 56 BBL @ 1BPM PUMPED 10 BBL @ 1.5BPM PUMPED 10 BBL@ 2BPM FREEZE PROTECT TBG WITH 33 BBL OF DIESEL JOB COMPLETE 09/09/2015 TAGGED FILL @ 6564' SLM—299' FILL. MEASURED BHP @ 6559' RKB. JOB COMPLETE 06/07/2015 FREEZE PROTECT F/L W/ 5 BBLS METHANOL FREEZE PROTECT TUBING W/ 3 BBLS METHANOL, FOLLOWED BY 30 BBLS DIESEL JOB COMPLETE 06/06/2015 MEASURE INJECTION TEMPERATURE SURVEY @ 6400', 6540', & 6583' RKB. JOB COMPLETE 06/02/2015 TAG FILL @ 6564' SLM(EST. 289' FILL); MEASURED BHP @ 6579' RKB (994 PSI). JOB COMPLETE. 05/27/2015 FREEZE PROTECT F/L WITH 3 BBLS METH FREEZE PROTECT TBG WITH 30 BBLS DIESEL JOB COMPLETE 07/12/2014 BAILED FILL/ SCHMOO FROM 6383'- 6475' SLM. PERFS: 6454' - 6872' RKB. MEASURED BHP @ 6470' RKB: 1741 PSI. COMPLETE. 08/25/2011 08/25/2010 LOG STATIC PRESSURE/TEMPERATURE SURVEY TO 6585'. 30 MIN STOP AT 6585', PRESSURE WAS 1765 PSI AT 76 DEG. 15 MIN STOP AT 4100', PRESSURE WAS 1287 PSI AT 62 DEG . 15 MIN STOP AT 2000', PRESSURE WAS 971 PSI AT 59 DEG. TOOLS WERE UNABLE TO FALL PAST 6700' 02/23/2010 TAGGED @ 6858' SLM, EST. 6881' RKB. READY FOR E/L. 01/23/2009 INJECTION PROFILE. RATE: 430 BWPD, 830 PSI, 139 DEGF. 30% OF FLUID ENTERING D SAND AT 6454'-6524'. 70% OF FLUID ENTERING B SAND AT 6562'-6614'. 0% OF FLUID ENTERING A SANDS. DID NOT SHUT IN WELL. DID NOT TAG TD. FLOWING BOTTOMHOLE PRESSURE WAS 2400 PSI. 08/22/2008 07/03/2008 http://akapps.conocophillips.net/WebBert/Well/Report/rptWellTable.aspx?REPORT=..%2... 2/16/2016 IP OF T��(-----,��/3s7 THE STATE Alaska Oil and Gas _���, f jL JSJ�T /�, Conservation Commission - _= = J X1`1 .•iticier#_=== - 333 West Seventh Avenue \Tti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 OF ALAS Fax: 907.276 7542 ���V AI_I :1 I 0,� �4 www.aogcc.alaska.gov S John Peirce 13- Sr. Wells Engineer pC 1/46. ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-166L2 Sundry Number: 315-426 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /320-c----d.--.. alet Cathy7 Foerster � - Chair DATED this 2T day of July, 2015 Encl. STATE OF ALASKA ' 3KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing r Operations Shutdow n I-- Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other Crystal Seal MBE Treatment P• 2 Operator Name: 4 Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc.• Exploratory r Development r,,'. 204-155 - 3.Address. r- 6.API Number. Stratigraphic r Service P.O. Box 100360,Anchorage,Alaska 99510 50-029-23220-61 7.If perforating, 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception'? Yes r No 17 I KRU 1E-166L2 ' 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). 94171 3259 - 9400' _ 3259' - none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108' 108' SURFACE 2982 10.75 3012' 2393' INTERMEDIATE 5986 7.625 6014' 3502' RECEIVED D-SAND LINER 4606 4 5 9402' 3258' JUL 142015 7, 24115 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft)• Tubing Size. Tubing Grade: Tubing MD(ft): slotted liner from 4822-9363• 3286-3259 4.5 L80 4712 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no Packer in this lateral NIPPLE-CAMCO"DB"NIPPLE MD=509 TVD=508 12.Attachments: Description Surrmary of Proposal C✓ 13. Well Class after proposed work. Detailed Operations Program r BOP Sketch I`" Exploratory r Stratigraphic r Development • Service r 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work 7/29/2015 _ OIL f • VVINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. John Peirce @ 265-6471 Email. John W.Peirce@conocophillips.com Printed Name John Peirce Title: Sr. Wells Engineer Signature s ,L — Phone 265-6471 Date 7/i?/i 7 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 316-- L/24 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No [/ Subsequent Form Required. /L — 4 p APPROVED BY _ Approved by. ;¢t .7 COMMISSIONER THE COMMISSION Date. 7-2-I-/5 1 i -7 A roved aIt ti t v Id or 12onths tr m_the date of approval. 1 PP 0 RPI �Q/ _ Submit Form and Form 10-403 Revised 5/2015 � 7��! � Attachments'n Duplicate �� RBDMSJ AUG - 2 2015 t KUP PROD 1E-166L2 • CC111QCA ilhi?S - Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(') MD(ftKB) Act Btm(ftKB) t:nrloaollglips 500292322061 WEST SAK PROD 92.76 6,556.43 9,417.0 Ir ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) `Rig Release Date 1E-166L2,102320131:34.01 PM SSSV:NIPPLE 120 8/24/2012 Last WO: 2/9/2009 35.29 9/24/2004 Vortical schemahc(actua0 Annott Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW osborl 1023/2013 lir. Casing Strings 1.1:t Casing Deserlpdon OD(in) ID mel Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WOLen(I...GI_ Top Thread D-SAND LINER 4 1/2 3.958 4795.7 9,402.0 3,258.8 12.60 L-80 DWC r-L___ v Liner Details Top( Nominal ID kF RKB) Top(TVD)(RKB) Top Incl(°) Item Des Com (in) 1analmmeuauaueM HANGER:22.o> 1aa1t I,—'. uea 4,795.7 3,279.8' 74.49 HANGER BAKER B-1 FLANGED HOOK HANGER 4.500 x - I Perforations&Slots Shot CONDUCTOR.30.0-1080Dens Top(TVD) BtmKB) (shots/f6 Top(RKB) etm(RKB) (RKB) (RKB) Zone Dara 0 Type Com 4,822.0 9,363.0 3,286.2 3,259.2 WS D,1E- 9/22/2004 32.0 SLOTS Slotted Liner,32 spf 166L2 2.5"Lx.125"W,4 NIPPLE;509.1 yl-ri circumferential rows HEAT TRACE.22.0 . Notes:General&Safety End Date Annotation 9/24/2004 NOTE:TRI-LATERAL WELL:10-166(A-SAND) 1E-166L1(B-SAND),1E-166L2(DSAND) 11/17/2005 NOTE:WORKOVER TO RECONNECT ESP CABLE-NO OTHER CHANGES 2/17/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 V2/17/2009 NOTE:WORKOVER TO CONVERT FROM ESP TO GAS LIFT SURFACE.29 8-3,012.0—• 4. GAS LIFT;3.029.2 GAS LIFT,4,542.7 NIPPLE;4,624.6 " al GAUGE;4,6320 A I- LOCATOR;4,684.8 ' It) SEAL ASSY,4.693.9 i II sem ems D-SAND WINDOW;4.799.0- 4,811.0 INTERMEDIATE;26.96.014.0 D-BAND LINER LEM,4.676.5-1 .*e 5.034.0 r SLOTS,4,822.0-9,363.0�_,.. 1 r_ T i D-SAND LINER:4,795.7- I I 9,402.0 1E-119 D MBE to 1E-166 Crystal Seal Treatment Proposal An MBE occurred between 1E-119 vertical injector and the offset 1 E-166 tri-lateral producer on 5-27-15. A SL tag was attained in 1E-119 on 6-2-15 at 6583' RKB (289' fill), and a SBHP was taken at 6579' RKB (3305' TVD) = 994 psi (EMW - 5.8 ppg). A 6-6-15 Flowing Temp Survey in 1E-119 confirms the D sand perfs at 6454 - 6524' RKB act as a thief zone due to a D MBE communicating with 1E-166. A 1E-166 well test on 5-27-15 shows a sudden high spike in watercut from 35% to 95% (1515 BWPD). 1E-119 has been SI since 5-27-15 due to the D MBE. Per this procedure, the D MBE will be sealed off by fullbore pumping Crystal Seal down 1E-119. This will enable the return of 1E-119 to PWI service to the West Sak A, B, and D sand ASAP. Procedure: Pumping 1. FB Step Rate Injection Test with Seawater at 0.5 to 1.5 bpm to verify good injectivity. 2. FB Crystal Seal treatment to seal the D sand MBE. Initiate pumping with 56 bbls Seawater down tubing to determine optimal steady rate to pump Crystal Seal slurry. Immediately after Seawater pumping and constant pump rate determination, continue pumping 3% KCL water with 0.05 ppg of 4 mm Crystal Seal down tubing at the established rate. Volume of this stage (and all subsequent stages) is TBD during pumping based on treating pressure responses seen during pumping. Ramp stages as they are called at: 0.10, 0.15, 0.20 and 0.25 ppg (4 mm Crystal Seal) at the established rate, else swap to pumping Flush when signs of a screen out development are seen. If screenout development is noted, attempt to pump 55 bbls of Diesel Flush down tubing to displace all the Crystal Seal from the tubing to the MBE. Underdisplace Crystal Seal from the tubing by -1 barrel to leave the D MBE entirely sealed with Crystal Seal to the wellbore. If screenout has not been seen, but it is time to call Flush, pump 55 bbls of Diesel to displace Crystal Seal from the tubing at stable established rate, then SD. RD. Coil Tubing: 3) RIH with Jet Swirl Nozzle to perform a Crystal Seal & fill cleanout. Perform cleanout jetting Seawater with FR to as deep as possible. FP well with 28 bbls Diesel. RD CTU. E-line (optional): 4) Perform an IPROF to verify that the D MBE has been sealed off. Return 1E-119 to PWI. Obtain well tests at 1E-166 producer to verify watercut trends as key indicator for presence of an open MBE, or not. JWP 7/13/2015 · . 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. ~Q Lt - L..5.~ Well History File Identifier Organizing (done) D Two-sided 111111111111111111I D Rescan Needed 11111111I11" 111111 RES CAN DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: 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} I //3/ ob I I 151 mP Scanning Preparation 11111111111111 "III Date: ¡(I, ð It) (;; 151 tWP I I I 3 Ô + --.1!L = TOTAL PAGES~ / (Count does not include cover sheet) l) Date: lO 151 Ir 11111111111111 "III Project Proofing BY: ÇMaria) BY: Production Scanning BY: Page Count from Scanned File: 50 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ¿ YES ~ Date: II/Ia/ lJ0 Stage 1 If NO in stage 1, page(s) discrepancies were found: NO Stage 1 YES 151 ~ NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111I11 "III BY: Maria Date: 151 Comments about this file: Quality Checked 111111111111111111I 10/6/2005 Well History File Cover Page.doc ~ .. ' • • r • s ~onacoPh~ll~ps October 20, 2009 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Ancharage, 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 Fax:659-7314 ~~~Le.~ V~ ~~ ~CT l :~ ZfJ~~ ~~es~Ca ~ii ~ G~s ~ons. ~onr~n~sxion Anchor~ge~ Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has set a blanking sleeve in the D Lateral Entry Module (LEM) of a West Sak multilateral injection well. Enclosed you will find 10-404 Report of Sundry Well Qperation for ConocoPhillips Alaska, Inc. for 1E-166 (PTD 204-153) and 1E-166L2 ~PTD 204-155). This report records the setting of the D-LEM isolation sleeve in the L2 lateral water injection well. If you have any questions regarding this matter, please contact myself or Bob Christensen at 659-7535. Sincerely, ~ -<!, 9 ~, , r , Darrell R. Humphrey Attachments II . ~~~~~~~~ , • ' • • ~ C I ~ P3 2QQ9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~s~~ ~~~ ~~~~ ~d~s, (;o~pjSS10~ REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other ^~ Set D Sand ISO Alter Casing ^ Pull Tubing ^ Perforate New Pooi ~ Waiver ^ Time Extension ^ Steeve Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter uspended Well ^ 2. Operator Name: 4. Current Well Status: . Permit to Drill Number: ConocoPhillips Alaska, It1C. Development ^~ Exploratory ^ 204-155 3. Address: Stratigraphic ^ Service ^ API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23220-61 KB Elevation (ft}: Well Name and Number: RKB 28' 1 E-166L2 Property Designation: 0. Field/Pool(s): ADL 25651 & 25660 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: ~ Total Depth measured 9417' ~ feet true vertical 3259' feet Plugs (measured) 4799' Effective Depth measured 9400' feet Junk (measured) NONE true vertical 3259' feet Casing Length Size MD ND Burst Collapse CONDUCTOR 80' 20" 108' 108' SURFACE 2982.15' 10-3/4" 3012' 2392' INTERMEDIATE 4803.14' 7-5/8" 4830' 3500' D-SAND LINER 4606' 4-1/2" 9402' 3259' Perforation depth: Measured depth: 4822-9363` true vertical depth: 3284-3259 Tubing (size, grade, and measured depth) 4-1/2", L80, 4712' MD. Packers & SSSV (type & measured depth) NONE N/A SSSV= NIPPLE 5321' 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 Pressu[e Prior to well operation 1209 533 942 783 221 Subsequent to operation 1118 627 1155 757 233 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: OilO 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 B. Christensen/ D. Humphrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659-7535 Date ~~-2a,U Form 10-404 Revised 04/2004 ~~~~.s ~ ~~~ (~ ~. ~~.Z3. ~ Submit Originaf Only • ~ 1 E-166L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/11/09 SET BAKER TYPE 2 ISOLATION SLEEVE @ 4799' RKB ISOLATING THE D SAND. RIH W/ 3.65" X 19' TYPE 2 ISO SLEEVE (COLLETS ARE 3.86" AND WILL COLLAPSE TO 'GO THROUGH 3.81" NIPPLE @ 4624' RKB) IWT CK @ 4550' CTMD= 7000#. RIH WT -1500 @ 30 FPM. TAG UP @ 4822' CTMD-PULL 2000# OVER SLACK OFF. ON LINE DOWN COIL W/ SLICK DIESEL @ 1.3 BPM CTP 2000# WHP 550 WORK HIPP TRIPPER WHILE EASING DOWN-WORK FOR SEVERAL MINUTES UNTIL STALL. DO A 2500# OVER PULL-PUMP OFF-POOH. , , ` ~., ' Cor~ocoPhillips ~. ~~ KUP 1 E-166L2 SSSV: NIPPLE 0 8/18/2008 Last WO: Z9/2009 3529 924/2004 Annotatlon DepN (ftl(0) End OaEa Annotation Last Mod ... EnG ~ate Last Tag: Rev Reason: SET I50 SLEEVE IN 0.LEM Imos bor 10/11/2009 Casin Strin s Caeing ~eacrlptlon String 0. .. String ID .. . Top (ftNB) S et Dapth (f... S et Depth ~TVO) ... String Wt... String ... String Top T~rC 0.SAND LINER 4 1/2 3.958 4,795.7 9,402.0 3,258.8 72.60 L-80 DWC Llner Detalls Top Depth (TVD) Toplncl Too Iftl(BI (RNB) (°J Imm Dascriotbn Commant ID Ilnl Comment 32 spf 2.; Iravs NIPPLE. HEAT TRi GP.S LIFT, GAS GAUGE, LOCATOR, a,sas SEALASSY. a wa D-SAND 0-SAND LINER, 1.I969.C02 TD (1 E-166L2), 9,417 Velw I Latch I S~ZO ITRO Run S ' • • w STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS, ~~ SAY ~ ~ ZGCI~ 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ e f ~ (fit ~~~~~~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ ~~ r Waiver ^ Time Extensio~~~4 I}8 Slewe Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConOCOPhilllps Alaska, InC. Development^ Exploratory ^ 204-155 -. 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23220-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' • 1 E-166L2 ^ 8. Property Designation: 10. Field/Pool(s): ADL 25651 & 25660 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 9417' feet true vertical 3259" feet Plugs (measured) NONE Effective Depth measured 9400' . feet Junk (measured) NONE true vertical 3259' ` feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 20" 108' 108' SURFACE 2982.15' 10-3/4" 3012' 2392' INTERMEDIATE 4803.14' 7-5/8" 4830' 3500' D-SAND LINER 4606' 4-1/2" 9402' 3259' Perforation depth: Measured depth: 4822-9363' true vertical depth: 3284-3259 Tubing (size, grade, and measured depth) 4-1/2", L80, 4712' MD. Packers &SSSV (type & measured depth) NONE NIA SSSV= NIPPLE 5321' 12. Stimulation or cement squeeze summary: "~ z'.-~l~~ ~~ ~~~ Q ~~0~ 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 713 497 819 996 175 Subsequent to operation 130 62 140 50 204 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 ' Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A contact B. Christensen/ D. Humphrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659-7535 Date - `•,Z-~ ~z ~ ~ ,~,~ •~ r ~ M / f ~ a ~ a !`~ 6l~ Form 10-404 Revised 04/2004 ~ ~ ~ ~~ ~ j ~ ~ / ~ ~~ ~~ S" ubmit Original Only Page 1 of 1 • Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139@conocophillips.com] Sent: Friday, May 08, 2009 9:14 AM To: Maunder, Thomas E (DOA) Subject:"~E: 1 E-166 (204-153), et al Tom -Only the B sand was isolated on this wel-. I will be faxing you some tech /sales info on the ISO sleeve. As far as no ing new wi ese. ey are the same type we have been using for some time. The tech /sales info should tell you the length. All I know at this point is that it was set at 5067' MD. Darrell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 06, 2009 5:17 PM To: NSK Prod Engr Specialist Subject: 1E-166 (204-153), et al Darrel and Bob, I am reviewing the 404 for the installation of the B sand isolation sleeve. Was only the B sand isolated or did this also isolate the A sand? Do you more specifics on the "Type 1 sleeve"? Top and bottom measured depths would be appreciated. Call or message with any questions. Tom Maunder, PE AOGCC 5/19/2009 • • Well Date Event Descri tion 1 E-166 1/2/09 (PRE -RWO) T PPPOT -PASSED. T POT -PASSED. IC PPPOT -PASSED. IC POT ~ - PASSED. UPPER BODY SEAL PPPOT -PASSED. UPPER BODY SEAL POT - ~ PASSED. LOWER BODY SEAL PPPOT -PASSED. LOWER BODY SEAL POT - w FAILED. LDS FUNCTION TEST -PASSED. a 1E-166 2/5!09 Nordic Rig 3 accepted onto 1E-166 on 2-5-2009 @ 09:00 am. RU hardline, bermed up cellar, pulled BPV, RU circ lines, loaded pit's with 8.8ppg seawater/KCL, tested hardline, loaded ESP spooler, killed weal, .installed BPV, ND tree, installed test dart, NU BOP, RU and started BOP test. 1E-166 216109 Cont BOP test, RD test equipment, pull test dart and BPV, ir~~~tali i~o-sleeve, MU landing jnt and circ hose, BOLD's and pull hanger to rig flc~r, fltash IA ~ with 150 bbls hot seawater, POOH stand back 4 1J2° tbg ar~d strap i;n derrick, MU and RIH with lateral wash tools, cleanout to 5,046', POQH to Y 264`. ~ O 1E-166 2f7/09 POOH LD cleanout assembly, MU seal assembly dummy run, RIH to 5,046°, ~ POOH, MU and RIH with LEM assembly to 4,774' ~ 1E-166 218!09 Orient and latch LEM in place, set ZXP, test 7 5J8" csg x ZXP for 5 minutes, M monitor well, pull setting tools out of ZXP, POOH LD 3 1/2" DP, RU and run 4 0 1/2" gas lift completion to 3,992'. ~ 1E-166 219/09 Locate SBE, confirm seals in place, space out, drop ball/rod down tbg, MU Z hanger and landing jnt, make final splices, pump 150 bbls inhibited seawater/KCL down IA, land hanger, test tbg x IA, shear SOV, install BPV, ND/NU, freeze protect well, allow to u-tube. 1E-166 2110109 Install BPV, secure well, install guages on tree, blow down all lines, break down hard line, clean out pits, RDMO well 1E-166, clean out cellar box, mov rig off 1E Pad. 1 E-166 2/14/09 PULLED B&R, RHC @ 4625' RKB. PULLED SOV AND SET 1" OV(PORT=5/16") @ 4542' RKB. PULLED DMY AND SET 1" GLV(PORT=3/16" TRO=1494) @ 3029' RKB. ~ ~ COMPLETE. ~ O a ' ~ 1 E-166L2 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/21/09 INSTALL A TYPE 1 ISOLATION SLEEVE INTO THE B-SAND LEM @ 5067' CTMD. *Vetco Grey Hanger, 11" X 4-1/2"'Conductor, 20" X 34" Insulated, set at 108' MD. Tubing String: 4-1 /2" 12.6#, L-80, IBTM 509' MD - 3.875" DB Nipple 3029' MD -GLM, Camco 4-1/2" X 1" KBG-2-1R 4543' MD -GLM, Camco 4-112" X 1" KBG-2-1R //" ~ 4625' MD - 3.812" DB Nipple 4632' MD -Guardian Gauge Carrier Heat Trace Cable to 3024' MD 10-3/4" Casing Shoe, 45.5/40.5#, L-80, BTC set 3012' MD, 2393' TVD 4796' MD - 4-1/2" X 7-5/8" Model 'B' HOOK Hanaer 4752' MD - 3.75" DB Nipple ConocoPhillips West Sak 1 E-166 Producer Tri-Lateral Completion 'D' Sand Lateral 4788' MD -Lateral Entry Module (LEM) Orienting Profile ~166L2: D-sand Window at +/- 4799' MD, 72 deg 3-1/2" bent joint and guide ~~ 4-1/2" 12.6# slotted and blank liner shoe 5010' MD - 5-1/2" X 7-5/8" ZXP Liner Top Packer w/ Hold Downs Lateral Entrv Module (LEM) Assembly 5-1/2 X 7-518 ZXP Liner Top Packer wl Hold Downs _ Casing Sealbore Receptacle - 4.75" ID f Tubing Swivel, 4-1/2" ~ Orienting Profile Positive Latching '' Collet '- Seal Bore for Lateral Isolation - 3.68" ID ~~ Access Window Positive Lateral Access Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 5030' MD-Casing ` Sealbore Receptacle ``~~~ 5063' MD - 4-1/2" X 7-5/8" Model 'B' HOOK Hanaer 1E-166L2: 3-1/2" Liner Shoe @ 9402' MD, 3258' TVD MD -Bottom of Seal Assembly 4.75" Seal OD 5057' MD -Lateral Entry Module (LEM) Orienting Profile 'B' Sand Lateral RWO 09 F~nNi1R1Es Bakcr Oil Tnnls As Completed Latera With D l Entrv Module (LEMI iverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running 7001 String Installed Installed (2.50" ID Mainbore Drih) " Lateral Drih) 17.00 'GS' Profile for Coil Connector ~ Running/ReMeving ~~ (1.00' Length) Snap InlSnap Out Poskive locating--- Back Pressure Valve cDnet (1.60' LengPo) Lateral Isolation ~~ r Flow-Thru Swivel Seals (135' Length) ~ Lateral Diverter ~ I - Hydraulic ~ Ramp '~ Disconnect Isolafian/ Mainbore'" ~ (1.80' Length) Diverter Skeve I _,-- GS Spear (7.80' Length) ~ Lateral Isolation'- ~ _ 6 .88ft Approx. Seals ', OAL' 'Jars may be required in highly deviated or deep applications 16' approa length). 18.5' Diverter Length 18.5' Sleeve LengM r`-~ ' 166L1: B-sand Window at +l- 5068' MD, 82 deg ' 3-112" bent joint and guide 4-1/2" 12.6# slotted and blank liner shoe 5128' MD - 3.562" DB Nipple 5-1/2" X 7-518" ZXP Liner Top Packer with " Hold Downs \ 5-1/2" X 7-518" Flex Lock ~ Liner Hanger I Packer ~ - Assembly Top at ~. Liner Hanger +/- 5302' MD ~- 5335' MD-Casing Sealbore Receptacle Baker Hughez 20aa. Thi> document may net be reproduced or diztrlbuktl, in wNOk or in pail, in any 1^rm nr by any means elmtronic or mechanical, including pholocopYi^9~ recortling, or by any inl^rmadon rtwage and retrieval >yakm now known or hereaNer invmlM, wiMOUI wdttm permi>aion hom 9aker Hughe> Inc. 'A' Sand Undulatina Lateral Eauipment Specifications 4-1/2" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.68" LaterallMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.89" Diverter and Sleeve Length: +l- 18.5' 4-112" 12.6# slotted and blank liner Casing, 7-5/8" 29.7#, L-80, BTCM, Set @ +/- 6014' MD, 3502' TVD. 1E-166: 4-112" Liner shoe @ 9596' MD, 3518' TVD 200 - 7 E-166 Tnaalerol Completbn -Producer Drawn By: Revision NO: RWO Completed January J0, 2009 Ian Toomey ;.4677' MD - 5-1/2" X 7-5/8" ZXP Liner Top Packer w/Hold Downs A696' MD -Casing Sealbore Receptacle 4.75" ID .4712' MD -Bottom of Seal Assembly 4.75" Seal OD 1 E-166L1: 3-1/2" Liner shoe @ 9380' MD, 3329' TVD 5346' MD -Bottom of Seal Assembly 4.75" Seal OD ConocoPhillips Al~t~w.i. h t, KUP ~ 1 E-166L2 Well Attributes Max An le & MD TD Wellbore API/UWI 500292322061 Fieltl Name Well Sbtua Protlllnl Type WEST SAK PROD Incl (°) 92.76 MD (RNB) 6,556 Act Btm IRxBI 9,417 Comment HIS Ippm) Date Annotation SSSV: NIPPLE Last WO: Eno Data KB13rtl (/[) 2/9/2009 35.29 Rlg Release Dab 9/24/2004 Annotation Depth IRKB) Last Tag: Entl Dab Annotation Rev Reason: Workover, Pull RHC Ball/Rod, GLV C/O Entl Data 2/17/2009 Casin Strin s Casing Description String 0... 3lring ID ... Top (FtN B) Sel Depth It... Sel Oepth (TVD) ... String Wt... String .. String Top Thrtl D-SAND LINER 4 1/2 3.958 4,796 9,402 3,258.8 12.60 L-80 DWC Liner Details Top IRKS) Top Depth (TVD) IRKB) Top loci (°) I bm Description Comment ID Iin) 4,796 3,279.8 74.49 H ANGER BAKER B-1 FLANGED HOOK HANGER 4.500 Pertorations & Slots Top (rtNB) Btm (RNB) Top ITVD) IRKB) Btm (TVD) IRKB) Zone Data snot Dens Ish... Type Comment 4,822 9,363 3,284.5 3,259.2 WS D, 1 E-166L2 9/22/2004 32.0 Slots Slotted Liner, 32 spf 2.5"Lx.125"W, 4 circumferential rows Notes: General 8 Safe Entl Date Annotation 9/24/2004 NOTE: TRI-LATERAL WELL: tE-166(ASAND), 1E-166L1(B-SAND), 1E-166L2(DSAND) 11/17/2005 NOTE: WORKOVER TO RECONNECT ESP CABLE - NO OTHER CHANGES 2/17/2009 NOTE: WORKOVER TO CONVERT FROM ESP TO GAS LIFT 2/17/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details Stn Top I~BI Top Depth ITVD) I~BI Top Incl (°) Maks Motlel OD (lnl Serv Valve TYPe Latch TYPe Port Blze Iinl TRO Run (Pal) Run Date Comm... 1 3,029 2,403.7 48.13 Camco KBG-2-1R 1 GAS LIFT GW BK 0.188 1,494.0 2/14/2009 2 4.543 3,194.6 66.08 Camco ~ KBG-2-1R 1 GAS LIFT OV BK 0.313 0.0 2/14/2009 Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Wednesday, March 25, 2009 8:59 AM To: Maunder, Thomas E (DOA) Subject: RE: I~'6~-a53)~ ~~"t~~ ~~ ~~ R~~~ Attachments: 1 E-166 Addendum to 10-404.pdf Tom, Page 1 of 1 Attached is the pre and post rig work summaries and a better schematic. I only included the pre-rig work relevant to the workover. Let me know if you'd like more detail. Thanks, Bretc ~Pac~ ~DrilC`ng eZ `WeUs 'Wor~ver~Engineer ~~'~~ NEAR ~= ~ ~t~C 'Work# (907) 265-6845 Cell# (907 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Saturday, March 21, 2009 3:06 PM To: Packer, Brett B Subject: 1E-166 (204-153) Bret, I am reviewing the 404 for the recent workover on this well and have some requests. 1. Please send a copy of the pre and post rig work. 2. Since this well is a multilateral, the "straight" drawing is a little confusing. Can you provide a simple drawing such as provided with the PTD application that illustrates the total 1E-166? Thanks in advance. Email is fine. Tom Maunder, PE AOGCC 3/25/2009 . ~ ~nn9 STATE OF ALASKA ~A~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION tF a®mt'f1tSStQt~ REPORT OF SUNDRY WELL OPE ~d~ "~ng. 1. operations Performed: Abandon ^ Repair Well 0 Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ~ 'Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhlllips Alaska, InC. Development 0 Exploratory ^ 204-155 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23220-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1 E-166L2 8. Property Designation: 10. Field/Pool(s): ADL 25651, 25660 Kuparuk River Field !West Sak Oil Pool • 11. Present Well Condition Summary: Total Depth measured 9417' feet true vertical 3259' feet Plugs (measured) Effective Depth measured 9400' feet Junk (measured) true vertical 3259' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 2984' 10-3/4" 3012' 2393' INTERMEDIATE 5986' 7-5/8" 6014' 3502' D-SAND LINER 4607' 4.5" 9402' 3258' Perforation depth: Measured depth: slots from 4822'-9363' true vertical depth: 3286'-3259' Tubing (size, grade, and measured depth) tubing in main wetlbore, L-80, 4712' MD. Packers & SSSV (type & measured depth) no packer Camco'DS' nipple @ 509' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable 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 SI -- Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ° Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Brett Packer @ 265-6845 Printed Name Brett Packer 5 ~ Title Ph 265 6845 Wells Engineer) D t ~/`~/~ ~, 7 Signature ~ii v ~ one: - a e Pre are Sharon All u Drake 263-4612 Form 10-404 Revised 04/20(}@` ~ ~ `ti- ~ E ~ _. ~ e Submit Ori inaZl O y a b.,.,> I.~ ~FC f,~~Ci ~ ~ f ~~Q J~~l ~/ aVetco Gray Hanger, 11" X 4-1/2"'Conductor, 20" X 34"Insulated, set at 108' MD. Tubing String: 4-112" 12.6#, L-80, IBTM 509' MD - 3.875" DB Nipple 3029' MD -GLM, Camco 4-1/2" X 1" KBG-2-1R 4543' MD -GLM, Camco 4-1/2" X 1" KBG-2-1R ~~ ; i~ 4625' MD - 3.812" DB Nipple k\ ~ 4632' MD -Guardian Gauge Carrier Heat Trace I to 3024' MD MD - 5-1/2" X 7-5l8" ZXP Liner Top Packer w/ Hold Downs ~6' MD -Casing Sealbore Receptacle 4.75" ID 4712' MD -Bottom of Seal Assembly 4.75" Seal OD 10-314" Casing Shoe, 45.5/40.5#, L-80, BTC set @ 3012' MD, 2393' TVD 4796' MD - 4-1/2" X 7-5/8" Model'B' HOOK Hanger 4752' MD - 3.75" DB Nipple conocorniiiips West Sak 1 E-166 Producer Tri-Lateral Completion RWO 09 s~ Rakcr (),ll 7nnls As Comaleted Latera With D l Entrv Module (LEM) iverters and Isolation Lateral Access Diverer Lateral Isolation Diverter GS Running fool String Installed Installed (3.00" Lateral Drily (2.50" ID Mainbore Dritt) 'GS' Profile for I Coil Connector ~7 J RunninglRetrieving ~ (tsa' Length) ! ' Il snap INSnap out j '" Positive Locating ~~ Ireack Pressure Valve ~ CoBet i (1.60'Length) ,, Lateral Isoletion!' r Fbw-Thru Swivel ~ Seals I I (1.25' Length) ~ ~ Lateral Divener ~~ ~~ ~ ~~ Hydraulic Ramp Disconnect I -'~ Isolation/ Mainbore-" (1.50' Length) ~ Diverter Sleeve , GS Spear ~x(1.50' Length) I Lateral Isolation ~"' i i ~ 6.bbk Approz. OAL' ~ ~ Seals r-, ~i 'Jars may be required in higAly deviated or deep applications 16' approz length). 18.5 Diverter Length 16.5' Sleeve LengM 'D' Sand Lateral 4788' MD -Lateral Entry Module (LEM) Orienting Profile /166L2: D-sand Window at +/_ 4799' MD, 72 deg 3-1/2" bent joint and guide _ 4-1/2" 12.6# slotted and blank liner / shoe 5010' MD - 5-1/2" X 7-5/8" ZXP Liner Top Packer w/ Hold Downs Lateral Entrv Module (LEM) Assembly ~5-1/2 X 7-5/8 ZXP Liner Top Packer w/Hold Downs Casing Sealbore .-Receptacle - 4.75" ID / Tubing Swivel, 4-112" ~ Orienting Profile f Positive Latching Collet '- Seal Bore for Lateral Isolation - 3.68" ID ~ Access Window Positive Lateral \\ Access Seal Bore for Lateral Isolation - 3.68" ID ~ Isolation Seal Asembly 4.T5" Seal OD 5030' MD-Casing Sealbore Receptacle 5063' MD - 4-1/2" X 7-5/8" Model 'B' HOOK Hanger 5-1/2" X 7-5/8" ZXP Liner Top Packer with Hold Downs 5128' MD - 3.562" DB Nipple 5-1/2" X 7-5/8" Flex ~'~ Liner Hanger /Packer Lock / n Assembly Top at Liner Hanger +/. 5302' MD 5335' MD-Casing Sealbore Receptacle eager Mugnes lODI. TFi• eocumem may ne, be repretlucetl er tlisFiCUkE, in W,ek pr In p,rl, in any loin, er nv am ma,na He<nnn~. p, mmn,mca. ~n<mem9 pnemropym9, rare.emv, e, er •nv inm,m.nnn .k.,9n ,ne rtn».x,v,r.~ ^aw x~.n n, nr.,aer ~n..nr.e...n,evl.,nn,n p•en~+•Ipn nom e,kr we9n..lnr. 1 E-166L1: 3-1/2" Liner shoe @ 9380' MD, 3329' TVD Eauipment Specifications 4-1/2" X 7-S18" HOOK Hanger Mainbore Drift: 5.72" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 41/2" Lateral Entry Module Mainbore Drik: 3.65" Mainbore Onft, w/ isolation sleeve: 2.50" Lateral Drift, w/ coil diverter: 3.00" OD of DiveRer and Sleeve: ~/- 3.89" Diverter and Sleeve Length: +/- 18.5' 5346' MD -Bottom of Seal Assembly 4.75" Seal OD 'A' Sand Undulating Lateral Casing, 7-5/8" 29.7#, L-80, BTCM, Set @ +l- 6014' MD, 3502' TVD. 4-1/2" 12.6# slotted and blank liner 1E-166: 4-1/2" Liner shoe @ 9596' MD, 3518' TVD 2000 - tE-166 Trlaateral Completion -Producer January 70, 2D09 ~-'~ Ian ioome ~ ~~~~~RWO Completed Y 1 E-166L2: 3-1/2" Liner Shoe @ 9402' MD, 3258' TVD MD -Bottom of Seal Assembly 4.75" Seal OD 5057' MD -Lateral Entry Module (LEM) ~ ~ Orienting Profile 'B' Sand Lateral 166L1: B-sand Window at +l- 5068' MD, 82 deg 3-1/2" bent joint and guide 4-1/2" 12.6# slotted and blank liner / shoe Cano~oF'hiilips ... L usne, krR7. HEATTRACE. z2 SURFACE, 30-3,012 GAS LIFT, 3,029 GAS LIFT. 4.563 NIPPLE.4,625 ' GAUGE.4,632 - LOCATOR, 4.685 SEAL ASSV, _ 4.694 D SAND D-SANG LINER, 4,796-9,402 \ 9.617 . KUP ~ Well Attributes WellUora APVU WI Field Name 1500292322061 (WEST SAI (Comment 'SSSV~NIPPLE _--Annotation (Depth (RKB( (Last Taq~ • T Max 1 E-166L2 le 8 MD TD An ',Well Status Prodllnj Typa Inc! (°) g MD(ffKB) iAct Bim (RKB) PROD 92 76 6,556 ' 9 417 eta Annotation End Date KB-Grd (ff) ~ Rig Release Da Last WO. 2/9!2009 I 35.29 I 9/24/2004 otation End Date Reason' Workover, Pull RHC Ball/Rod, GLV C/O 2/17/2009 (RKB) Sat Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd 4.796 9,402 3,258.8 12.60_ _ L-80 DWC Comment ID (ir Top (TVD) Btm (TVD) Dens B6n (RKB) (ffK8) (RKB( Zone Date (sh"' TYPe 9.363 3,284.5 3,259.2 WS D, tE-166L2 9/22/2004 320 Slots Si _ ci general 8 Safety to -- _ - Annotation NOTE TRI-LATERAL WELL: 1E-166(ASAND), 1E-166L1(B-SAND), 1E-1 ~NOTE~ WORKOVER TO RECONNECT ESP CABLE - NO OTHER CHAN( - (NOTE: WORKOVER TO CONVERT FROM ESP TO GAS LIFT f}NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Top Inc! (`) Make Valve 'i Latch rows 4 C~ • Well Date Event Descri tion 1 E-166 1/2/09 (PRE -RWO) T PPPOT -PASSED. T POT -PASSED. IC PPPOT -PASSED. IC POT ~ - PASSED. UPPER BODY SEAL PPPOT -PASSED. UPPER BODY SEAL POT - ~ PASSED. LOWER BODY SEAL PPPOT -PASSED. LOWER BODY SEAL POT - w~ FAILED. LDS FUNCTION TEST -PASSED. a 1E-166 2/5109 Nordic Rig 3 accepted onto 1E-166 on 2-5-2009 @ 09:00 am. RU hardline, bermed up cellar, pulled BPV, RU circ lines, loaded pit's with 8.8ppg seawater/KCL, tested hardline, loaded ESP spooler, killed well, installed BPV, ND tree, installed test dart, NU BOP, RU and started BOP test. 1E-166 2/6/09 Cont BOP test, RD test equipment, pull test dart and BPV, install iso-sleeve, MU landing jnt and circ hose, BOLD's and pull hanger to rig floor, flush IA w with 150 bbls hot seawater, POOH stand back 4 1/2" tbg and strap in 0 derrick, MU and RIH with lateral wash tools, cleanout to 5,046', POOH to Y 264' . ~ 1E-166 2/7/09 POOH LD cleanout assembly, MU seal assembly dummy run, RIH to 5,046', ~ POOH, MU and RIH with LEM assembly to 4,774' ~ 1E-166 2/8/09 test 7 5/8" csg x ZXP for 5 minutes, Orient and latch LEM in place set ZXP ~ , , monitor well, pull setting tools out of ZXP, POOH LD 3 1/2" DP, RU and run 4 0 1/2" gas lift completion to 3 992'. ~ , 0 1E-166 2/9/09 Locate SBE, confirm seals in place, space out, drop ball/rod down tbg, MU Z hanger and landing jnt, make final splices, pump 150 bbls inhibited seawater/KCL down IA, land hanger, test tbg x IA, shear SOV, install BPV, ND/NU, freeze protect well, allow to u-tube. 1E-166 2/10/09 Install BPV, secure well, install guages on tree, blow down all lines, break down hard line, clean out pits, RDMO well 1E-166, clean out cellar box, move rig off 1E Pad. 1 E-166 2/14/09 PULLED B&R, RHC @ 4625' RKB. PULLED SOV AND SET 1" OV(PORT=5/16") @ ~ 4542' RKB. PULLED DMY AND SET 1" GLV(PORT=3/16" TRO=1494) @ 3029' RKB. ~ COMPLETE. ~ O a i • Con©c©Phillips Time Log & Summary WelNlew Web ReAOrtMg Report Well Name: 1 E-166 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 2/5/2009 9:00:00 AM Rig Release: 2/10/2009 3:00:00 AM Time Logs _ _ S. Depth E. Depth _P__h_a__se_ _ Code Subc_ode T Comm__ent Date From To Dur 2/05/2009 _ 2a hr Summary Nordic Rig 3 accepted onto 1 E-166 on 2-5-2009 @ 09:00 am. RU hardline, bermed up cellar, pulled BPV, RU circ lines, loaded pit's with 8.8ppg seawater/KCL, tested hardline, loaded ESP spooler, killed well, installed BPV, ND tree, installed test dart, NU BOP, RU and started BOP test. 07:30 09:00 1.50 0 0 COMPZ RPCOM MOB P Set up double stack of rig mats. Move rig over 1 E-166 Accept Nordic Rig 3 at 9:00 am on 2-5-2009. 09:00 10:00 1.00 0 0 COMPZ RPCOM RURD P RU hardline, tiger tank and berm. 10:00 11:30 1.50 0 0 COMPZ RPCOM MPSP P PU lubricator and pull BPV. 11:30 14:00 2.50 0 0 COMPZ RPCOM RURD P Rig up to kill well. Off load fluids to pits. Test lines to 2000 psi. Crane on location, load ESP spool onto rig floor. 14:00 17:00 3.00 0 0 COMPZ RPCOM KLWL P Initial well pressures T/I/0 = 80/840!150 psi. Bleed down tubing and IA. Pump 90 bbl down the tubing at 5 bpm - 80 psi, and 200 bbl down the IAat 5 bpm - 90 psi. Well is on a vacuum, shut in and monitor well. 17:00 18:00 1.00 0 0 COMPZ RPCOM OTHR P Blow down and RD circ lines, install BPV. 18:00 19:00 1.00 0 0 COMPZ RPCOM NUND P ND tree, install test dart. 19:00 22:00 3.00 0 0 COMPZ RPCOM NUND P NU 13 5/8" BOP. 22:00 00:00 2.00 0 0 COMPZ RPCOM BOPE P RU and test BOPE at 250/2,500 psi on chart. Witness of BOP test waived by AOGCC Rep Bob Noble on 2-5-09 at 18:00 hrs. 2/06/2009 Cont BOP test, RD test equipment, pull test dart and BPV, install iso-sleeve, MU landing jnt and circ hose, BOLD's and pull hanger to rig floor, flush IA with 150 bbls hot seawater, POOH stand back 4 1/2" tbg and stra in derrick, MU and RIH with lateral wash tools, cleanout to 5,046', POOH to 264'. 00:00 03:30 3.50 0 0 COMPZ RPCOM BOPE P Cont testing BOPE at 250/2,500 psi on chart. 03:30 05:30 2.00 0 0 COMPZ RPCOM OTHR P RD test equipment, pull test dart, un-chain stands of 3 1/2 in derrick and shuffle to off-side. 05:30 06:30 1.00 0 0 COMPZ RPCOM RURD P Pull BPV, install isolation sleeve, MU landin 'nt and circ hose, BOLD's. Page 1 of 4 • Time Lo~s_ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:30 08:30 2.00 0 0 COMPZ RPCOM CIRC P Pull hanger to rig floor, pump 150 bbls hot sea-water/KCL down IA to clean tb and a ui ment. 08:30 13:30 5.00 4,468 0 COMPZ RPCOM PULL P Pull completion standing back 4 1/2" tbg. Spool ESP cable, pumping 50 bbls Hr for well control. Recovered All (76) Cannon clamps, (2) Flat guards, (3) Protectolizers, and (10) Bands. Missing (1) door off a protectolizer, but screw was in place. All equipment shafts rotated freely. Oil in the Tandem Seals and Motor were all clean and clear. Cable and Motor Test good. Procedure showed we should recover 15 Bands but 5 where removed during previous operation to connect the enetrators. 13:30 15:30 2.00 0 0 COMPZ RPCOM PULL P Rig down and lay down ESP motor. 15:30 16:00 0.50 0 0 COMPZ RPCOM EQRP P Install wear Ring. 16:00 17:00 1.00 0 564 COMPZ RPCOM PULD P RU Snozzelators BHA on 3 1/2" DP. 17:00 19:00 2.00 564 4,726 COMPZ RPCOM TRIP P RIH with Snozzelator on 3 1/2" DP to 4,726', up weight 95K, down weight 69K. 19:00 21:00 2.00 4,726 5,046 COMPZ RPCOM CIRC P Warm up top drive quill and grease washpipe, MU top drive and wash down from 4,726' to 5,046', pumping at 8 bpm - 3,000 psi down tbg, 6 bpm down IA. Had no trouble going in and out of hook han er. 21:00 21:30 0.50 5,046 5,046 COMPZ RPCOM OWFF P Blow down top drive while monitoring well, well on vac. 21:30 00:00 2.50 5,046 264 COMPZ RPCOM TRIP P POOH with cleanout assembly standing back 3 1/2" DP from 5,046' to 264'. 2/07/2009 POOH LD cleanout assembly, MU seal assembly dummy run, RIH to 5,046', POOH, MU and RIH with LEM assembl to 4,774' 00:00 01:30 1.50 264 0 COMPZ RPCOM PULD P Cont POOH LD cleanout assembly. 01:30 03:30 2.00 0 607 COMPZ RPCOM PULD P MU 4 1/2" seal assembly (4.76" seals) BHA for dumm run. 03:30 06:00 2.50 607 4,790 COMPZ RPCOM TRIP P RIH with seal assembly BHA on 3 1/2" DP to 4,790' and MU top drive, u wei ht 95K, down wei ht 70K. 06:00 07:00 1.00 4,790 5,046 COMPZ RPCOM DHEO P Made numerous attempts to pass through hook hanger but tagging up at 4,813'. Rotated and reciprocated string and finally passed through hook han er to a de th of 5,046'. 07:00 12:00 5.00 5,046 0 COMPZ RPCOM TRIP P POOH from 5,046' and LD dummy run BHA. 12:00 14:00 2.00 0 0 COMPZ RPCOM OTHR P RU crane remove ESP cable and s ool from floor 14:00 17:00 3.00 0 461 COMPZ RPCOM TRIP P Pick up LEM BHA, perform shallow MWD test GOOD. Page 2 of 4 Time Logs Date From To Dur S_De~th E_D~th Phase Code Subcode T .Comment 17:00 22:00 5.00 461 .4,774 r COMPZ _ RPCOM TRIP P RIH with LEM on 3 1/2" DP, 30 FPM, filling hole @ 50 bph for well control, to 4,774', up weight 95K, down wei ht 75K. 22:00 00:00 2.00 4,774 4,774 COMPZ RPCOM DHEQ P Break circ at 3 bpm - 600 psi to orient LEM assembly to 16 degrees left of hi hside. 2/08/2009 Orient and latch LEM in place, set ZXP, test 7 5/8" csg x ZXP for 5 minutes, monitor well, pull setting tools out of ZXP, POOH LD 3 1/2" DP, RU and run 4 1/2" as lift com letion to 3,992'. 00:00 01:00 1.00 4,774 5,034 COMPZ RPCOM OTHR P Wash down to 5,034' mule shoe depth, passing through hook hanger with no problem, re-oriented LEM and latched ZXP at 4 degrees left of highside, un-latched with 20K over pull (115K) slacked off and latched into hook hanger again at 4 degrees left of hi hside. 01:00 02:00 1.00 5,034 5,034 COMPZ RPCOM PACK P Dropped 1 3/4" ball and pumped down string at 1 bpm, seated ball, pressured up to 2,000 psi to activate pusher tool and set ZXP, cunt pressure up to 3,200 psi with test um and neutralized usher tool. 02:00 03:00 1.00 5,034 5,034 COMPZ RPCOM PRTS P Fill la with 8.8ppg sea-water/KCL, close upper pipe rams, pressure up on IA to 2,500 psi and test 7 5/8" csg x ZXP packer for 5 minutes on chart, good test. Blled off IA and pull settin tools from ZXP. 03:00 ..03:30 0.50 5,034 5,034 COMPZ RPCOM OWFF P Blow down top drive, monitor well for 15 minutes, fluid level in IA dropped out of sight, no indication of gas bubble. 03:30 09:30 6.00 5,034 0 COMPZ RPCOM PULD P POOH LD 3 1/2" DP filling hole with 50 b h. 09:30 10:30 1.00 0 0 COMPZ RPCOM RGRP P Slip and cut drill line. 10:30 12:00 1.50 0 0 COMPZ RPCOM RURD P RU sheaves, spools and rig floor to run 4 1/2" com letion. 12:00 00:00 12.00 0 3,992 COMPZ RPCOM RCST P MU seal assembly and gauge carrier, splice Tec wire to gauge, RIH with 4 1/2" SCC completion to 3,992', checking electrical integrity of heat trace and Tec wire every 1,000', filling hole 50 bph. Up weight 80K, down wei ht 63K. 2/09/2009 Locate SBE, confirm seals in place, space out, drop ball/rod down tbg, MU hanger and landing jnt, make final splices, pump 150 bbls inhibited seawater/KCL down IA, land hanger, test tbg x IA, shear SOV, install BPV, ND/NU, freeze rotect well, allow to u-tube. 00:00 02:30 2.50 3,992 4,717. COMPZ RPCOM RCST P Cont RIH with 4 1/2" SCC gaslift completion from 3,992', locate SBE, no- o'd at 4,717', set down 10K. 02:30 03:30 1.00 4,712 4,699 COMPZ RPCOM HOSO P Loaded IA with 8.8 seawater/KCL to surface, fluid level holding. Pulled up hole 18' drag dropped 5K, fluid level dro ed out of si ht. Page 3 of 4 Time Logs _ _ _ >_Date _ From To Dur S: Depth E. De th Phase Code Subcode T_ Comment __ 03:30 04:30 1.00 4,699 4,688 COMPZ RPCOM HOSO P Space out completion with a 2' space out, MU hanger and landing 'nt. 04:30 06:00 1.50 4,688 4,688 COMPZ RPCOM OTHR P MU heat trace and Tec wire splices and tested both. (Waiting on correct enetrator! 06:00 07:30 1.50 4,688 4,688 COMPZ RPCOM CIRC P Pump 150 bbls inhibited seawater/KCL (1% CRW-132) followed by 40 bbls clean seawater/KCL down IA. 07:30 09:00 1.50 4,688 4,712 COMPZ RPCOM HOSO P Lowered hanger down thru stack and landed. RILDS. 90K up wt 65 dwn wt. Tested tubing hanger Orings to 5000 si. 09:00 10:30 1.50 4,712 4,712 COMPZ RPCOM DHEQ P Dropped ball and rod. With annulus open, pressure test tubing to 3000 psi monitoring IA for returns. Bleed down tubing to 1750 psi. Pressure up on IA to 3000 psi for 30 min on chart. Bled pressure off IA, bled pressure off tubing. Ramp up pressure on IA and sheared SOV @ 4543' w/1300 si. 10:30 15:00 4.50 4,712 4,712 COMPZ RPCOM NUND P Back out landing jt. and wash out BOP stack. Drain stack and lay down landing jt. Remove side port isolation sleeve from hanger. Install two-way check. ND BOPE. Replace HCR valve. Lift off BOP stack. 15:00 17:00 2.00 4,712 4,712 COMPZ RPCOM DHEQ P Meggar heat trace thru penetrator. Make final connection and final electrical test on TECH wire. RD s oolers. 17:00 21:00 4.00 4,712 4,712 COMPZ RPCOM NUND P NU tree, heat trace penetrator leaked, removed tree, replaced o-ring on penetrator, installed tree, tested at 250/5,000 psi, good test, pull two wa check. 21:00 23:00 2.00 4,712 4,712 COMPZ RPCOM FRZP P PJSM with LRS personell, test manifold and circ lines at 250/2,500 psi, good test, freeze protect well with 130 bbls diesel down IA at 2 b m, 800 si ICP - 1,000 si FCP. 23:00 00:00 1.00 4,712 4,712 COMPZ RPCOM RURD P Allow well to u-tube, warm up move system, move mudshack and tanks for ri move. 2/10/2009 Install BPV, secure well, install guages on tree, blow down all lines, break down hard line, clean out pits, RDMO well 1 E-166, clean out cellar box, move ri off 1 E Pad. 00:00 01:30 1.50 0 0 COMPZ RPCOM RURD P Blow down and RD circ lines, set BPV, install guages and secure tree, SITP = 0, IA = 0, OA = 180 si. 01:30 03:00 1.50 0 0 DEMOB MOVE DMOB P PJSM, back rig off well site, move mats, clean cellar box and well site. Nordic Rig 3 Released at 03:00 hrs on 2/10/2009. Page 4 of 4 • ~ -b ~~-" . ~._ _. ,~: .. .. ~, ~ .~ MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFicheiCvrPgs_Inserts\1Vlicrofilm Marker.doc ;¿U{ .(:) (t- À-b, \0 DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 5¡J~c1 I 'h/-~i API No. 50-029-23220-61-00 Permit to Drill 2041550 Well Name/No. KUPARUK RIV U WSAK 1E-166L2 Operator CONOCOPHILLIPS ALASKA INC ----~ MD 9417____ TVD 3258 /' Completion Date 9/24/2004""-- Completion Status 1-01L Current Status 1-01L UIC N -~~~ ~-----~'--~---_..~ REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: GR / RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name _.~--~- Mud Log No Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH/ Start Stop CH Received 4799 9417 Open 10/13/2004 108 9417 Open 5/9/2005 . Comments l I I MULTIPLE I PROPAGATION I RESISTIVITY/GAMMA RAY/GRAPHIC IMAGES MULTIPLE I PROPAGATION I RESISTIVITY/GAMMA I RAY/GRAPHIC IMAGES I MULTIPLE [ PROPAGATION I RESISTIVITY/GAMMA RAY/GRAPHIC IMAGES I I MULTIPLE I . PROPAGATION I RESISTIVITY/GAMMA RAY/GRAPHIC IMAGES I 1: .yfg I I r ~ U, I I I 14 I I Directional Survey 13115 Induction/Resistivity 25 Blu 13115 Induction/Resistivity 25 Blu 108 9417 Open 5/9/2005 13115 Induction/Resistivity 108 9417 Open 5/9/2005 13115 LIS Verification 108 9417 Open 5/9/2005 Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received Permit to Drill 2041550 MD 9417 TVD 3258 ADDITIONAL INFORMATION Well Cored? Y @ Chips Received? ~ Analysis Received? ~ Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Well Name/No. KUPARUK RIV U WSAK 1E-166L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23220-61-00 Completion Date 9/24/2004 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? c9/N &/N Formation Tops ~ Date: J! a 3f7 ~J--t h . . , 1a. Well Status: Oil 0 Gas U Plugged U Abandoned U Suspended U WAG 0 1b. Well ClåS'$~ 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL 0 No. of Completions _ Other - Service 0 Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., 12. Permitto Drill Number: ¡ ConocoPhillips Alaska, Inc. or Aband.: September 24, 2004 204-155/ 3. Address: 6. Date Spudded: r\ , )~ .,.e ~. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 September;A'; 2004 .... I 50-029-23220-61 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: / 1E-166L2 Surface: 147' FNL, 640' FEL, Sec. 21, T11N, R1OE, UM September 21 , 2004 At Top Productive 8. KB Elevation (It): 15. FieldlPool(s): Horizon: 2537' FNL, 1109' FWL, Sec. 22, T11N, R1OE, UM 28' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): West Sak Oil Pool 1810' FNL, 1016' FWL, Sec. 27, T11N, R1OE, UM 9400' MD /3259' rvD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: , 5959440 " Zone- 4 , 9417' MD /3258' TVD , ADL 25651 & 25660 x- 549890 y- TPI: x- 551660 y- 5957061 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 551607 I y- 5952509 . Zone-4 none ALK 469 & 470 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1630' MD 21. Logs Run: -r/ w w...d.w '17 i1 ,. mb GRlRes 3 2. , I ,. fYþ 22. CASING, LINER AND CEMENTING RECORD ,.41> ~o·lf.-, ~ SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD PULLED CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE 20" x 34" 62.5# H-40 28' 108' 28' 108' 42" 317sx ASI 10.75" 45.5# L-80 28' 3012' 28' 2393' 13.5" 520 sx AS Lite, 181 sx DeepCrete 7-5/8" 29.7# L-80 28' 6014' 28' 3502' 9-7/8" 320 sx DeepCrete 4.5" 12.6# L-80 4795' 9402' 3290' 3258' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET slots in lower 'D' liner from: 4.5" 4470' 5302' 4822'-9363' MD 3286'-3259' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) October 12, 2004 production shared with 1 E-166 and 1 E-166L1 Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/15/2004 6 hours Test Period --> 1077 736 10 33 Bean 617 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) not available not available 24-Hour Rate -> 4185 2582 41 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none", r...·.......·"··k'·"'__.,c-.".-""'.·"'<$ i GD1V~;'.~2·':Cd~ i NONE ! 9,~t/4¡ O~!G1~L~L ¡ . iF''¡:¡:'Ei) 1 \: .~I 1. [ L 1 ,6b \ I-__C_~_wj ,~ O~^M < Form 10-407 Revised 12/2003 CONTINUED ON REVERSE r . ....- I STATE OF ALASKA .0·' CT ·.f ~ ';;I)[ 11.' 1 ., t..U .ILl ALA 'A Oil AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPeRT! Å14ôtlfOBm¡¡:1ìie0 ~~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1E-166L2 West Sak D 4798' 3280' ocr 1 ., /U'U4 l¿,. '-. N/A 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 McKeever @ 265-6826 PrintedNa~~ Signature t Title: .-BIòÐne Kuparuk Drillina Team Leader Date i "C>(ccr r or Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 URIGlr~AL Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: Slip and cut 104' of drlg line and serviced top drive MU 13 1/2" BHA #1, Bit, bit sub and 1-NM flex DC, tagged ice in conductor at 55' Flooded conductor checking for leaks Repaired Willis choke and Demco valve on standpipe Re-Ieveled sub over hole Cleaned out inside conductor from 55' to 108' Drilled 13 1/2" hole from 108' to 310' (202') ART 2 Hrs POOH MU 131/2" BHA #2 with MWD, oriented and uploaded same, RIH to 310' RU HES slickline unit for Gyro Drilled 13 1/2" hole per directional plan from 310' to 1,390' MD/1,327' TVD (1,080'), ART 2.4 hrs, AST 4.9 hrs, 20-35K wob, 50 rpm's, 450-530 gpm, 1,200 psi -1,700 psi, rot wt 90K, up wt 95K, dn wt 85K, torque Off btm -0-, on btm 4K ft-Ibs, took Gyro survey's for check shots at 375' and 560' and ck ok, RD slickline at 940' 5.25 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 1,390' to 1,947' MD/1,704' TVD, (557'), ART 1.6 hrs, AST 2.0 hrs, 10-30K wob, 50 rpm's, 550 gpm, off btm pressure 1,400 psi, on btm 1,750 psi, off btm torque 2.5K ft-Ibs, on btm 4.5K ft-Ibs, rot wt 92K, up wt 100K, dn wt 85K, pumped 1 weighted hi vis sweep and had 20% increase in cuttings back Pumped out of hole from 1,947' to HWDP at 1,113', pumped out at 500 gpm at 1 ,400 psi POOH standing back HWDP and BHA #2, drained 1.8 deg bend mud motor and LD same MU BHA #3 with 1.3 deg bend motor jetted for 700 gpm, oriented MWD and RIH with HWDP then MU 13 1/2" ghost reamer, RIH to 1,119' RIH to 1,861', washed 86' to btm at 1,947' with no problems Circ btms up after trip, circ out a large amount of clay and sand Drilled 13 1/2" hole per directional plan from 1,947' to 3,020' MD/2,398' TVD, (1,073'), (Csg Pt), ART 4.2 hrs, AST .6 hrs, 10-30K wOb, 100 rpm's, 700 gpm, off btm pressure 2,300 psi, on btm 2,400 psi, off btm torque 7K ft-Ibs, on btm 9K ft-Ibs, rot wt 104K, up wt 132K, dn wt 85K, pumped weighted hi vis sweep on last std, no gas hydrates in surface hole """ Note"" After conferring with town the new surface TD was picked @ 2400' TVD +/- 8/31/2004 12:00 - 14:30 2.50 MOVE DMOB MOVE 14:30 - 17:00 2.50 MOVE MOVE MOVE 17:00 - 18:00 1.00 MOVE RURD MOVE 18:00 - 20:00 2.00 WELCT NUND SURFAC 20:00 - 22:00 2.00 DRILL OTHR SURFAc 22:00 - 00:00 2.00 DRILL PULD SURFAC 9/1/2004 00:00 - 01 :45 1.75 DRILL PULD RIGUP 01 :45 - 02:15 0.50 WELCT BOPE RIGUP 02:15 - 03:45 1.50 RIGMNT RSRV RIGUP 03:45 - 04:30 0.75 DRILL PULD SURFAC 04:30 - 05:00 0.50 DRILL CII3C SURFAC 05:00 - 06:15 1.25 RIGMNT RGRP SURFAC 06:15 - 07:00 0.75 RIGMNT OTHR SURFAC 07:00 - 07:30 0.50 DRILL CIRc SURFAC 07:30 - 10:15 2.75 DRILL DRLG SURFAC 10:15 - 10:45 0.50 DRILL TRIP SURFAC 10:45 - 13:00 2.25 DRILL PULD SURFAC 13:00 - 13:30 0.50 LOG RURD SURFAC 13:30 - 00:00 10.50 DRILL DRLG SURFAC 9/2/2004 00:00 - 05:15 05:15 - 06:15 1.00 DRILL TRIP SURFAC 06:15 - 08:45 2.50 DRILL PULD SURFAC 08:45 - 10:15 1.50 DRILL PULD SURFAC 10:15 -11:00 0.75 DRILL TRIP SURFAC 11 :00 - 12:00 1.00 DRILL CIRC SURFAC 12:00 - 19:00 7.00 DRILL DRLG SURFAC Rig down and moved rig off 1E-126 Spot sub, rig complex's, rock washer and pipe sheds on 1 E-166, moved rig 1,080' from 1 E-126 to 1 E-166 Finished rigging up service lines and completed rig acceptance check list ACCEPTED RIG @ 18:00 hrs 8/31/04 NU 21 1/4" 2M diverter and 16" line and began mixing spud mud Loaded pipe shed with 5" DP & HWDP, continued mixing spud mud and changed out saver sub on top drive PU and stood back 16 stds of 5" DP Fin PU & standing back 21 stds of 5" DP, PU & Stood back 10 stds of 5" HWDP and jars Function tested diverter, John Spaulding WAOGCc waived witnessing test Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/212004 9/3/2004 Fin circ out weighted hi vis sweep, circ at 700 gpm at 2,200 psi and 100 rpm's, had 35% increase in cuttings back from sweep Monitored well-static Backreamed out of hole at drlg rate from 3,020' to 1,119', at Ghost reamer and BHA #3, LD ghost reamer, no problems backreaming out POOH wet with HWDP to 200', stood back HWDP and Cleared rig floor, RU to LD BHA #3 LD BHA #3,3-63/4" NMCSDP, short NMDC, stab, MWD, drained and LD motor, cleared rig floor Began RU to run 103/4" csg when hydraulics went out on top drive Trouble shoot loss of hyd. power to top drive, changed out relief valve and hyd. pump to top drive, changed out lower set of 5" pipe rams on BOP's to 7 5/8" csg rams Fin RU Doyons 103/4" csg equipment with Franks fill up tool Held PJSM with rig crew and tong operator on running of csg MU 103/4" float shoe, 2 jts 103/4" 45.5# Le80, BTC csg, fit collar, thread locked conn below FC and circ thru shoe track, RIH with 103/4" csg to 1,003' Circ btms up at 1,003', circ at 2 bpm at 325 psi, st wt up 73K, dn wt 60K, circ out thick mud with sand and clay RIH with 103/4" csg to 2,007' Circ btms up at 2,007', circ at 2 bpm at 325 psi, st up wt 118K, dn wt 86K RIH with 103/4" csg, MU hanger and landed csg with float shoe at 3,012' MD/2,393' TVD, float collar at 2,925', no problems RIH, Ran a total of 20 jts (798') of 40.5# L-80, BTC csg above shoe track and a total 53 jts (2,177') of 45.5#, L-80, BTC csg including shoe track, total float equip, csg and hanger, 2,982', ran 52 bow spring centralizers and 21 stop rings per well plan Circ btms up thru fill up tool and began cond mud for cementing, staged pump rate up to 6 bpm at 300 psi, st wt up 155K, dn wt 100K RD Franks fill up tool and MU Dowell's cement head Cont to circ and cond mud for cementing, circ at 6 bpm at 325 psi, reciprocating pipe with 160K up wt and 105K dn wt, circ and cond mud to 9.4 ppg and lower PVNP to <15 Fin circ and conditioning mud for cementing, final MW in & out, 9.4 ppg, 44 vis, 12 PV and 15 YP, circ at 6 bpm at 325 psi, st wt up 160K dn wt 105K, held PJSM with Dowell, APC vac truck drivers and rig crew on cementing operations while circ. 2.00 CEMEN PUMP SURFAC Turned over to Dowell and cemented 103/4" csg, pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 50 bbls of 10.5 ppg mudpush,dropped btm plug, began mixing and pumping Arcticset lead slurry, pumped 412 bbls (520 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6 bpm at 110 psi, followed with 80.5 bbls (181 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.48 yield with add., ave 5.5 bpm at 180 psi, reciprocated csg and had full retums, shut down and dropped top plug 1.00 CEMEN DISP SURFAC Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 262 bbls of 9.4 ppg mud, displaced cmt at 6 bpm, initial circ pressure 350 psi, max pressure 700 psi, slowed rate to 3.5 bpm and bumped plug on calc displacement, pressured up to 1,400 psi, checked floats and held, CIP @ 03:20 hrs, had full returns during 19:00 - 19:30 0.50 DRILL CIRC SURFAC 19:30 - 19:45 0.25 DRILL OBSV SURFAC 19:45 - 22:30 2.75 DRILL REAM SURFAC 22:30 - 00:00 1.50 DRILL TRIP SURFAC 00:00 - 01 :45 1.75 DRILL PULD SURFAC 01 :45 - 02:30 0.75 CASE RURD SURFAC 02:30 - 12:00 9.50 RIGMNT RGRP SURFAC 12:00 - 12:45 0.75 CASE RURD SURFAC 12:45 - 13:00 0.25 CASE SFTY SURFAC 13:00 - 15:45 2.75 CASE RUNC SURFAC 15:45 - 16:15 0.50 CASE CIRC SURFAC 16:15 - 17:30 1.25 CASE RUNC SURFAC 17:30 - 18:45 1.25 CASE CIRC SURFAC 18:45 - 20:15 1.50 CASE RUNC SURFAC 20:15 - 21:30 1.25 CEMEN CIRC SURFAC 21:30 - 22:15 0.75 CEMEN RURD SURFAC 22: 15 - 00:00 1.75 CEMEN CIRC SURFAC 9/4/2004 00:00 - 00:30 0.50 CEMEN CIRC SURFAC 00:30 - 02:30 02:30 - 03:30 Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/4/2004 02:30 - 03:30 1.00 CEMEN DISP SURFAC job and had 110 bbls of 10.7 ppg cmt back to surface, reciprocated csg till 02:45 hrs, 70 bbls into displacement, approx 275 bbls lead cement out of shoe 03:30·04:15 0.75 CASE DEQT SURFAC RU and tested 10 3/4· csg to 2,500 psi for 30 min, good test 04:15 - 05:15 1.00 CASE RURD SURFAC RD cement head, LD landing jt and cleared rig floor 05:15 - 09:00 3.75 WELCT NUND SURFAC ND 21 1/4" diverter, starting head and 16" diverter line 09:00 - 10:30 1.50 WELCT NUND SURFAC NU & Orient Vetco Gray MB 222 Wellhead, Tested seals to 5,000 psi for 15 min. 10:30 - 13:30 3.00 WELCT NUND SURFAC NU 133/8" BOP stack NOTE: Had 4 bbl spill at injection skid, mud was spilled into secondary containment and immediately cleaned up 13:30 - 14:45 1.25 WELCT SURFAC RU to test BOPE 14:45·17:30 2.75 WELCT SURFAC Began to test BOP's and door seal on blind rams leaked, re-tightened and continued to leak, removed choke line hose and changed out door seal on off drillers side, rigged back up and refilled choke manifold and stack 17:30 - 22:15 4.75 WELCT BOPE SURFAC Tested BOPE, choke manifold, 4" and 5" floör valves, rams including 7 5/8" csg rams to 250 psi low and 3,000 psi high, annular to 250 psi low and 1,500 psi high John Spaulding W/AOGCC waived witnessing of test 22:15 - 22:45 0.50 DRILL RIRD SURFAC Installed wear bushing 22:45 . 00:00 1.25 DRILL RIRD SURFAC Began changing over top drive to 4" XT-39 DP, changed out saver sub 9/5/2004 00:00 - 01 :30 1.50 DRILL RIRD SURFAC Finished changing over top drive to 4" XT-39 DP, changed pipe grabbers and pipe guide 01 :30 - 03:45 2.25 DRILL PULD SURFAC PU 54 jts (18 std) of 4" XT-39 DP from pipe shed and RIH to 1,670' 03:45 - 04:30 0.75 DRILL CIRC SURFAC Circ thru 4" DP and displaced out 9.4 ppg mud in hole to re-condtioned 9.0 ppg LSND mud 04:30 - 05:15 0.75 DRILL TRIP SURFAC POOH standing back 4" DP 05:15 - 07:00 1.75 DRILL PULD SURFAC PU an additional 54 jts (18 std) of 4" XT-39 DP from pipe shed and RIH to 1,670' 07:00 - 07:30 0.50 DRILL TRIP SURFAC POOH standing back 4" DP 07:30 - 08:00 0.50 DRILL PULD SURFAC RU and LD 2 stds of 5" DP from derrick 08:00 - 12:00 4.00 DRILL PULD SURFAC MU 9 7/8" BHA #4 with 1.1 deg bend mud motor, and MWD, oriented and uploaded MWD, RIH with HWDP and jars, MU ghost reamer RIH to 1,110' 12:00 - 13:00 1.00 DRILL TRIP SURFAC RIH with BHA #4 from 1,110' to 2,871' with 5" DP, changed over to 4" DP 13:00 - 13:15 0.25 DRILL DEQT SURFAC Circ and tested MWD, staged pump rate to 510 gpm at 1,325 psi and tool ck ok 13:15 - 13:45 0.50 DRILL CIRC SURFAC Fin displacing out 9.4 ppg mud with re-conditioned 9.0 ppg LSND mud, circ at 530 gpm at 1,500 psi, rot wt 98K, up wt 130K, dn wt 78K 13:45 - 15:00 1.25 CEMEN DSHO SURFAC Drilled out plugs, float collar at 2,925', shoe jts and float shoe at 3,012', drilled 20' of new formation to 3,040' MD/2,411' TVD, drilled with 5K wob, 50 rpm's, 530 gpm at 1,500 psi 15:00 - 15:30 0.50 DRILL CIRC SURFAC Circ hole clean evening MW in and out at 9.0 ppg for LOT, circ at 530 gpm at 1 ,500 psi 15:30 - 16:15 0.75 DRILL LOT SURFAC RU and performed LOT to 13.4 ppg EMW, 550 psi, 9.0 ppg mud at 2,393' TVD 16:15 - 00:00 7.75 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 3,040' to 3,809' MD/2,870' TVD, (769'), ART 2.1 hrs, AST 2.6 hrs, 5-15K wob, 100 rpm's, 155 spm, 657 gpm, off btm pressure 2,250 psi, on btm 2,450 psi, off btm torque 5-12K ft-Ibs, on btm 7-1 OK ft Ibs, rot wt 103K, up wt 145K, dn wt 79K, clean hole ECD with 9.0 ppg MW = 9.4 ppg, ECD with 9.0 ppg MW Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/512004 16:15 - 00:00 7.75 DRILL DRLG INTRM1 while drlg ave 9.65 ppg 9/6/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 3,809' to 5,023' MDI 3,331' TVD, (1,214') ART 5.2 hrs, AST 2.5 hrs, 5-30K wob, 100 rpm's, 155 spm, 655 gpm, off btm pressure 2,700 psi, on btm 3,000 psi, off btm torque 5-11 K ft-Ibs, on btm 7-10K ft-Ibs, rot wt 98K, up wt 145K, dn wt 76K, 9.2 ppg MW, ave ECD 10.4 ppg, max ECD 10.9 ppg, pumped weighted hi vis sweep at 4,276' and had 30% increase in cuttings Est Top of West Sak "D" at 4,798' MD/3,280' TVD, No BGG was seen until drilling "D" sand, Max gas from "D" sand 1,500 units 12:00 - 23:00 11.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 5,023' to 6,020' MD/3,503' TVD, (997') ART 5.7 hrs, AST 1.8 hrs, 5-30K wOb, 100 rpm's, 155 spm, 655 gpm, off btm pressure 3,150 psi, on btm 3,300 psi, off btm torque 9K ft-Ibs, on btm 11 K ft-Ibs, rot wt 94K, up wt 135K, dn wt 72K, 9.2 ppg MW, ave ECD 10.4 ppg, max ECD 10.7 ppg, pumped 1-weighted hi vis sweep at 5,180' with 5% increase in cuttings and 1 at 5,985' with 10% increase in cuttings Est Top of West Sak "B" at 5,067' MDI 3,343' TVD, Ave BGG while drilling 300-400 units, Max gas from "B" sand 2,700 units 23:00 - 00:00 1.00 DRILL REAM INTRM1 Backreamed out of hole at drilling rate from 6,020' to 5,494' with no problems 9/7/2004 00:00 - 03:30 3.50 DRILL REAM INTRM1 Backreamed out of hole from 5,494 to 4,185' at drlg rate till ghost reamer was at csg shoe, backreamed at 100 rpm's, 655 gpm at 3,000 psi, with no problems, pumped out of hole to csg shoe at 3,012' 03:30 - 04:15 0.75 DRILL CIRC INTRM1 Pumped weighted hi vis sweep and circ hole clean at 3,012' (csg shoe), circ at 575 gpm at 1,700 psi and 40 rpm's, had 5% increase in cuttings from sweep, circ 3X btms and clean at shakers, rot wt 95K, up WI 11 OK, dn wt 95K 04:15 - 04:30 0.25 DRILL OBSV INTRM1 Monitored well-static 04:30 - 05:00 0.50 DRILL TRIP INTRM1 POOH wet from 3,012' to 2,875', hole taking proper fill, pumped dry job and changed over handling tools to 5" DP 05:00 - 06:30 1.50 DRILL PULD INTRM1 POOH LD 56 jts of 5" DP to 1,110' (BHA) 06:30 - 09:30 3.00 DRILL PULD INTRM1 POOH LD, 5" HWDP, jars and ghost reamer, downloaded MWD and LD BHA #4 09:30 - 10:00 0.50 DRILL PULD INTRM1 Pulled wear bushing, cleared rig floor 10:00 - 11 :45 1.75 CASE RURD INTRM1 RU Doyon's 7 5/8" csg handling equipment with Franks fill up tool 11 :45 - 12:00 0.25 CASE SFTY INTRM1 Held PJSM on running of 7 5/8" csg 12:00 - 17:00 5.00 CASE RUNC INTRM1 RIH with 75/8",29.7#, L-80, BTC-M csg to 2,100', MU 75/8" Float shoe, 2 jts csg, float collar, thread locked btm 3 conn's and circ thru float equip and ck ok, RIH with 47 add. jts along with pup jts for spacing out to 2,100' 17:00 - 18:00 1.00 CASE CIRC INTRM1 Circ a csg cap at 2,100', staged pump rate up to 3112 bpm at 275 psi, circ out thick mud, st wt up 124K, dn wt 47K 18:00 - 19:30 1.50 CASE RUNC INTRM1 RIH with 7 5/8" csg from 2,100' to 2,984 19:30 - 20:00 0.50 CASE CIRC INTRM1 Circ a csg cap at 103/4" csg shoe, staged pump rate up to 4 bpm at 350 psi, st up wt 156K, dn wt 45K 20:00 - 23:30 3.50 CASE RUNC INTRM1 Fin RIH with 7 5/8' csg, RIH to btm with no problems in open hole, MU hanger and landed 75/8" csg at 6,014' MDI 3,502' TVD with float collar at 5,927', ran a total of 140 jts 7 5/8",29.7#, L-80 BTC-M csg with 3-pup jts and hanger (Total 5,987') 23:30 - 00:00 0.50 CASE CIRC INTRM1 Began circ and conditioning mud for cementing, circ thru Franks fill up tool, staged pump rate up to 5 bpm at 525 psi, st WI up 175K, dn wt 77K 9/8/2004 00:00 - 00:30 0.50 CEMEN CIRC INTRM1 Fin circ btms up thru Franks fill-up tool while conditioning mud, staged pump rate to 6 bpm at 550 psi, st wt up 175K, dn WI 77K Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/8/2004 00:30 - 01 :00 0.50 CEMEN RURD INTRM1 LD Franks fill up tool and MU Dowell's cement head 01 :00 - 03:15 2.25 CEMEN CIRC INTRM1 Cont to circ and cond mud for cementing, circ at 6 bpm at 500 psi, st wt up 190K, dn 80K, conditioned mud from 9.3 ppg, 58 vis, 21YP, 18 PV to 9.2 ppg, 50 vis, 17 YP, 15 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ 03:15·04:15 1.00 CEMEN PUMP INTRM1 Dowell pumped 10 bbls CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped 20 add. bbls of CW 100, pumped 50 bbls of MudPush at 10.5 ppg, dropped btm plug then pumped 128 bbls, (320 sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6 bpm at 250 psi, reciprocated pipe with full returns, shut down, washed up and dropped btm plug 04:15 - 05:15 1.00 CEMEN DISP INTRM1 Rig displaced cement with 8.8 ppg OBM, bumped plug after pumping 271.3 bbls OBM (95% pump eft.) (Calc Disp 272.5 bbls) ave 7 bpm while displacing cmt, max pressure 1,000 psi, slowed pump rate to 4 bpm with 15 bbls left to pump and bumped plug to 1,500 psi, ck floats and held CIP at 05:00 hrs, reciprocated pipe until 50 bbls of cement was around shoe when hole began getting tight and stopped reciprocating, est TOC @ 3,600' 05:15 - 06:00 0.75 CEMEN RURD INTRM1 RD cement head and LD landing jt 06:00 - 07:30 1.50 WELCT EQRP INTRM1 Installed 7 5/8" pack-oft and tested to 5,000 psi for 15 min 07:30 - 08:00 0.50 DRILL PULD INTRM1 Installed wear bushing 08:00 - 08:45 0.75 DRILL RIRD INTRM1 RD 7 5/8 csg equipment, elevator bales and cleared rig floor 08:45 - 10:45 2.00 RIGMNT RSRV INTRM1 Slip & cut 65' of drlg line and serviced top drive. RIU hardline on 10-3/4" x 7-5/8" annulus. PTto 1,500 psi, OK. Pump 15 bbls water @ 1,100 psi 2 BPM. SID 800 psi. 10:45 - 12:30 1.75 DRILL PULD INTRM1 PU and stood back in derrick 9 stds 4" push pipe 12:30 - 14:15 1.75 DRILL PULD INTRM1 MU BHA #5,43/4" mud motor with 1.2 deg bend, MWD, LWD and PWD, oriented and uploaded MWD, RIH with BHA #5 to 256' 14:15 - 16:30 2.25 DRILL PULD INTRM1 RIH with BHA #5 PU 4" XT-39 DP from pipe shed, RIH to 3,030' 16:30 - 17:00 0.50 DRILL DEQT INTRM1 Shallow tested MWD at 3,030', 300 gpm at 1,480 psi and ck ok, st wt up 75K, dn wt 65K 17:00 - 19:30 2.50 DRILL PULD INTRM1 Cont to RIH with BHA #5 PU 4" DP from pipe shed, RIH to 5,486', PU a total of 186', RIH from 5,486' to 5,926' from derrick and tagged up on plugs above float collar at 5,925' 19:30 - 20:00 0.50 DRILL CIRC INTRM1 Circ btms up for csg test evening MW in & out at 8.8 ppg, 300 gpm at 1,900 psi, st wt up 99K, dn wt 69K 20:00 - 21 :00 1.00 CASE DEQT INTRM1 RU and tested 7 5/8" csg to 2,500 psi for 30 min 21:00 - 22:15 1.25 CEMEN DSHO INTRM1 Drilled out cmt plugs, float collar at 5,925', soft cement inside shoe track, float collar at 6,014' then drilled 20' of new formation from 6,020' to 6,040' MD/ 3,503' TVD, ADT .1 hrs,4-6K wob, 40-60 rpm's, 300 gpm at 2,100 psi, rot wt 80K, up wt 105K, dn wt 67K 22:15 - 23:00 0.75 DRILL CIRC INTRM1 Circ hole clean for LOT, circ at 300 gpm at 1,850 psi 23:00 - 00:00 1.00 DRILL FIT INTRM1 RU to perform LOT, pressured up on well to 1,300 psi and shut down for FIT, at 1,300 psi, 8.8 ppg mud at 3,502' = 15.9 ppg EMW FIT 9/9/2004 00:00 - 02:30 2.50 DRILL DRLG PROD Drilled 6 3/4" hole from 6,040' to 6,236' MD/3,547' TVD, (196'), ART.6 hrs, AST.7 hrs, 10K wob, 80 rpm's, 296 gpm, oft btm pressure 1,850 psi, on btm 2,000 psi, oft btm torque 3K ft-Ibs, on btm 4K, rot wt 82K, up wt 108K, dn wt 68K NOTE: Flushed 7 518" x 103/4" annulus with 150 bbls fresh water then freeze protected with 100 bbls diesel 02:30 - 02:45 0.25 DRILL CIRC PROD Circ hole to est clean hole ECD, with 8.8 ppg OBM clean hole ECD was 10.2 ppg NOTE: While circ, determined internal scribe line correction was not Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/9/2004 02:30 - 02:45 0.25 DRILL CIRC PROD made in the MWD tool, scribe line correction was to be 94 deg. causing well to get off directional plan. To drill ahead we would cross 1 E-35 hard line and decision was made to shut in well and set tbg plug in well 1 E-35 before drlg ahead 02:45 - 03:00 0.25 DRILL TRIP PROD POOH from 6,236' to 6,014' to 7 5/8" csg shoe 03:00 - 12:00 9.00 WAlTON EQIP PROD Called out HES slickline, worked pipe and circ often inside csg while W.O. slickline, production shut down injection on 1 E-35 well and HES Slickline RIH and set plug in tbg at 11,114' 12:00 - 12:15 0.25 DRILL TRIP PROD RIH from 6,014', washed 96' to btm at 6,236' with no problems 12:15 - 18:00 5.75 DRILL DRLG PROD Directiona/ly drilled 63/4" hole from 6,236' to 6,701' MD/3,504' (465') ART -0-, AST 3.8 hrs, 4-15K wob, -0- rpm's, 75 spm, 318 gpm, off btm pressure 2,225 psi, on btm 2,400 psi, off btm torque 4K, on btm 6K ft-Ibs, rot wt 80K, up wt 115K, dn wt 55K, 8.8 ppg OBM, ECD while sliding 9.9 ppg 18:00 - 19:00 1.00 DRILL CIRC PROD Circ hole evaluating geological and directional options, circ at 318 gpm at 2,225 psi, found to have drilled out the top of zone, decision was made with town to drill back into zone and continue drilling, clean hole ECD while circ was 10.2 ppg with 8.8 ppg OBM 19:00 - 00:00 5.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 6,701' to 7,134' MD/3,511' (433') ART 1 hr, AST 1.9 hrs, 2-5K wOb, 100-120 rpm's, 75 spm, 318 gpm, off btm pressure 2,250 psi, on btm 2,400 psi, off btm torque 4K, on btm 5K ft-Ibs, rot wt 75K, up wt 115K, dn wt 60K, 8.9 ppg OBM, Ave ECD 10.6 ppg 9/10/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 63/4" hole from 7,134' to 8,103' MD/3,536' TVD, (969') ART 3.6 hrs, AST 4.1 hrs, 2-15K wob, 120 rpm's, 318 gpm, off btm pressure 2,400 psi, on btm 2,500 psi, off btm torque 5K ft-Ibs, on btm 5.5K ft-Ibs, rot wt 80K, up wt 115K, dn wt 56K, 8.8 ppg OBM, ave ECD 10.4 ppg, max ECD 10.8 ppg, ave BGG 75 units, max gas 450 units 12:00 - 18:00 6.00 DRILL DRLG PROD Drilled from 8,103' to 8,680' MD/ 3,501' TVD, (577') ART 3.1 hrs, AST .8 hr, 2-15K wob, 120 rpm's, 318 gpm, off btm pressure 2,475 psi, on btm 2,575 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 123K, dn wt 46K, 8.9 ppg OBM, ave ECD 10.7 ppg, max ECD 11.1 ppg, ave BGG 50 units, max gas 200, pumped wt'd hi vis sweep at 8,640' and had 25% increase in cuttings back from sweep 18:00 - 19:30 1.50 DRILL CIRC PROD Troubleshoot MWD not decoding, checked mud pumps screens and pulsation dampners and slowed data rate on MWD and tool ck'd ok, problem occured before and after pumping wt'd sweep 19:30 - 00:00 4.50 DRILL DRLG PROD Drilled from 8,680' to 9,032' MD/ 3,497' TVD, (352') ART 1.8 hrs, AST 1 hr, 2-6K wob, 120 rpm's, 318 gpm, off btm pressure 2,550 psi, on btm 2,675 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 117K, dn wt 57K, 8.8 ppg OBM, ave ECD 10.9 ppg, max ECD 11.1 ppg, ave BGG 30 units, max gas 100 units, began PU 4" pushpipe at 8,941' 9/11/2004 00:00 - 08:45 8.75 DRILL DRLG PROD Drilled 6 3/4" hole from 9,032' to 9,602' MD/ 3,518' TVD, (570') (T.D.) ART 4.5 hrs, AST 1 hr, 2-5K wob, 120 rpm's, 318 gpm, off btm pressure 2,825 psi, on btm 3,000 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 95K, up wt 131K, dn wt 74K, 8.8 ppg OBM, ave ECD 10.9 ppg, max ECD 11.1 ppg, ave BGG 50 units, max gas 100 units, pumped weighted hi vis sweep on last std 08:45 - 09:30 0.75 DRILL CIRC PROD Circ weighted hi vis sweep out of hole, had 15% increase in cuttings back from sweep, circ at 318 gpm, 2,825 psi at 120 rpm's 09:30 - 09:45 0.25 DRILL OBSV PROD Monitored well-static 09:45 - 16:00 6.25 DRILL REAM PROD Backreamed out of hole at drlg rate from 9,602' to 5,950', (Csg Shoe) Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/11/2004 09:45 - 16:00 6.25 DRILL REAM PROD circ at 318 gm, 100-120 rpm's, initial circ pressure 2,825 psi, final circ pressure 2,375 psi, no problems backreaming out 16:00 - 17:30 1.50 DRILL CIRC PROD Pumped weighted hi vis sweep and circ hole clean at 5,950', circ at 318 gpm at 2,000 psi, had 10% increase in cuttings back from sweep, circ 1 .5x btms up and clean at shakers, rot wt 79K, up wt 113K, dn wt 56K, 5.5K ft-Ibs torque 17:30 - 18:00 0.50 DRILL OBSV PROD Monitored well-static, dropped 1 7/8" rabbit and pumped dry job 18:00 - 21 :30 3.50 DRILL TRIP PROD POOH from 5,950' to BHA #5 at 256', SLM, no corr, retrieved rabbit 21:30 - 23:30 2.00 DRILL PULD PROD POOH and stood back HWDP and jars, downloaded MWD, LD MWD and motor, cleaned rig floor 23:30 - 00:00 0.50 CASE RURD CMPL TN RU to run 4 1/2" liner 9/12/2004 00:00 - 00:15 0.25 CASE SFTY CMPL TN Held PJSM with rig crew on running liner 00:15 - 04:45 4.50 CASE PULR CMPL TN PU and ran 4 1/2" liner per well program, ran 4 1/2" ROT silver bullet guide shoe with no float, 125 jts, (4,237') of 41/2" 12.6#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 76 jts (2,360') of blank liner and 49 jts (1,873') of slotted liner, ran 1- 4 1/2" x 6 1/4" spiralglide centralizer 1/jtto csg shoe (105 total) ran 15 restrictor packers with 30 spacer rings placed on blank liner to isolate shale sections per geology. 04:45 - 06:00 1.25 CASE PULR CMPL TN MU Baker 190-47 csg seal bore eX!, 51/2" x 7 5/8" Flexlock liner hanger, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 4,298' 06:00 - 09:00 3.00 CASE RUNL CMPL TN RIH with 4 1/2" Liner on 5" DP to 5,900', had to screw into each std to keep from running over 09:00 - 09:15 0.25 CASE CIRC CMPL TN Circ a DP cap at 7 5/8" csg shoe, circ at 170 gpm at 250 psi, rotated liner, with pumps on rot wt 75K, up wt 77K, dn wt 73, rotated at 20 rpm's at 2-3K ft-Ibs torque, pumps off st wt up 85K, dn wt 65K 09:15 - 13:30 4.25 CASE RUNL CMPL TN RIH with liner from 5,900' to 9,596' liner setting depth with no problems in open hole, st wt up 120K, dn wt 75K 13:30 - 14:00 0.50 CASE OTHR CMPL TN Dropped 1/34" ball and pumped down to seat, pump at 2 bpm at 510 psi, with ball on seat pressured up to 3,500 psi to set Flexlock hanger, bled off the pressure, cont to set packer, worked 45K wt down and packer didn't set, rotated 20 rpm's with 3K ft-Ibs torque and set ZXP packer, set st wt down several times to ensure packer set, no other problems setting hanger/packer, set "A" sand liner with TOL @ 5,302' and shoe at 9,596', st wt up after setting liner 11 OK, dn WI 86K 14:00 - 14:15 0.25 CASE DEQT CMPL TN RU & tested 7 5/8" csg and ZXP packer to 1,500 psi for 10 min, good test 14:15 - 14:45 0.50 DRILL OBSV CMPL TN Monitored well-static, pumped dry job 14:45 - 18:00 3.25 DRILL TRIP CMPL TN POOH and LD Baker liner setting tool, cleared rig floor 18:00 - 21 :45 3.75 WINDO ULD CMPL TN PU Whipstock and mills to rig floor, MU Baker seal assembly, 6 jts of 3 1/2" DP for space out and 7 518" Baker btm trip whipstock, milling assembly with LWD/MWD, uploaded MWD and oriented BHA #6, TIH with 4" HWDP to 1,250' 21:45 - 22:15 0.50 WINDO CMPL TN Shallow tested MWD at 1,250' at 300 gpm, 1,000 psi and tool ck ok 22:15 - 00:00 1.75 WINDO CMPL TN RIH with whipstock assembly, BHA #6 from 1,250' to 3,306' 9/13/2004 00:00 - 00:45 0.75 WINDO CMPL TN RIH with whipstock from 3,306' to 4,626' 00:45 - 01 :15 0.50 WINDO CMPL TN Made MADD pass from 4,626' to 4,654' and correlated MWD to K-13 sand 01:15 - 02:00 0.75 WINDO CMPL TN RIH with whipstock from 4,654' to 5,269' 02:00 - 02:15 0.25 WINDO CMPL TN Oriented whipstock to 15 deg left of high side, tagged TOL at 5,302', set whipstock and sheared off from same, st wt up 102K dn WI 71 K 02:15 - 05:15 3.00 WINDO CMPL TN Milled window in 75/8" csg, top of window at 5,068', btm of window at Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 5,080', drilled 63/4" hole to 5,100' MD (32'), 2-6K wob, 60-80 rpm's, 250-270 gpm, 1,450 psi, rot wt 75K, up wt 102K, dn wt 71 K, 6-8K ft-Ibs torque Circ hi vis sweep and circ hole clean, had no increase in cuttings back from sweep, circ at 270 gpm at 1,450 psi, worked mills thru window with no problem Monitored well-static, pumped dry job POOH and LD milling assembly, upper mill in gauge, cleared rig floor Pulled wear bushing and flushed out BOP stack, re-installed wear bushing MU 6 3/4" BHA #7, 1.2 deg 4 3/4" motor, MWD/LWD/PWD, oriented and uploaded MWD, RIH to 257' RIH with BHA #7 from 257' to 2,500' Shallow tested MWD at 2,500', 297 gpm at 1,525 psi, tool checked ok, st wt up 67K, dn 62K RIH with BHA #7 from 2,500' to 5,017' Slip and cut 47' of drlg line, serviced top drive and drawworks Oriented BHA and RIH thru window from 5,068' to 5,080' with no pumps or problems, washed and reamed undergauge hole from 5,082' to btm at 5,100', string up wt 90k, dn wt 70K Drilled 6 3/4" hole from 5,100' to 5,207' MD/3,355' TVD, LWD tool failed, ART 1.2 hrs, AST .4 hrs, 5-12K wob, 90 rpm's, 70 spm, 297 gpm, off btm pressure 1,850 psi, on btm pressure 2,150 psi, off btm torque 3.5K ft-Ibs, on btm 4K, rot wt 78K, up wt 89K, dn wt 69K Backreamed out from 5,207' to window, took several attempts then pulled BHA thru window. Circ btms up at 5,022', 297 gpm, 1,850 psi and 80 rpms Monitored well-static, pumped dry job POOH from 5,022' to 1,846' to change out LWD tools POOH f/1 ,846' to bit. Inspect bit, Down load MWD tools, Change out LWDI MWD tools and program same. Surface test tools, RIH & orient thru window @ 5,080'. Madd pass fl 5,105' to 5,206'. Drill 6-3/4" hole f/5,206' to 6,888' MDI 3,357' TVD (1,682'), ART = 9.5 hrs, AST = 1.7 hrs, WOB 2/12K, RPM 80/120, 320 gpm @ 2250 psi, UP 101 K, DN 63K, ROT 78K, TQ 5500 ftllbs ON 1 5500 ftllbs OFF, Ave. ECD's 10.4 ppg w/8.9 ppg mud, Max gas 854 units, Ave gas 110 units. 12.00 DRILL DRLH PROD2 Drill 6-3/4" hole f/6,888' to 8,009' MDI 3,345' TVD (1,121 '), ART = 4.8 hrs, AST= 3.0 hrs, WOB 2/1 OK, RPM 120,320 gpm @ 2375 psi, UP 105K, DN 55K, ROT 77K, TQ 6000 ftlJbs ON /6000 ftlJbs OFF, Ave. ECD's 10.6 ppg w/8.9 ppg mud, Max gas 178 units. 7.25 DRILL DRLH PROD2 Drill 6-3/4" hole f/8,009' to 8,941' MD/3,329' TVD (1,932'), ART = 4.0 hrs, AST = 1.5 hrs, WOB 2/6K, RPM 90/120, 320 gpm @ 2750 psi, UP 111 K, DN 51 K, ROT 75K, TO 6500 ftllbs ON /6500 ftllbs OFF, Ave. ECD's 10.9 ppg w/ 8.9 ppg mud, Max gas 207 units. 0.75 DRILL TRIP PROD2 Circ evaluate logs for side track, POOH to 8,658' 4.00 DRILL DRLH PROD2 Orient and side track to low side of hole fl 8,663' to 8,860' MDI 3,339' TVD, ART = 1.0 hrs, AST = 1.0 hrs, WOB 2/7K, RPM 90/120, 330 gpm @ 2700 psi, UP 120K, DN 45K, ROT 76K, TO 6000 ftlJb ON /6500 ftllb OFF, Ave ECD's 10.9 ppg w/8.9 ppg mud. 1.25 DRILL DRLH PROD2 Orient and side track to low side of hole f/ 8,860' to 8,941' MD/3,340' TVD, ART = 0.5 hrs, AST = 0.25 hrs, WOB 2/12K, RPM 90/120, 330 05:15 - 06:15 06:15 - 06:30 CMPL TN 06:30 - 10:30 CMPL TN 10:30 - 12:30 CMPL TN 12:30 - 14:00 1.50 DRILL PULD PROD2 14:00 - 14:30 0.50 DRILL TRIP PROD2 14:30 - 14:45 0.25 DRILL DEOT PROD2 14:45 - 16:00 1.25 DRILL TRIP PROD2 16:00 - 17:30 1.50 RIGMNT RSRV PROD2 17:30 - 17:45 0.25 DRILL CIRC PROD2 17:45 - 20:30 2.75 DRILL DRLG PROD2 20:30 - 21 :45 1.25 DRILL TRIP PROD2 21:45 - 22:15 0.50 DRILL CIRC PROD2 22:15 - 22:30 0.25 DRILL OBSV PROD2 22:30 - 00:00 1.50 DRILL TRIP PROD2 9/14/2004 00:00 - 01 :00 1.00 DRILL TRIP PROD2 01 :00 - 02:30 1.50 DRILL TRIP PROD2 02:30 - 06:00 3.50 DRILL TRIP PROD2 06:00 - 07:45 1.75 DRILL TRIP PROD2 07:45 - 00:00 16.25 DRILL DRLH PROD2 9/15/2004 00:00 - 12:00 12:00 - 19:15 19:15 - 20:00 20:00 - 00:00 9/16/2004 00:00-01:15 Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/16/2004 00:00 - 01 :15 1.25 DRILL DRLH PROD2 gpm @ 2750 psi, UP 110K, DN 57K, ROT 78K, TQ 7000 ftIlb ON / 6500 ftIlb OFF, Ave ECD's 10.9 ppg w/8.9 ppg mud. 01:15 - 05:30 4.25 DRILL DRLH PROD2 Drill 6-3/4" hole f/8,941' to 9,423' MD/3,329' TVD (482'), ART= 2.9 hrs, AST= .25 hrs, WOB 2/12K, RPM 90/120, 320 gpm @ 2900 psi, UP 119K, DN 66K, ROT 92K, TQ 6500 ftIlbs ON / 6500 ftIlbs OFF, Ave. ECD's 11.0 ppg w/ 8.9 ppg mud, Max gas 108 units, Pump Hi-vis weighted sweep on last connection. 05:30 - 06:45 1.25 DRILL CIRC PROD2 Finish pumping Hi-vis sweep out of hole - 10 to 15% increase in cuttings. 06:45 - 13:15 6.50 DRILL TRIP PROD2 Monitor well, Back ream out of hole at drilling rate- 320 gpm @ 2900 to 1850 psi, 100 RPM, Pulling rate 40/45 ftImin, No problems- hole in good shape, No problems going thru window @ 5,080' to 5,068'. 13:15 - 14:30 1.25 DRILL CIRC PROD2 Pump Hi-vis sweep and circ hole clean w/3 times btm's up at rate of 320 gpm @ 1850 psi, Monitor well, Pump dry job. 14:30 - 18:00 3.50 DRILL TRIP PROD2 POOH, Stand back HWDP, Jars, NMDC's, Lay down Bit & Motor, Down load & lay down MWD tools, Clear rig floor. 18:00 - 21 :45 RIP CMPL T2 Make up Baker whipstock retrieving tools, Pick up 11 jts. 4-3/4" DC's, 1 jt HWDP, RIH to 5,073'. 21 :45 - 23:30 IRC CMPL T2 Wash & Work whipstock retrieving tool several times and latch onto whipstock on depth @ 5,073' (whipstock slot), Jar loose w/80K over pull. 23:30 - 00:00 0.50 WINDO RIP CMPL T2 Pull and stand back 1 stand drill pipe & single. 9/17/2004 00:00 - 00:30 0.50 WINDO CIRC CMPL T2 Circ btm's up at rate of 5 bpm @ 900 psi. 00:30 - 02:30 2.00 WINDO RIP CMPL T2 Monitor well, POOH slow to 4,400' due to swabbing & Work pipe to make well take proper fill- well finally began taking proper fill, Pump dry job, Drop rabbit. 02:30 - 07:30 5.00 WINDO RIP CMPL T2 POOH, Lay down whipstock and tools, Clear rig floor. 07:30 - 12:00 4.50 CASE PULR CMPL T2 Rig & run 4-1/2" liner, Pick up Baker B1 Flanged Hook Hanger. 12:00 - 13:00 1.00 CASE RUNL CMPL T2 RIH w/liner on drill pipe to window & work thru same, Made it thru window on second try. 13:00 - 16:00 3.00 CASE RUNL CMPL T2 RIH w/liner on drill pipe with no problems, Shoe @ 9,379' 16:00 - 17:30 1.50 CASE CIRC CMPL T2 Hook hanger at bottom of window @ 5,080' w/ Top of liner @ 5,063.13' and Shoe @ 9,379.68', Drop ball, Circ, ball did not seat, drop 2nd 29/32" ball, cir. Ball did not seat. Drop1-3/4" ball, Pressure up and release running tool. Reverse circ and recover ball at surface. 17:30 - 18:00 0.50 CASE CIRC CMPL T2 Rig & reverse circ out ball. 18:00 - 22:00 4.00 CMPL TN TRIP CMPL T2 Monitor well, Pump dry job, POOH & lay down liner running tools. 22:00 - 00:00 2.00 CMPL TN PCKR CMPL T2 Rig & run LEM assembly. 9/18/2004 00:00 - 05:00 5.00 CMPL TN PCKR CMPL T2 RIH w/ LEM assembly to 5,345' w/ top @ 5,010', Latch and pull test LEM to 10K over. 05:00 - 05:45 0.75 CMPL TN PCKR CMPL T2 Drop ball, Pressure up to 3000 psi & Set ZXP Packer, Increase pressure to 4400 psi to lease f/ LEM & neutralize push tool, Close Hydril & test annulus to 1500 psi f/5 min.- OK. 05:45 - 08:15 2.50 CMPL TN CIRC CMPL T2 Stand back 1 stand, Rig & attempt to shear out ball w/ 6000 psi - No good, Rig & reverse circ ball out of pipe at rate of 3.5 bpm @ 700 psi. 08:15 - 12:30 4.25 CMPL TN TRIP CMPL T2 Monitor well, Pump dry job, POOH & lay down LEM running tool. 12:30 - 17:00 4.50 WELCT BOPE CMPL T2 Pull wear bushing, Rig & test BOPE to 250 psi low & 3000 psi High, Test witnessed by AOGCC Jhon Crisp, Install wear bushing. 17:00 - 19:00 ULD CMPL T2 Make up 'D' Lateral whipstock & mill assembly, Orient & Make up MWD. 19:00 - 23:00 RIP CMPL T2 RIH slow w/ whipstock assembly to 4,330'. 23:00 - 23:30 CIRC CMPL T2 Madd pass & log f/4,330' to 4,360'. 23:30 - 00:00 RIP CMPL T2 Continue RIH to 4,962'. Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: Orient whipstock 16 deg. Left, Tag top of liner w/ No-Go @ 5,010' & Seals @ 5,014', Set trip anchor, Shear off f/ bolt w/ top of whipstock @ 4,799'. Mill window f/4,799' to 4,811', Mill guage mill out window with btm. mill @ 4,830', WOM 2/4K, 80 RPM, 270 gpm @ 1750 psi, TQ 5/9,000 fVlb. Pump Hi-vis weighted sweep & ream out window. Monitor well, Dry pipe, POOH & Lay down mill assembly (All mills in guage). Pull wear bushing, Wash out stack, Reinstall wear bushing, Make up BHA #11, Orient tools, Program MWD/LWD. RIH to 2,100', Shallow test MWD tools, RIH to 4,740'. Cut & slip drilling line 61'. Orient motor, Slide thru window f/4,799' to 4,811' with no problem, Wash to 4,830'. Drill 6-3/4" hole f/ 4,830' to 5,673' MD/3,300' TVD (843'), ART = 3.8 hrs, AST = 1.9 hrs, WOB 2/5K, RPM 90, 300 gpm @ 1800 psi, UP 98K, DN 66K, ROT 78K, Torque 4000 ft/lbs ON /6500 ft/lbs OFF, Ave. ECD's 10.0 ppg w/8.9 ppg mud, Max gas 744 units. 12.00 DRILL DRLH PROD3 Drill 6-3/4" hole f/5,673' to 6,608' MD/3,290' rvD (935'), ART = 7.5 hrs, AST= 1.1 hrs, WOB 2/12K, RPM 90/120, 300 gpm @ 2000 psi, UP 102K, DN 63K, ROT 77K, Torque 6000 ft/lbs ON /6000 ft/lbs OFF, Ave. ECD's 10.4 ppg w/8.9 ppg mud, Max gas 586 units. 12.00 DRILL DRLH PROD3 Drill 6-3/4" hole f/6,608' to 8,075' MD/ 3,284' TVD (1,467'), ART = 8.6 hrs, AST= 0.5 hrs, WOB 2/6K, RPM 90/100, 310 gpm @ 2100 psi, UP 115K, DN 53K, ROT 76K, Torque 7000 ft/lbs ON /7000 ft/lbs OFF, Ave. ECD's 10.5 ppg w/ 8.9 ppg mud, Max gas 541 units. 3.25 DRILL DRLH PROD3 Drill 6-3/4" hole f/8,075' to 8,380' MD/3,280' rvD (305'), ART = 2.0 hrs, AST= 0.0 hrs, WOB 2/12K, RPM 100/120, 310 gpm @ 2450 psi, UP 112K, DN 52K, ROT 76K, Torque 7000 ft/lbs ON / 7000 ft/lbs OFF, Ave. ECD's 10.5 ppg w/ 8.9 ppg mud, Max gas 664 units. 1.00 RIGMNT RGRP PROD3 Change out top drive saver sub, Work pipe several times between operations. 12.25 DRILL DRLH PROD3 Drill 6-3/4" hole f/8,380' to 9,417' MD/ 3,258' rvD (1,037'), ART= 9.0 hrs, AST= 0.5 hrs, WOB 2/12K, RPM 100/120,310 gpm @ 2600 psi, UP 128K, DN 55K, ROT 85K, Torque 8000 ft/lbs ON /8000 ft/lbs OFF, Ave. ECD's 10.9 ppg w/8.9 ppg mud, Max gas 978 units, Pump Hi-vis weighted sweep on last connection. Finish pumping Hi-vis sweep out of hole - 10 to 15% increase in cuttings. Monitor well, Back ream out of hole at drilling rate- 310 gpm @ 2600 to 1850 psi, 100 RPM, Pulling rate 40/45 ft/min, No problems- hole in good shape, No problems going thru window @ 4,811' to 4,799'. Pump Hi-vis weighted sweep, Circ hole clean w/3 times btm's up (Hole appeared clean, No noticeable increase in cuttings). Monitor well, Pull 5 stands and observe for swabbing, Pump dry job, POOH & lay down BHA (Hole took good fill). Make up Baker whipstock retrieving tools, RIH to 4,805'. Work pipe & Hook whipstock, Pull Anchor loose w/ 40K over. Monitor well, Pump dry job, Drop rabbit, POOH & lay down whipstock & tools. Clear rig floor, Rig to run 4-1/2" liner, PJSM. Pick up 4-1/2", 12.6#, L-BO, DWC slotted liner and pick up Baker Hook Hanger as per detail. 00:15 - 04:45 CMPL T2 04:45 - 05:30 CMPL T2 05:30 - 09:30 CMPL T2 09:30 - 10:30 1.00 WELCT CMPL T2 10:30 - 12:00 1.50 DRILL PROD3 12:00 - 14:00 2.00 DRILL TRIP PROD3 14:00 - 15:00 1.00 RIGMNT RSRV PROD3 15:00 - 15:30 0.50 DRILL REAM PROD3 15:30 - 00:00 8.50 DRILL DRLH PROD3 9/20/2004 00:00 - 12:00 12:00 - 00:00 9/21/2004 00:00 - 03:15 03:15 - 04:15 04:15 - 16:30 16:30 - 17:30 1.00 DRILL CIRC PROD3 17:30 - 00:00 6.50 DRILL TRIP PROD3 9/22/2004 00:00-01:15 1.25 DRILL CIRC PROD3 01 :15 - 06:45 5.50 DRILL TRIP PROD3 06:45 - 09:45 3.00 WINDO RIP CMPL T3 09:45 - 10:15 0.50 WINDO RIP CMPL T3 10:15 - 15:00 4.75 WINDO RIP CMPL T3 15:00 - 16:00 1.00 CASE RURD CMPL T3 16:00 - 19:30 3.50 CASE PULR CMPL T3 Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/22/2004 9/23/2004 9/24/2004 3.00 CASE RUNL CMPL T3 RIH w/liner on drill pipe (Oriented thru window first time), Ran liner to btm @ 9,402' with no problems 1.00 CASE OTHR CMPLT3 Drop 29/32" ball, Check UP wt. of 122K, DN 71K, Hook Hanger @ 4,811' (first time down), Unhook turn 1/4 turn and bypass window 10', Turn Hook 1/4 turn and bypass window again, Turn Hook 1/4 tum and Hook Hanger 1.57' low @ 4,812.57' w/ Top of liner @ 4,795.72' & Guide Shoe @ 9,401.98', Set 36K down on Hook, Pump down ball at rate of 2 bpm @ 370 psi, Release from Hanger w/ 3500 psi, Pull up to 9,353' (Lost 14K liner weight), Rig & shear out ball w/4200 psi. Observe well, Circ btm's up at rate of 5 bpm @ 1100 psi. Monitor well, Pump dry job, POOH & lay down liner running tools. Lay down 4" drill pipe from off drillers side of derrick. Rig & pick up 138 joints 4-1/2",12.6#, L-80, IBT Tubing for completion string. POOH and stand back 4-1/2" tubing on off drillers side. Rig & lay down remaining drill pipe and collars from drillers side of derrick. Pull wear bushing. Clear rig floor, Rig to run ESP completion string. Service top drive. PJSM, Pick up Centrilift ESP Completion, Guage, Motor, Seal section, Screen Intake, Service same w/ oil, Connect Esp cable & check same. RIH slow running cable & Installing Cannon clamps every other joint & checking cable conductivity every 1000' to 4,420', Make up hanger, Make final cable splice to wellhead penetrator. Found Penetrator connector to be incorrect tread, and correct one not in state, Wait on Orders Wrap and secure ESP Cable below tubing hanger (With out connecting to hanger), Land string as per detail w/ Tail @ 4,470', Pump guage @ 4,466', Motor @ 4,432', Seal Section @ 4,418' (64.2 deg), GLM #1 @ 3,800' MD ( 2866' TVD), GLM #2 @ 3,006' MD ( 2388' rvD) Parts used on ESP cable; 3 - Protectolizer guards= OD 5.875" 2 - Flat guards= OD 5.625" 15 - Flat stainless steel bands 76 - Cannon clamps= 6.75" 1.00 WELCT NUND CMPL TN Lay down landing joint, Install 2 way check, Rig & flush out BOP stack w/ wash tool. 1.50 WELCT NUND CMPL TN Nipple down BOPE. 1.50 WELCT NUND CMPL TN Nipple up & test Vetco Gray Tree to 250 psi low and 5000 psi High. 1.50 CMPL TN FRZP CMPL TN Pull 2 way check, Rig & Freeze protect well w/185 bbls diesel, Pumping down 7-5/8" x 4-1/2" annulus thru Screen intake @ 4,408' with returns up 4-1/2" tubing, Had good diesel to surface. 1.00 CMPL TN OTHR CMPL TN Rig lubricator, Install BPV, Install blind flanges to wellhead, Secure well, Remove scaffolding, Record pressures of 10-3/4" x 7-518" = 150 psi, 7-5/8" x 4-1/2" = 225 psi, 4-1/2" tubing = 100 psi. Note; Release rig to move to 1 E-114 at 24:00 hrs 9/24/2004. 19:30 - 22:30 22:30 - 23:30 23:30 - 00:00 0.50 CASE CIRC CMPL T3 00:00 - 03:00 3.00 CASE CIRC CMPL T3 03:00 - 08:00 5.00 DRILL PULD CMPL T3 08:00 - 12:00 4.00 CMPL TN RUNT CMPL T3 12:00 - 14:30 2.50 CMPL TN TRIP CMPL T3 14:30 - 19:30 5.00 DRILL PULD CMPL T3 19:30 - 20:00 0.50 CMPL TN PULD CMPL T3 20:00 - 23:30 3.50 CMPL TN RURD CMPL T3 23:30 - 00:00 0.50 RIGMNT RSRV CMPL T3 00:00 - 03: 15 3.25 CMPL TN PULD CMPL TN 03:15 - 15:00 11.75 CMPLTN RUNT CMPL TN 15:00 - 17:00 2.00 WAlTON ORDR CMPL TN 17:00 - 17:30 0.50 CMPL TN SOHO CMPL TN 17:30 - 18:30 18:30 - 20:00 20:00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 Printed: 10/11/2004 3:38:27 PM ",,/ ConocoPhillips . ConocoPhillips Alaska, Inc.,Slot #166 Pad iE, Kuparuk River Unit, North Slope, Alaska SURVEY U.G Page 1 Wellbore: 166 L2 Well path: MWD w/Mag-Sag<4811-9417'> Date Printed: 1i-0ct-2004 r&i. BAKER HUGHES INTEQ ~RbO" 166 L2 I creat~ 20-Se 2004 I Last R;ViSed 22-Se -2004 'I Iwen ~ I Govemment ID I ~~e~~;6~~d Pad 1E Installation,. 1~_lJ"' IE sti a ~87754 6208 I NOrthi:ï 8985 8206 I~~~ I~Aiqm'" 1 .. . - - . R - 'RIOAN DATUM 1927 _m · . Tru. 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 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7140.33 Feet on azimuth 166.46 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ¥ ConocoPhillips . ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit, North Slope, Alaska SURVEY LaG Page 2 Wellbore: 166 L2 Well path: MWD w/Mag-Sag<4811-9417'> Date Printed: 11-0ct-2004 r&ií. BAKER IIUGIIE5 INTEQ Wellpath (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severit) Vertical Easting Northing Positionl),) PositionlX) Section1ftl 4799.00 74.57 1R95R ~2RORR 1754nF nnn ?<\Qn Q1 <;<;1R<;Q Rn 4811.94 76.41 1R9.55 <\?R<\ Q? 14 ?4 ?4n<\ ?<\ <;<;1RR1 OR An 4872.24 79.98 170.00 3296.26 2461.31S 1766.98E 5.97 2461.31 551672.82 5956990.40 49R5.5~ 8R.50 17054 ~~072~ rlVh:il- 7 n1 ?Ç;?';7 <;<;1RRQ n7 <;n<;044 0?4<\ 17? 1<\ <\<\nR 11 R54 ?R4<; <\R "''''A7n"" A? r:.7 5152.99 91.60 172.06 3304.82 2737.96S 1809.62E 0.89 2737.96 551717.29 5956714.06 524R.R4 90.46 17?07 ~~m14 LK:ilJ. liS 1 ?? ?R<\n 7n <;<;17<\n R<\ 5956621.42 5339.79 89.72 171.36 <\<\n? QQ 1R<\<;.Q7E un ?Q?? RR <;<;1744.RR <\r:. 5431.30 91.35 171.56 3302.13 3013.36S 1849.56E 1.79 3013.36 551759.05 5956438.96 5525.40 90.25 171.56 3300.82 3106.4~S 1RR<\.<\7~ 1 17 <\ 1 nR.4<\ <;<;177<\AR <;R?1.Ro 00.1' 17<\.40 <\<\00 <;1 <\?01.Qn~ 1R7<;.00E ?01 <\?01 00 r:.r:.17AR.R4 ~~ 5715.23 90.49 172.60 3300.01 3294.75S 1887.22E 1.03 3294.75 551798.58 5956157.86 <;ROR.<\7 Ro.RO 172.44 <\200.04 <\<\R7.1n~ 1 Roo.<\<;E 0.07 <\<\R710 <;51R11 <\1 ~~ 5900.4~ 90.RO 1 RO.1 R 3?00 R? ~77.oR~ 1014.0RE ~.79 <\477!iR -.;;;.1R2R.R.<\u .R5 5995.13 91.38 167.91 3297.82 3570.75S 1932.88E 1.45 3570.75 551846.06 5955882.19 ROR7 37 0141 1RR 47 3?0<; <;7 3RR1 01~ 10<;1 7R~ o R1 3RR1 01 ~ n7 R1R?17 R979 171 1<; 3?04 <;R ~7~' ~~~ ~~O ~ ·<;<;1RR? Q? q1 6275.24 89.57 173.80 3295.10 3846.56S 1980.71E 2.86 3846.56 551895.72 5955606.74 R3RR 7Q 000? 17R O? 3?C\4 70 ? 7R 3030 73 ~ R<\ R4R~R~ R979 17R n 3?C\4 11 140 ~ -"'<;1Q11 ?7 rut 6556.42 92.76 177.09 3292.05 4127.00S 2000.02E 3.23 4127.00 551916.89 5955326.46 RR40 C\4 00 R1 17<; rut 3?RO 30 ~~~~ ..- 31R 4??0 ?4 ~ ?7 R74?R5 RRR~ 17? 3? 3?Ro 75 ~50 ~ -"<;1Q<\47R .01 6836.21 87.52 173.53 3292.72 4405.18S 2028.16E 1.91 4405.17 551946.87 5955048.50 Ro?o R 1 oO.oR 17R.13 3?03 0<; AAOA 17'" ?03R.<;7~ 4R3 4<1oR 1R r:.r:.10,,<;Q¡) <;R 7023.7~ R9~~ 177 01 3?03 Rq 45q? 11~ 1.qq 4<;0?11 -.;.;.¡ QR?1 <; RR 7116.83 90.12 177.42 3294.14 4685.10S 2046,72E 0.96 4685.10 551967.29 5954768.74 7?OR.RR Rq.q7 177.43 32q4.07 477R.RR~ ?O<;O.R<;E o 1R 477R.AR ~7?M 5q54R7702 7302.10 91.78 1R1.02 ~2q2.R4 4R70.?4S 2052.11E 4.<\n ~?4 <;<;1073.01 RR 7395.14 89.17 180.62 3291.87 4963.26S 2050.78E 2.84 4963.26 551973.19 5954490.64 74RqR7 q175 1R1 q3 3?q1 11 ~I)~I I~S 30R ~ -';<;1 Q71 7? .14 75R2.72 90.03 1R~ 15 ~2RqRR ~l h~S ~n, ~~_ ? ?7 <;1<;n RQ <;<;1 QRR ?1 .18 7676.71 90.03 185.15 3289.61 5244.43S 2037.76E 2.13 5244.43 551962.03 5954209.41 77RqC\4 9092 1R<; 7R ~?RRR4 5~~7n~ 1 1R ~ ~".'n"..., 7n .56 7863.96 90.67 1R7.47 <\?R7 ""'- r:.A,>n ",.,'" ?n1 R n7~ 1M ""'-<\nR? "''''AnA''' "'0 1? 7957.42 91.44 187.23 3285.82 5523.29S 2006.11E 0.86 5523.29 551932.24 5953930.37 8051.13 90.25 1R914 ~2R4.4~ r:."1" n",,,, ? 4n <;R1R n<\ __ .n'~ ~~ 'r:.R R144 <;0 qOO? 1 RQ 11 3?R3 4R r:.7nA ??'" on <;70R ?1 r:.r:..;c:m¡; <\<\ r:.0r:.<\7i1r:. ?Q 8237.19 90.61 188.82 3282.24 5799.76S 1963.52E 0.46 5799.76 551891.50 5953653.65 8330.18 91.01 192.27 3280.93 <;RQ1 1 R~ 1Q4R.<;1~ 373 <;RQ1 1R <;51R7<;.00 5053<;R?1 R R424.R7 R90<; 10?M 3?RO.RR <;qR3.30~ 1 O?<; 07~ ?1R 5qR3.3q r:.r:..¡¡w;: 17 r:.Q<;<td.RQ Rn 8519.13 92.73 195.25 3279.41 6074.99S 1903.06E 4.66 6074.99 551832.86 5953378.06 RR11.R5 q1.01 10<;.""'- 327R.30 R1R4 14~ 1R7R.<;1E 1.Rq R1R4 14 ~~, nnn n, r:.O<;<\?RR 7R R705.71 90.09 1 Q3.R<; 3?7<; 4Q R25511~ 1 R<;4. R<;F ?05 R?<;<;.11 -.;;;.1 7R<;.RR 5953197.64 8799.12 90.83 194.99 3274.74 6345.57S 1831.39E 1.45 6345.58 551763.00 5953107.03 RRQO OQ Q? ?1 10541 3?7? .3? R433.33~ 1 R07 <;<;F 1.<;Q R433.33 ~~¡.; 595~019.1~ R979R7 9123 1QR 11 3?RQ R4 R<;1Q r:.n", 17A<\ ?<\¡:: 1 <\4 ~ <;Q<;?Q<\? R1 9070.71 91.44 193.37 3267.51 6607.51S 1760.07E 3.02 6607.51 551693.43 5952844.65 Q1RO 73 Q13? 1 C\4 40 3?R<; 3<; RROil AA'" '7~n 'n_ 1 1<; RRC\4 RR ~.;:..;.,~ <;Q<;?7<;71R 9?50RR 92~~ 1Q477 3?R?4R R7R? nR'" 171<; 7QF 1 1Q p.~ 9340.51 91.32 195.96 3259.62 6868.45S 1692.05E 1.74 6868.46 551627.15 5952583.29 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 99.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7140.33 Feet on azimuth 166.46 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~illips . ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit, North Slope, Alaska SURVEY ulm Page 3 Wellbore: 166 L2 Well path: MWD w/Mag-Sag<4811-9417'> Date Printed: 11-0ct-2004 "1. BAKER HUGHES INTEQ Northing 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 99.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7140.33 Feet on azimuth 166.46 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ¥ ConocoPhillips . ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit, North Slope, Alaska SURVEY LING Page 4 Well bore: 166 L2 Well path: MWD w/Mag-Sag<4811-9417'> Date Printed: 11-0ct-2004 J&ii. BAKER HUGHES INTEQ H.oleSections Start MDft Wellbore Casin s Name Top Top Top Shoe Shoe Shoe Shoe Wellbore O.OON 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 99.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7140.33 Feet on azimuth 166.46 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated · (IT) rE Œ\ n ~\ ~ rY( UJJ If LJdu l1 ~,1 ci2) LI\.\ -- / ¡ , ì / i ! FRANK H. MURKOWSKI, GOVERNOR AlfASIiA. OIL AND GAS CONSERVATION COMMISSION í 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 1E-166L2 ConocoPhillips Alaska, Inc. Permit No: 204-155 Surface Location: 147' FNL, 640' FEL, SEC. 21, T11N, RlOE, UM Bottomhole Location: 1809' FNL, 1077' FWL, SEC. 27, T11N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1E-166, Permit No. 204-153, API 50-029-23220. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 (pager). BY ORDER OF THE COMMISSION DATED this~day of August, 2004 cc: Department offish & Game, Habitat Section w/o enc1. Department of Environmental Conservation w/o encl. . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION . 4Áì PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill 0 RedrillU 1 b. Current Well Class: Exploratory D Development Oil 0 Multiple Zone 0 Re-entry D Stratigraphic Test D Service D Development Gas D Single Zone 0 2. Operator Name: 5. Bond: 0 Blanket D Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1E-166L2 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 9463' TVD: 3320' Kuparuk River Field 4a. Location of Well (Govemmental Section): 7. Property Designation: Surface: 147' FNL, 640' FEL, Sec. 21, T11 N, R10E, UM ADL 25651 & 25660 West Sak Pool Top of Productive Horizon: 8. Land Use Pennit: 13. Approximate Spud Date: 2516' FNL, 1112' FWL, Sec. 22, T11N, R10E, UM ALK 469 & 470 9/20/2004 Total Depth: 9. Acres in Property: 14. Distance to 1809' FNL, 1077' FWL, Sec. 27, T11N, R10E, UM 2560 Nearest Property: 6357' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 549890 y- 5959440 Zone- 4 (Height above GL): 28 feet Well within Pool: 1E-112L2,1044' 16. Deviated wells: 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Kickoff depth: 4853' ft. Maximum Hole Angle: 91.40 Downhole: 1483 psig Surface: 1087 psig 18. Casing Program Setting Depth Quantity of Cement Size SDecifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5/40.5 L-80 BTC 2172/691 ' 28' 28' 2891' 2300' 510 sx ASLite, 180 sx DeepCrete 9-7/8" 7-5/8" 29.7# L-80 BTCM 6088' 28' 28' 6116' 3516' 290 sx DeepCrete - ~ 6.75" 4.5" 12.6# L-80 DWC 4634' 4823' 3275' 9457' 3250' slotted liner - 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (It): Total Depth TVD (It): Plugs (measured) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Casing Length Size Cement Volume MD rvD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): üV Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch0 Drilling Program 0 Time v. Depth Plot D Shallow Hazard Analysis U Property Plat 0 Diverter Sketch D Seabed Report D Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve McKeever @ 265-6826 Printed Name Randy Thomas Title Kuparuk Drilling Team Leader Signature ~I!-~ ~ r f.-~j "Tko ....(þPhone 2'-5' -" $l¿'" Date 1'/13/0f Prpn"red b" Sharon Al/suD-Drake Commission Use Only Pennit to Drill API Number: Penn it Approval See cover letter Number: Z.O¿¡ - / S ç 50- 0..2.. c; - .2 .3.2.- 20 - ~ } Date: for other requirements Conditions of approval : Samples required D Yes ~ No Mud log required DYes ~ No Hydrogen sulfide measures D Yes ~ No Directional survey required I8J Yes D No Oth" ~~~~",,^~ð. ~~"'''~\~\'.~''(''~~\c..cI<.A~....e''-..\ "-C;-~..l k. /71/;//,1"" BY ORDER OF gk ~ Approved. A .,. vV' \ ~ THE COMMISSION Date: 4f..3' IJ ~ Form 1~ReV~2I2003 - / I , Submit in Du licate ORIGINAL p · APpen for Permit to Drill, Well 1 E-166L2 Revision No.O Saved: 11-Aug-04 Permit It - West Sak Well #1 E-166L2 Application for Permit to Drill Document M(lximiZE Well V( IU~ Table of Contents 1. Well Name ......................... .... ........... ...... .......................... ............... ..... .......... ... ........ 2 Requirements of 20 AAC 25.005 (f). .... ............ ..... .... ........ ...... ...... ........... ....... ...... ....... .......... ........ .........2 2. Location Summary .............. .... ........ ..... ......................... .............. ....... ....... ... ............ 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........................................... 4 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................4 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ...................................................................................5 Requirements of 20 AAC 25.005(c)(7) .. ............ .......... ........ ...... ........... ............ ... .......... ............. ............ 5 8. Drilli ng FI uid Program .. ........................... ... .............. .................... .......... ............. .... 5 Requirements of 20 AAC 25.005(c)(B) ...................................................................................................5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ...........................................................................5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 1 o. Seismic Analysis ......................... .................. ...... ............................... .... ......... .......... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................5 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bonding ...............................................................................................6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................6 1E-166L2 PERMIT IT. doc Page 1 of 7 Printed: 11-Aug-04 · AP.on for Permit to Drill, Well1E-166L2 Revision No.O Saved: 11-Aug-Q4 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments. ............. ........ ... ............. ............. ........ ............ ........ ......... ........... .... ...... 7 Attachment 1 Doyon 141 West Sak 20043 ksi BOP Configuration (1 page) ....................................... 7 Attachment 2 Directional Plan (6 pages) ...............................................................................................7 Attachment 3 Drilling Hazards Summary (1 page) ................................................................................7 Attachment 4 Well Schematic (1 page) ................................................................................................. 7 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 tIle commission under 20 MC 25.040(b). For a we!! with multiple wel! branc/le~ each branch must similarly be itk fied by a unique name and API number by adding a suffìx to the flame designated for the well by the operator and to the number a . 'fled to the well by the commission. The well for which this Application is submitted will be designated 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface" at the top of each objective formation, and at total depth, referenced to govemmental section lines. (8) the coordinates of the proposed location of the well at the surface" referenced to the state plane coordinate system for this ~tate 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 (lE-166 Well bore) ASP Zone 4 NAD 27 Coordinates Northings: 5,959,440 Eastings: 549,890 I 147' FNL, 640' FEL, Section 21, T11N, Rl0E, UM I I RKB Elevation I Pad Elevation I 98.4' AMSL 70.4' AMSL Location at Top of Productive Interval West Sak "D" Sand ASP Zone 4 NAD 27 Coordinates Northings: 5,957,082 Eastings: 551,663 2516' FNL, 1112' FWL, Section 22, T11N, Rl0E, UM Location at Total De th ASP Zone 4 NAD 27 Coordinates Northings: 5,952,510 Eastings: 551,668 4823 3275 3176 1809' FNL 1077' FWL Section 27 TUN Rl0E UM Measured De th RKB: 9 463 Total Vertical De th RKB: 3 320 Total Vertical De th 55: 3 221 and (D) other information required by 20 AAC 25.0S0(b); tE-166L2 PERMIT IT. doc Page20f 7 Printed: 11-Aug-04 · APpen for Permit to Drill, Well 1 E-166L2 Revision No.O Saved: 11-Aug-04 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated- the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores witllin 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete weIl1E-166L2. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled "Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). Immediately prior to running the intermediate string of 7-5/8" casing, a test plug will be set below the lowermost rams, and those rams will be closed and tested to 3,000 psi on a 7-5/8" aD. 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 encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The ex~eservoir pressures in the West Sak sands in the 1E-166L2 area vary from 0.42 to 0.45 psi/ft, or 8.0 to 8.6 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole presSùì"ê d~ from the nearby West Sak well 1E-119. 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 A2 sand formation is 1,087 psi, calculated thusly: MPSP =(3,296 ft)(0.45 - 0.11 p~i/ft) (8) data 0 The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 1 E-166L2 PERMIT IT. doc Page 3 of 7 Printed: 11-Aug-04 · APan for Permit to Drill, Well 1 E-166L2 Revision No.O Saved: 11-Aug-04 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 inte-;¡rity tests, as required under 20 MC 25.030(f}; No formation integrity test will be performed in the drilling of 1E-166L2 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 tbe following items,. except for an item already on file with the commission and identified in tbe application: (6) a complete proposed casing and cementing program as required by 20 MC 25.03~ and a description of any slotted linet; pre- perforated linet; or screen to be installed; Casing and Cementing Program I See also Attachment : Cement Summary Hole Top Btm CsgITbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (/b/ft) Grade Connection rfð (ft) (ft) Cement Proaram 20 X 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE 10-3/4 13-1/2 45.5 L-80 BTC 2172 28 / 28 2200 /1855 Cemented to 40.5 691 2200 / 1855 2891 / 2300 Surface with 510 sx ASUte Lead, 180 sx DeepCRETE Tail 7-5/8 9-7/8 29.7 L-80 BTCM 6088 28 / 28 6116 / 3516 Cement Top planned @ 4300' MD I 3088' TVD. Cemented wi 290 sx DeeDCRETE 4-1/2 6-3/4" A2 12.6 L-80 Grant 3719 5916/ 3481 9635 / 3509 Slotted- no slotted Sand Prideco cement Lateral (lE- 166) DWC/C 4-1/2 6-3/4" B 12.6 L-80 Grant 4361 5102/ 3340 9463 / 3320 Slotted- no slotted Sand Prideco cement , ..., ( cc ' -- ,. - DWC/C - 166 L1) 4-1/2 6-3/4" 12.6 L-80 Grant 4634 48231 3275 9457 I 3250 Slotted- no slotted D Sand prideco cement Lateral DWCIC (IE-166 L21 ( ~ 1E-166L2 PERMIT IT.doc Page 4 of 7 Printed: 11-Aug-04 · APpen for Permit to Drill, Well 1 E-166L2 Revision No.O Saved: 11-Aug-04 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 follow¡i1g item~ except for an Item already on tile with the commission and identitied 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); No diverter system will be used during operations on lE-166L2 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following ¡tem~ except for an Item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling flUId system, as required by 20 MC 25- 033,; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Value 9.0 Densit Plastic Viscostiy Ibl100 sf Yield Point cP A2/BID sand laterals HTHP Fluid loss (m1130 min @ 200psi & 150· Oil I Water Ratio Electrical Stabilit 15-25 18-28 <4.0 80 / 20 >600 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 Rig 141. 9. 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 Item~ except for an item already on tile with the commission and identified in the application: (9) for an exploratory or stratigraphic test well a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25-033(fJr' Not applicable: Application is not for an exploratory or stratigraphic test well. 10. 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 itemSr except for an item already on file with the commission and Identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25-061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1£-166L2 PERMITlT.doc Page 5 of 7 Printed: 11-Aug-04 · AP.on for Permit to Drill, Well 1 E-166L2 Revision No.O Saved: 11-Aug-04 11. 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 dnlled from an offshore platfonrl¡ mobile bottom-founded structure, jack-up rig or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061{b}/ Not applicable: Application is not for an offshore well. 12. 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 tile with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met· Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. 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 is listed below. Please refer also to Attachment 4, Well Schematic. Note: Previous operations are covered under the lE-166, and lE-166Ll Application for Permit to Drill. . 1. Make up junction isolation 1 re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. 2. Run and set Baker WindowMaster whipstock system, at window point of 4,823' MD / 3,2,75' lVD, the top of the D sand. 3. Mill 6-3/4" window. POOH. 4. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 5. Drill to TD of D sand lateral at 9,457' MD / 3,250' lVD, as per directional plan. 6. POOH, back reaming out of lateral. POOH. 7. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 8. PU and run 4-1/2" slotted liner. 9. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. Release hanger running tool. 10. POOH, laying down drill pipe as required. 11. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 12. Nipple down BOPE, nipple up tree and test. 13. Set BPV and move rig off. 14. Freeze protect well with diesel by pumping into 4-1/2" x 7-5/8" annulus, taking returns from tubing and allowing to equalize. 15. Rig up wire line unit. Pull BPV 16. Set gas lift valves in mandrels. Operate well on gas lift for +1- 180 days. Shut well in. 17. Rig up wireline. Replace gas lift valves with blank dummy valves. Run ESP through tubing. 18. Operate well with ESP. 1£-166L2 P£RMIT IT. doc Page 6 of 7 Printed: 11-Aug-04 · APan for Permit to Drill, Well 1 E-166L2 Revision No.O Saved: 11-Aug-04 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dnll mustc be accompanied by each of the following items¡ except for an item already on fiie 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 MC 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. ConocoPhillipS Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Doyon 141 West Sak 20043 ksi BOP Configuration (1 page) Attachment 2 Directional Plan (6 pages) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 Well Schematic (1 page) 1E-166L2 PERMIT IT. doc Page 7 of 7 Printed: "-Aug-04 --^"í'" Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. ..J..!\r 13-5 Annular ~ To be tested to 250 psi and 1,500 psi at initial ~ installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-Yz" to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. oil( Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves ~ To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. ~ 13-5 Single Ram Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" To be tested to 250 psi and 3,000 psi only before running casing. ~ Wellhead Valves tested to 3,000 psi upon assembly y ConocoPhillips Alaska Doyon 141 West Sak 3 ksi BOP Configuration 13-5 BOP 3K diagram.vsd Sheet 1 of 1 prepared by Steve McKeever 8/1112004 . . C~illips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Well bore: 166L2 Wellpath: 166L2 Ver#3 Date Printed: 29-Jul-2004 r... BAKlR HUGHIS INTEQ Wellbore Name I Created I Last Revised 166L2 111-F eb-2004 I 26-Jul-2004 17 59.8686 35 45.4138 Installation Name Pad 1 E Eastin 550528.1946 Field Name Ku aruk River Unit Eastin 487754.6208 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7154.92 Feet on azimuth 165.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . ConocciPhillips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska . PROPOSAL LISTING Page 2 Well bore: 166L2 Wellpath: 166L2 Ver#3 Date Printed: 29-Jul-2004 B.. SW:'. INTEQ Welloath Reoort MD[ft] Inc[deg] Azi[deg) TVD[ft) Vertical North[ft) East[ft) Station Station ! Dogleg I Vertical Station Comment Depth SS Position(Grid Position(Grid I [deg/1 0 Section[f North) East! i Oft! II 4823.18 75.00 172.00 3275.00 3176.00 2369.64S 1757.77E 5957082,00 551663.00 0.00 2369.64 TOD WhiDstock Face Tie on 4835.18 76.91 172.00 3277.91 3178.91 2381.16S 1759.39E 5957070.48 551664.70 15.90 2381.16 Base WhiDstock Face End of Build 4853.18 76.91 172.00 3281.99 3182.99 2398.53S 1761.83E 5957053.14 551667.25 I 0.00 2398.53 End Milled ODenhoJe KOP End of Hold 4953.18 82.91 172.00 3299.51 3200.50 2495.98S 1775.53E 5956955.79 551681.59 6.00 2495.98 5053.18 88.91 172.00 3306.64 3207.64 2594.71S 1789.40E 5956857.17 551696.12 6.00 2594.71 5069.35 89.88 172.00 3306.81 3207.81 2610.715 1791.65E 5956841.18 551698.48 6.00 2610.71 End of Build 5169.35 92.88 172.00 3304.40 3205.40 2709.705 1805.57E 5956742.30 551713.04 3.00 2709.70 End of Build 5200.00 92.88 172.00 3302.86 3203.86 2740.028 1809.83E 5956712.01 551717.51 0.00 2740.02 5300.00 92.88 172.00 3297.84 3198.84 2838.92S 1823.72E 5956613.21 551732.06 0,00 2838.92 5370.79 92.88 172.00 3294.29 3195.29 2908.93S 1833.57E 5956543.27 551742.36 0.00 2908.93 End of Hold 5470.79 89.88 172.00 3291.89 3192.88 3007.925 1847.48E 5956444.39 551756.93 3.00 3007.92 End of Droo 5500.00 89.88 172.00 3291.95 3192.95 3036.848 1851.54E 5956415.50 551761.19 0.00 3036.84 5600.00 89.88 172.00 3292.16 3193.16 3135.875 1865.46E 5956316.57 551775.76 0.00 3135.87 5700.00 89.88 172.00 3292.37 3193.37 3234.905 1879.38E 5956217.65 551790.33 0.00 3234.90 5800.00 89.88 172.00 3292.59 3193.59 3333.928 1893.29E 5956118.73 551804.91 0.00 3333.92 5900.00 89.88 172.00 3292.80 3193.80 3432.958 1907.21E 5956019.81 551819.48 0.00 3432.95 6000.00 89.88 172.00 3293.01 3194.01 3531.98S 1921.13E 5955920.89 551834.05 I 0.00 3531.98 6100.00 89.88 172.00 3293.22 3194.22 3631.00S 1935.05E 5955821.96 551848.63 0.00 3631.00 6200.00 89.88 172.00 3293.44 3194.44 3730.035 1948.96E 5955723.04 551863.20 0.00 3730.03 6300.00 89.88 172.00 3293.65 3194.65 3829.06S 1962.88E 5955624.12 551877.77 0.00 3829.06 6400.00 89.88 I 172.00 3293.86 3194.86 3928.088 1976.80E 5955525.20 551892.34 0.00 3928.08 I 6500.00 89.88 172.00 3294.08 3195.08 4027.118 1990.71E 5955426.27 551906.92 0.00 4027.11 6600.00 89.88 172.00 3294.29 3195.29 4126.148 2004.63E 5955327.35 551921.49 0.00 i 4126.14 6700.00 89.88 172.00 3294.50 3195.50 4225.168 2018.55E 5955228.43 551936.06 0.00 4225.16 6800.00 89.88 172.00 I 3294.72 3195.72 4324.198 2032.47E 5955129.51 551950.64 0.00 4324.19 6900.00 89.88 172.00 I 3294.93 3195.93 4423.228 2046.38E 5955030.59 551965.21 0.00 4423.22 7000.00 89.88 172.00 ¡ 3295.14 3196.14 4522.248 2060.30E 5954931.66 551979.78 0.00 4522.24 7100.00 89.88 172.00 I 3295.35 3196.35 4621.278 2074.22E 5954832.74 551994.36 0.00 4621.27 7136.33 89.88 172.00 I 3295.43 3196.43 4657.248 2079.27E 5954796.80 551999.65 0.00 4657.25 SIC Kick off Point 7200.00 89.88 173.91 I 3295.57 3196.57 4720.438 2087.08E 5954733.68 552007.88 3.00 4720.43 7300.00 89.88 176.91 I 3295.78 3196.78 4820.108 2095.09E 5954634.07 552016.54 3.00 4820.10 7400.00 89.88 179.91 i 3295.99 3196.99 4920.058 2097.86E 5954534,15 552019,98 3.00 4920.05 7403.15 89.88 I 180.00 13296.00 3197.00 4923.208 2097.86E 5954531.00 552020.00 3.00 4923.20 WS 1E E2 D-MDPT#1 RVSD0621 04, 3DJ Kick off Point 7500.00 90.27 182.88 I 3295.87 3196.87 5020.018 2095.42E 5954434.19 552018.20 3.00 5020.01 7600.00 90.68 185.86 I 3295.03 3196.04 5119.708 2087.80E 5954334.46 552011.25 3.00 5119.70 7700.00 91.09 188.83 3293.49 3194.49 5218.868 2075.03E 5954235.23 551999.13 3.00 I 5218.86 7783.28 91.43 191.30 3291.66 3192.66 5300.835 2060.48E 5954153.17 551985.13 3.00 5300.83 End of BuildfTum 7800.00 91.43 191.30 3291.24 3192.24 5317.228 2057.20E 5954136.76 551981.96 0.00 5317.22 7900.00 91.43 191.30 3288.76 3189.76 5415.258 2037.61E 5954038.61 551963.02 0.00 5415.25 8000.00 91.43 191.30 3286.27 3187.27 5513.285 2018.01E 5953940.46 551944.08 0.00 5513.28 8100.00 91.43 191.30 3283.78 3184.78 5611.315 1998.42E 5953842.32 551925.13 0.00 5611.31 8200.00 91.43 191.30 3281.29 3182.29 5709.348 1978.82E 5953744.17 551906.19 0.00 5709.34 8300.00 91.43 191.30 3278.80 3179.80 5807.378 1959.22E 5953646.02 551887.25 0.00 5807.37 8400.00 91.43 191.30 3276.31 3177.31 5905.408 1939.63E 5953547.87 551868.31 0.00 5905.40 8500.00 91.43 191.30 3273.82 3174.83 6003.438 1920.03E 5953449.72 551849.37 0.00 6003.43 8600.00 91.43 191.30 3271.34 3172.34 6101.468 1900.44E 5953351.58 551830.42 0.00 6101.46 I 8700.00 91.43 191.30 3268.85 3169.85 6199.498 1880.84E 5953253.43 551811.48 0.00 6199.49 8800.00 91.43 191.30 3266.36 3167.36 6297.525 1861.25E 5953155.28 551792.54 0.00 6297.52 8900.00 91.43 191.30 3263.87 3164.87 6395.555 1841.65E 5953057.13 551773.60 0.00 I 6395.55 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.Oft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7154.92 Feet on azimuth 165.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . ...../ ConocOPhillips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Wellbore: 166L2 Well path: 166L2 Ver#3 Date Printed: 29-Jul-2004 r... 8AIŒR HUGHES INTEQ Wellpath Report MD[ft} Inc[deg} Azi[deg} TVD[ft} Vertical North[ft} East[ft} Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[f North\ East\ Oftl" tl 9000.00 91.43 191.30 3261.38 3162.38 6493.58S 1822.06E 5952958.98 551754.65 0.00 6493.58 9100.00 91.43 191.30 3258.90 3159.90 6591.61S 1802.46E 5952860.84 551735.71 0.00 6591.61 9200.00 91.43 191.30 3256.41 3157.41 6689.64S 1782.87E 5952762.69 551716.77 0.00 6689.64 9300.00 91.43 191.30 3253.92 3154.92 6787.678 1763.27E 5952664.54 551697.83 0.00 6787.67 9400.00 91.43 191,30 3251.43 3152.43 6885.70S11743.67E 5952566.39 551678.88 0.00 6885.70 9457.46 91.43 191.30 3250.00 3151.00 6942.02S I 1732.42E 5952510.00 551668.00 I 0.00 6942.02 TD All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7154.92 Feet on azimuth 165.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . ConocJ'Phjflips ConocoPhi/lips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska . PROPOSAL LISTING Page 4 Well bore: 166L2 Wellpath: 166L2 Ver#3 Date Printed: 29-Jul-2004 Comments MDlftl TVDrftl Eastfftl Northfftl Comment 400.00 400.00 O.OOE O.OON KOP 1583.33 1458.71 332.36E 278.885 EOC 4206.56 3045.82 1652.09E 1809.625 5tart 200' PUmD TanDent 4406.56 3136.17 1691.57E 1983.635 End 200' PumD TanDent 4823.18 3275.00 1757.77E 2369.645 TOD WhiDstock Face 4835.18 3277.91 1759.39E 2381.165 Base WhiDstock Face 4853.18 3281.99 1761.83E 2398.535 End Milled ODenhole KOP 9457.46 3250.00 1732.42E 6942.025 TD Hole Sections Diameter 5tart 5tart Start 5tart End End End EndlnEast[ft Wellbore I I fin! MDfft! TVDfftl Northlftl Eastfftl Morft! TVDfftl Northfftl 13 1/2 0.00 0.00 O.OON O.OOE 2890.59 2299.00 922.585 1099.49E 166 I 9718 2890.59 2299.00 922.585 1099.49E 6116.22 3516.00 3647.07S 1937.30E 166 I 63/4 4823.18 3275.00 2369.645 1757.77E 9457.46 3250.00 6942.025 1732.42E 166L2 Casings I Name ITop Top Top [TOP Shoe 5hoe Shoe 5hoe Wellbore i MDfftl TVDfftl Northfftl Eastffll MDfft! TVDfftl Northfftl Eastfftl I 10 3/4in Casino 0.00 0.00 O.OON I O.OOE 2890.59 2299.00 922.585 1099.49E 166 7 5/8in Casino 0.00 0.00 O.OON I O.OOE 6116.22 3516.00 3627.12S 1934.50E 166 4 1/2in Liner 4823.1 B 3275.00 2369.645 I 1757.77E 9457.46 3250.00 6942.025 1732.42E 166L2 I Taraets Name Northlftl Eastrftl I TVDIftI Latitude LonDitude Eastino Northino WS 1 E E2 4923.205 2097.86E I 3296.00 N70 17 11 .4463 W149 34 44.2951 552020.00 5954531.00 D-MDPT#1 I RV5D062104 1732.42~00 WS 1 E E2 D TOE 6942.025 N70 16 51.5923 W149 34 54.9554 551668.00 5952510.00 RV5D062104 I WS 1E E2 4923.875 2197.87E I 3330.00 N70 17 11.4395 W149 34 41.3815 552120.00 5954531.00 D-MDPT#2 I RVSD010704 Survey Tool Program ~ Reference Survev Name MDffl! TVDlftl Survev Tool Error Model 649104 Planned 9457.46 3250.00 ISCWSA MOO MOO+SAG - ISCW5A - 28 Jar 03 OJH 647695 Planned 4823.18 3275.00 ISCWSA MWD MOO+SAG - ISCW5A - 28 Jar 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical 5ection is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7154.92 Feet on azimuth 165.99 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated taker Hughes Incorporat! Anticollision Report GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 4823.18 to 9457.45 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: 1/12/2004 Validated: No Planned From To Survey ft ft 4.00 4823.18 Planned: 1E-166 Vers#3 V18 (0) 4823.18 9457.45 Planned: 1E-166L2 Vers#3 V13 Version: TooJcode Tool Name MWD+SAG+IFR MWD+SAG+IFR MWD+SAG+IFR (AK) MWD+SAG+IFR (AK) Summary Pad 1E 112 1E-112L1 V3 7500.00 9675.00 997.39 330.43 666.97 Pass: Major Risk Pad 1E 112 1E-112L2 V2 8028.22 10325.00 1052.61 336.93 715.68 Pass: Major Risk Pad 1 E 117 117 A2-Lateral VO Plan 9111.75 8250.00 450.46 407.28 43.18 Pass: Major Risk Pad 1E 117 117 B-Lateral VO Plan: 9111.75 8250.00 450.46 407.25 43.21 Pass: Major Risk Pad 1E 117 117 D-Lateral VO Plan: 9111.75 8250.00 450.46 407.25 43.21 Pass: Major Risk Pad 1E 119 119 VO Plan: 1E-119 Ve 7981.13 6975.00 1029.88 338.56 691.32 Pass: Major Risk Pad 1E 166 1E-166 V1 Plan: 1E-166 4825.00 4825.00 0.00 144.36 -144.36 FAIL: Major Risk Pad 1 E 166 1E-166l1 V1 Plan: 1E-1 4825.00 4825.00 0.00 144.36 -144.36 FAIL: Major Risk Pad 1E 170 170 A2-Lateral VO Plan 9455.06 7825.00 1022.19 413.00 609.20 Pass: Major Risk Pad 1E 170 170 B-Lateral VO Plan: 9455.06 7825.00 1022.19 412.98 609.21 Pass: Major Risk Pad 1 E 170 170 D-Lateral VO Plan: 9455.06 7825.00 1022.19 412.98 609.21 Pass: Major Risk Pad 1 E 2 1 E-02 VO 4825.00 5600.00 992.30 77.73 914.57 Pass: Major Risk Pad 1E 35 1 E-35 V1 6047.89 5750.00 388.88 217.45 171.43 Pass: Major Risk Pad 1E 35 35A VO Plan: 35A ST Ve 6069.83 5775.00 401.94 216.71 185.23 Pass: Major Risk . . _ii. BAKER HUGHES INTEQ Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E ConocoPhillips Alaska, Inc. lot: Well: Well bore: Slot #166 166 166L2 ConocJ'Phillips 10 340 20 330 30 320 40 310 50 300 60 290 70 280 80 270 90 260 100 250 110 240 120 130 220 140 150 160 190 180 170 Created by : lanner Date plotted: 29-Jul-2004 lot reference is 1661.2. Ref wellpath is 1661.2 Ver#3. Coordinates are in feet reference Slot #166. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum 111 Rig Datum to mean sea level: 99.00 It. Plot North is ali ned to TRUE North. Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well lE-166LJI)rilling HazardAummarï (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Low Miti ation Strate Stripping drills, shut-in drills, increased mud wei ht. Good hole cleaning, PWD tools, hole o ener runs decreased mud wei ht Reduced um rates mud rheolo , LCM Trip speeds, proper hole filling (use of trip sheets um in out, backreamin Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low· Lost Circulation Hole Swabbing on Trips Low Moderate Œ-166L2 Drilling Hazards Summary. doc prepared by Steve McKeever 8/10/2004 12:03 PM ~ ð 8 -o~ :;r' == :t>=: õf"'C ~~ ~ ~ ( ) III -n~ ( )¡n~ ¡w&, CD ( ) c "'nn ..a.::rs:!:. ~~g "'III:=!: f::(t) n= ... rp ... 8! m~ n ~~ """ ~~ ~~d Ì\\5' (Q .... ª[~: Insulated Conductor Casing, 20". 94#. K55 x 34",0.312" WT @ \ +/- 108' MD 10·3/4",45.5#, L-SO, Special Drift, STC (10542532) set@ +/. 2,S91' MD / 2,300' TVD ~ @ 50 degrees TD 13·1/2" hole Top of U~!1uC@l3,514' ---.. MDI2,693' TVD Top ofWestSakp @l 4;823'MD/3,27S' TVD---" Top of West Sak B @l 5,102' MD /3,340' TVD---" Top of West Sak A2 @ 6,116' MD /3,516' TVD---" Wellhead / Tubing Head / Tree, 13-5/ r B" x 4-W'. 5.000 ksi Tubing String; 4·1/2",12.6 #, L· SO, IST,AS Modlifed with Special Clearance Couplings (4.920" 00) (1) Gas Lift Mandrels, (1062-2035) CAMCO 4-1/2" x 1" Model KBG-2. one 3 joints above ESP. one at 2400' TVD. Electric Submersible Pump, Centrilift 41S HP motor, with FC6000 wireline deployed pump. Bottom at 4,406' MD, 3,136' TVD 1E·166 As Suilt: ASP NAD 27 Easllngs: 549.889.71 ASP NAD 27 Northings: 5.959,439.68 Pad Elevation: 70.4' AMSL Doyon Rig 141 Rig Floor (RF)@O' Elevation: 9S' AMSL f.. ,\66 ff..\.:33\ ~\a1\ ,,3 '\ ... O\feC:ton 166L2 D SaM Window@ +/. ~ 4,S23' MO / 3,275' TVO, 75 ¥ degrees '~~lJ ~::===?=:ª=:§====~==:-===:=:====::=~=====:~=~ Lateral Entry Module #1 (LEM), Saker, with seal bore and ZXP packer above. ------ ------------ ::::====::::===:::: - -- - o and S Sand Liners, 4·Y,", . , OWC/C, every joint slotted, (0. .. slots, 32 per foot, 5.9% open area) =§=;;;=§====;;;ªË§ª=;;=~~~§==§~=;§=ê=-:==:========;;===~=ª Tubing, 4·Y," ISTM, from LEM to A2 Liner, with seal stem and CAMCO 3.562" "OS" nipple. 7·5/S", 29.7#, L·80, STeM ~ (10527S3S) Casing set @ +/. 6,116' MO / 3,516' TVD. Set@ 81 degrees TO 9·7/S" hole ~ A2 Sand Liner, 4·Y,", 12.6#, LSO, R3, OWC/C, with slots over sand, blank over shales, and constrictors for isolation. (0.125" x 2.5" slots, 32 per foot, 5.9% open area) R3 Slotted =10783557, R2 Slotted =10790121 R3 Blank =10794247. R2 Blank =10790738 1E·166: 6·y.... A·Sand lateral TD @ 9,635' MD / 3,509' TVD . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIA IE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /{tú 1£--/6b [2 PTD# 2oC¡-IÇ~ X Development Service Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUE". APPLIES (OPTIONS) MULTI The permit is for a new welIbore segment of X LATERAL existing weD f:¡lú.l€"/h ~ Permit No,~o"'-IS3 API No. 50-0.2.'1 - .2.3, (Jf API num ber Production. sbotdd continue to be reported as last two (2) digits a function "of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), an (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated In both name (name on permit plus PH) ." and API Dumber (SO - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING Tbe permit is approved subject ·to full EXCEPTION compliance with 20 AAC 25.0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing ex ception. (Company Name) assumes tbe liability of any protest to tbe spacing ,exception tbat may occur. DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample intervals tbrough target zones. <.-c:> ~~ iii I/) 0) 0 Q) 0. I/) I/) ~ ã o æ .0 3 ~~ c: o ~ o > .c W CI) a 8 -. c: E 0 ~ 0) E a. ...I _ CD ,:: ~::> w ~ <C CI) ~ ::> > æ ~ ::> 0:: ~ ~ cu ~ Q) 'ð E Q) cu c:> z m...l ~q .... -. > w a . 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(I)' a (¡¡, >, 0, ]1' ~: õ a c:' 0' "0' Q), ë Q), I/) Q)' +-,' ~ 'Ë cu' G;: ãí: a., 0, 10 CD r-- ex¡ 0) C') t') t') t') C') » 0) o Õ CÞ c:> g Q) 0 ~~ co ... 0 D.a. ~o:: <C' <C Z z: I/) Q)' c:' 2, 1/)' m' 0) ~' .Q iii' .c' 1/), Ô' 1/)' ëii ~ m c:, co 0' 'g, .¡ CI), >: c, 0, b 0, ãí 0' ëi x, ~ 1/), t:, o a e' I/) 1/)' ~ Q)'O) 0: ~ .c 1/)' » ~, ~. o :C' ~: .E' Q) c:' 0' .c, 0. -.' ~: co C:' ~: ë o (.) ~, ....,. ~ ~' :]' 1/), c:' g, '5 e:' 8: "0, (I) .0' CU' Q), CI), Q) ¡;; a ~ IV) ~ (X) Q) ¡;; Q O)Qj c:C: .~.~ Q).!!1 .5 E g>E WO o ~ '-----.., ~ Q) -.... ¡;; a~ ~ Qj .~ g 0)'- £1g¡ 0'- t!J ~ IJ o~ e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding 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. **** REEL HEADER **** LDWG 05/05/04 AWS 01 **** TAPE HEADER **** LDWG 05/05/04 01 *** LIS COMMENT RECORD *** . . fI pll( !!!!!!!!!!!!!!!!!!! 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: MWD RUN 3 3 C. WONG 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 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE BIT SIZE (IN) 42.000 13.500 9.625 6.750 1E-166L2 500292322061 COnocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 04-May-05 MWD RUN 9 9 H. WOLTER M. THORTON 21 11N 10E 98.40 70.40 CASING SIZE (IN) 20.000 10.750 7.625 MWD RUN DRILLERS DEPTH (FT) 108.0 3012.0 4811.0 9417.0 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 óì.,OY -/5:) . . TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 17' 59.869" LONG: W149 DEG 35' 45.414" LOG MEASURED FROM D.F. AT 98.4 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) Baker Hughes INTEQ runs 1 & 2 utilized an 8" directional only tool to drill from 108 to 3020 feet MD (108 to 2398 feet TVD). 2) Baker Hughes INTEQ run 3 utilized a 6.75" directional tool with a Multiple Propagation Resistivity (MPR), Gamma Ray, along with Annular Pressure to drill from 3020 to 6020 feet MD (2398 to 3503 feet TVD). 3) Baker Hughes INTEQ run 8 utilized a 4.75" Gamma Ray tool to set a whip stock, mill a window, and drill from 4799 to 4830 feet MD (3281 to 3288 feet TVD). 4) Baker Hughes INTEQ run 9 utilized a 4.75" directional tool with a Multiple Propagation Resistivity (MPR), Gamma Ray, along with Annular Pressure to drill from 4830 to 9417 feet MD (3288 to 3258 feet TVD). REMARKS : 1) Depth of 10 3/4" Casing Shoe - Driller: 3012 feet MD (2392 feet TVD). Depth of 10 3/4" Casing Shoe - Logger: 3012 feet MD (2392 feet TVD). 2) Top of 7 5/8" Casing Window: 4799 feet MD (3281 feet TVD). Bottom of 7 5/8" Casing Window: 4811 feet MD (3284 feet TVD). 3) The interval from 9387 to 9417 feet (3258 to 3258 feet TVD) was not logged due to sensor offsets at TD. $ Tape Subfile: 1 79 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! !!!!!!!!! !!!! !!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3012.0 STOP DEPTH 9417.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # . . MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 3 9 MERGE TOP 3012.0 4811.0 MERGE BASE 4811. 0 9417.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT le-166L2 5.xtf 150 ConocoPhillips Alaska, Inc. lE-166L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROP 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F J 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 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 ------- 28 Total Data Records: 414 . . Tape File start Depth Tape File End Depth Tape File LeVel Spacing Tape File Depth Units 3012.000000 9417.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 456 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!! !!!!!!!! LDWG File Version 1.000 !!!!!! !!!!!!!! !!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 2 .2500 START DEPTH 2976.0 STOP DEPTH 4811. 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: 06-SEP-04 MSB 18704 6.75 MPR MEMORY 6020.0 2976.0 4811.0 o 48.6 78.9 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR PRES MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL PRESSURE MULT. PROP. GAMMA RAY RES. TOOL NUMBER DHA 6289 1006728 6010 10083974 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.625 3012.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): LSND 9.05 .0 . . 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: .0 200 .0 .000 .000 .000 .000 114.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 2 (MWÐ Run 3) . MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-166L2.xtf 150 conocoPhillips Alaska, I lE-166L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROP 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME . Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 237 Tape Tape Tape Tape File File File File "" feet 2976.000000 4811. 000000 0.250000 Start Depth End Depth Level Spacing Depth Units **** FILE TRAILER **** Tape Sub file: 3 322 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 . log header data for each bit run in separate files. 6 .2500 START DEPTH 4811.0 STOP DEPTH 9417.0 # 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: 21-SEP-04 MSB 18704 4.75 MPR MEMORY 9417.0 4811.0 9417.0 o 74.6 .. . MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM PRES $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY PRESSURE RES. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 92.7 TOOL NUMBER 18410 6032 4209 56318 6.750 4811.0 OBM 8.90 .0 .0 54000 .0 .000 .000 .000 .000 120.0 .0 .0 .0 .00 .000 .0 o BIT RUN 6 (MWD Run 9) . MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1e-166L2.xtf 150 ConocoPhillips Alaska, I 1E-166L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL RPCH RPSH GRAM RPCL RPSL RPCH RPSH 0.0 0.0 0.0 0.0 0.0 GRAM RPD RPM RPS RPX .. . . ROPA RPTH ROPA RPTH ROP RPTHM 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value~ 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value~ 0) Datum Specification Block Sub-type is: 1 FRAME SPACE '" 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 595 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 4811.000000 9417.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 680 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 05/05/04 01 **** REEL TRAILER **** LDWG 05/05/04 AWS 01 ... " Tape Subtile: 5 Minimum record length: Maximum record length: . . 2 records... 132 bytes 132 bytes
