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204-246
STATE OF ALASKA . AL.OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 1 Plug Perforations 1 Fracture Stimulate Pull Tubing r Operations Shutdown Performed: Suspend E Perforate r Other Stimulate r Alter Casing Change Approved Program E Plug for Redrill E Perforate New Pool E Repair Well ra Re-enter Susp Well Other:Crystal Seal MBE I 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E204-246 3.Address: 6.API Number: Stratigraphic E Service E P. O. Box 100360,Anchorage,Alaska 99510 50-029-23238-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651,25648 KRU 1E-121 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 12415 feet Plugs(measured) None true vertical 3742 feet Junk(measured) None Effective Depth measured 12386 feet Packer(measured) 4905,4676 true vertical 3740 feet (true vertical) 3625, 3565 Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20 108 108 0 0 SURFACE 2632 10.75 2662 2394 0 0 INTERMEDIATE 5241 7.625 5267 3694 0 0 B SAND LINER 7483 4.5 12388 3741 0 0 SCAN Er> ,, ; -e ,' ;,,t Perforation depth: Measured depth: 5272-5669,5886-6496,6745-12003, 12258-12350 True Vertical Depth: 3695-3716,3726-3742,3749-3731,3733-3738 Tubing(size,grade,MD,and ND) 3.5, L80,4713 MD, 3574 TVD RECEIVED Packers&SSSV(type,MD,and ND) PACKER-ZXP LINER TOP PACKER @ 4905 MD and 3625 ND FEB 1 7 2016 PACKER-ZXP LINER TOP PACKER @ 4676 MD and 3565 ND NIPPLE-CAMCO DS NIPPLE @ 516 MD and 516 ND 12.Stimulation or cement squeeze summary: AOGCC Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 107 - 179 - 180 Subsequent to operation 204 - 174 - 210 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service E Stratigraphic Copies of Logs and Surveys Run E 16.Well Status after work: Oil F Gas E' WDSPL ra Printed and Electronic Fracture Stimulation Data E GSTOR M' WINJ E WAG r' GINJ r SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-388 Contact John Peirce 265-6471 Email John.W.Peirceanconocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature1::_u ___ Phone:265-6471 Date 2 `I�_A ' l/ Form 10-404 Revised 5/2015 Z //yj C., Submit Original Only RBDMS L,t- FEB 1 8 2016 KUPD 1E-121 ConocaPhitlips '1. Well Attribut Max Angle TD a • Alaska..Il'I Wellbore API/UWI Field Name Wellbore Status 'ncl C) MD(ftKB) Act Btm(ftKB) C8000OPh)IIbps'''° 500292323800 WEST SAK PROD _ 93.31 11,629.07 12,415.0 ... .. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-121,2/12/20168:2140 AM SSSV:NIPPLE 80 8/24/2012 Last WO: 2/5/2009 33.61 2/6/2005 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _ Last Tag.CTMD 4,183.0 11/2/2008 Rev Reason:WELL REVIEW osborl 10/23/2013 Ib ! I r Casing Strings ' - ■' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread iyb•, CONDUCTOR 20 19.124 33.0 108.0 108.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread • •••• •••�•••�•• ••^• SURFACE 103/4 9.950 30.1 2,661.9 2,393.7 45.50 L-80 BTC HANGER;22.7 Vile. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread V � D SAND WINDOW 7 5/8 6.825 4,816.0 4,828.0 3,604.5 Lasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 26.5 5,267.0 3,694.1 29.70 L-80 BTCM �`„„„„„„,.., Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;33.0-1 oe.o i II B SAND LINER 41/2 3.958 4,905.0 12,388.0 3,740.6 12.60 L-80 DWC/IBT NIPPLE;516.3 Liner Details HEAT TRACE;32.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 4,905.0 3,625.8 73.60 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 4.970 SURFACE;30.1-2,681.9 l 4,924.0 3,631.1 74.19 NIPPLE 'RS'NIPPLE 4.875 4,926.9 3,631.8 74.28 HANGER FLEX-LOCK LINER HANGER 4.830 111 GAS LIFT;2,805.3IN 4,936.7 3,634.5 74.58 SBE 190-47 SEAL BORE EXTENSION 4.750 111 4,956.8 3,639.7 75.20 XO BUSHING CROSSOVER BUSHING 3.960 I 11 12,353.9 3,738.5 86.64 BUSHING DRILLABLE PACKOFF 3.960 • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread L1 LINER LEM 41/2 3.910 4,676.3 4,947.0 3,637.2 12.60 L80 IBTM GAS LIFT;4,505.7 Liner Details iliNominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Corn (in) NIPPLE,4,614.3 4,676.3 3,564.8 74.87 PACKER ZXP LINER TOP PACKER 4.970 111. 4,695.6 3,569.9 74.86 SBR 190-47 Casing Seal Bore Extension 4.750 GAUGE;4,625.6 4,760.1 3,586.7 74.86 NIPPLE CAMCO 3.75"'D8'Nipple 3.750 4,805.5 3,598.6 74.88 HANGER Upper LEM Assembly HOOK HANGER 3.910 li4,812.5 3,600.4 74.80 HANGER Lower LEM Assembly HOOK HANGER 3.990 .11 4,867.9' 3,615.3 73.90 NIPPLE BAKER 2.75"'D'Nipple 2.750 II4,943.7 3,636.3 74.80 SEAL ASSY 1192-47 SEAL ASSEMBLY 3.930 LOCATOR;4,684.6 Tubing Strings Tubing Description String Ma...ID(in) Top IRKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection SEAL ASSY;4,695.4 TUBING WO 31/2 2.992 22.7 4,713.5 3,574.5 9.30 L80 EUEBRD Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 22.7 22.7 0.10 HANGER VETCO GRAY TUBING HANGER w/PUP 4.500 55.6 55.6 0.25 XO 4.5x3.5 3.500 516.3 516.2 4.04 NIPPLE CAMCO'DS'NIPPLE 2.875 4,614.4 3,548.7 74.59 NIPPLE CAMCO'DS'NIPPLE 2.812 4,625.6 3,551.6 74.90 GAUGE Baker Guardian Gauge 2.992 4,673.6 3,564.1 74.87 XO- 3 1/2"EUE box X 4 1/2"IBTM pin Crossover 2.992 Enlarging .11 ri 4 'II 4,684.8 3,567.1 74.87 LOCATOR 4 1/2"IBTM Coupling w/Locator Ring 3.900 D SAND LINER;4,612.2- I I�. 4,695.4 3,569.8 74.86 SEAL ASSY GBH-22 Seal Assembly(2 ft space out) 3.870 12,303.016.0. 48120- 1 D SAND WINDOW;4,8 -1I IOther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) C) Des Corn Run Date ID(in) 32.0 32.0 0.14 HEAT HEAT TRACE 2/4/2009 0.000 TRACE Perforations&Slots Shot II. Top(ND) Btm(ND) (Rots / Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date k) Type Corn 5,272.0 5,669.0 3,695.0 3,716.5 WS B,1E-121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS LI L1 LINER LEM;4,676.3-4,947.0 :.) w/constrictor packers @ MP 5671',5886',6494', 6744',12023',12248' 5,886.0 6,496.0 3,726.4 3,741.7 WS B,1E-121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 1 6,745.0 12,003.0 3,749.1 3,731.4 WS B,1E-121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS INTERMEDIATE;26.5-5,267.0 12,258.0 12,350.0 3,733.2 3,738.2 WS B,1E-121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS IPERF;5,272.0-5,669.0 Mandrel Inserts S. St nl o N Top(ND) Valve Latch Port Size TRO Run IPERF;5,688.08,498.0 Top(ftKB) (ftKB) Make Model Go(In) Sery Type Type (in) (psi) Run Date Com 1 2,805.3 2,508.3 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/4/2009 - 2 4,505.7 3,514.8 CAMCO KBMG 1 GAS LIFT OV BK-5 0.313 0.0 2/12/2009 - Notes:General&Safety (PERF;6,745.0-12,003.0 ._ End Date Annotation 2/6/2005 NOTE:TREE-ABB VETCO GRAY/Horz/4-1/16""5M(w/PENETRATOR WIRE) 2/6/2005 NOTE:TREE CAP CONNECTION:9""OTIS ` 2/6/2005 NOTE:MULTI-LATERAL WELL-1E-121(B-SAND),1E-121L1(D-SAND) 11/2/2008 NOTE:WILL ATTEMPT TO FLOW AROUND STUCK ESP PUMP 11/6/2008 NOTE:WELL CONVERTED FROM ESP TO GAS LIFT !PERF;12,258.0-12,350.0 2/6/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0REV 5/18/2011 NOTE:RESTRICTION @ 4637"CTMD,COULD NOT DRIFT 2.80" B SAND LINER;4,905.0- 12,388.0 1,2 Crystal Seal Treatment 1 DATE SUMMARY 4/19/2015 Pumped 5 bbls meth down F/L, followed by 35 bbls diesel down Tbg. Job complete. 5/11/2015 BRUSH N FLUSH CMU @ 5905' RKB; DRIFT TO CMU WITH 3.84"DRIFT; SET 5/16"CHOKE ON 3.81"DB LOCK @ CMU 5905' RKB, JOB COMPLETE. 5/23/2015 PULLED 5/16" CHOKE AND SET 3.81" DB LOCK w/ 114"CHOKE©5905' RKB. COMPLETE. 7/19/2015 B&C CTU#1: RETREIVE DOWNHOLE CHOKE ON DB LOCK FROM SLIDING SLEEVE AT 5905'WITH BAKER G-FORCE JARS. PULL P PRONG FROM DB PLUG AT 6059'WITH JARS. IN PROGRESS. 7/20/2015 B&C CTU#1: RETREIVE DB PLUG FROM 3.56" DB NIPPLE AT 6059' WITH BAKER G-FORCE JARS. INSTALL NEW STYLE(2.75"ID)TYPE 1 ISO-SLEEVE ACROSS D LEM AT 6006'WITH BAKER SI-DI HIPP TRIPPER. PERFORM WEEKLY BOP TEST. READY FOR ELINE TRACTOR PERF. 8/6/2015 UNABLE TO TRACTOR PAST 8890'. DECISION MADE TO RDMO AND MOVE OVER TO 1E-105 TO BEGIN PERFORATION JOB. 8/8/2015 PUMP 40 BBL DIESEL DOWN TBG JOB COMPLETE 8/14/2015 B&C CTU#1: PERFORM DEPTH DETERMINATION LOG IN B LATERAL WITH PDS MEMORY UTILIZING A PUMP THROUGH TOOL CARRIER. DRY TAG AT 10679'CTMD(PERF DEPTH FROM 9460'-9470'). LOG PERF INTERVAL AND PAINT TIE IN FLAGS AT 9451'AND 9551'CTMD. IN PROGRESS. 8/19/2015 B&C CTU#1: PERFORM WEEKLY BOP TEST ON BACK DECK. PERFORATE MBE INTERVAL IN B LATERAL FROM 9465'-9470'RKB WITH SLB 2-IN POWERFLOW HSD GUNS (2006FP-6SPF, EHD 0.45",4.5" PEN). DEPTH CORRECTED TO TAG FROM LAST MEMORY LOG, REFERENCED TO IPROF DATED 23-JUN-06. WELL LEFT FREEZE PROTECTED AND SHUT IN. READY FOR CRYSTAL SEAL. 9/18/2015 PUMPED 219BBL SEAWATER DWN TBG FOLLOWED BY 42BBL DSL TO ESTABLISH INJECTION RATES (JOB COMPLETE) 9/19/2015 Pumped MBE treatment per design. Pumped 217 bbls 3% KCL w/1925#of 124 mesh Crystal Seal. Treatment displaced into suspected MBE w/ 100 SW and 40 bbls diesel. Note: Do not bring well back on injection or offset producer 1E-121 on prod until minimum tomorrow, 9/20, afternoon. 9/27/2015 Injectivity Test, pump 40 bbls dsl down tbg @1 bbl/min @ 900 psi,job complete iimmi ircoF T� , telyj�,sTHE STATE Alaska Oil and Gas '� of Conservation Commission - �� ALASKA. s __ t =_;f-= 333 West Seventh Avenue _ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 F4;r7\--a--.A., \-r,,'F` Main. 907.279 1433 ALAS Fax' 907.276 7542 www.aogcc alaska.gov SCANNED JUL 0 7 2015 John Peirce Sr. Wells Engineer12 ConocoPhillips Alaska, Inc. ' O P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-121 Sundry Number: 315-388 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, / /D)ra_L__474._L. Cathy P. roerster Chair y- DATED this,-- day of June, 2015 Encl. RE—kAri PVkID STATE OF ALASKA C /4.g . A ,KA OIL AND GAS CONSERVATION COM. 3ION JAN 'Lill 2l $ APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1.Type of Request Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Ferforate New Pool r Repair Well r Re-enter Susp Well r Other:Crystal Seal MBE . ft7 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 7 204-246 • 3.Address. Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23238-00, 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 r J KRU 1 E-121 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,25648 ' 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): 12415 • 3742 ' 12386' - 3740' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20 108' 108' SURFACE 2632 10.75 2662' 2394' INTERMEDIATE 5241 7.625 5267' 3694' B SAND LINER 7483 4.5 12388' 3741' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size' Tubing Grade: Tubing MD(ft). • 5272-5669,5886-6496,6745-12003,12258-12350 3695-3717,3726-3742,3749-3731,3733-3738 3.5 L80 4714 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER • MD=4676 TVD=3565 PACKER-ZXP LINER TOP PACKER ' MD=4905 TVD=3626 NIPPLE-CAMCO DS NIPPLE ' MD=516 TVD=516 12.Attachments: Description Surrmary of Proposal kr. 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/13/2015 OIL p WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r i 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 to-ti-,.tr.. .. Phone:265-6471 Date 6/j_c/jS Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 315. 3 v Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No / Subsequent Form Required: /0_4 0 y (A t n / APPROVEDMM BSY / G1 Approved b L `T/w,'V COMMISSIONER THE COMMISSION Date: h •-3v -�.� , .,- !o/zY / Approved application is valid for 12 months from the date of approval. submit Form and Form 10-403 Revised 5/2015 'PM (d2-2.) ORIGINAL Atta ents in Duplicate RBDMs JUN 3 0 2015 KUP PROD 1E-121 ' ConocoPhillips Well Attributesh. Max Angle&MD TD • Alaska,),,, Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) • Laraxw4vllipc 500292323800 WEST SAK PROD 93.31 11,629.07 12,415.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1E-121,10/23/20131103.52 AM SSSV:NIPPLE 80 8/24/2012 Last WO: 2/5/2009 33.61 2/6/2005 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - - - Last Tag:CTMD 4,183.0 11/2/2008 Rev Reason:WELL REVIEW osborl 10/23/2013 �� - CCastngasingDescripllS�nngs on OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(i...Grade Top Thread CONDUCTOR 20 19.124 33.0 108.0 108.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 30.1 2,661.9 2,393.7 45.50 L-80 BTC 'uaaruaaatleaa✓aistlHANGER;22.7 .910.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -" D SAND WINDOW 75/8 6.825 4,816.0 4,828.0 3,604.5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 26.5 5267.0 3,694.1 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread Mr CONDUCTOR;33.0-108.0M ..`MJF B SAND LINER 41/2 3.958 4,905.0 12,388.0 3,740.6 12.60 L-80 DWC/IBT NIPPLE;516. Liner Details 3 mem Nominal ID Top(ftKB) Top(TVD)(ftKB)_ Ind(° Top In ) Item Des Com (in) HEAT TRACE;32.0 4,905.0 3,625.8 73.60 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 4.970 4,924.0 3,631.1 74.19 NIPPLE 'RS'NIPPLE 4.875 4,926.9 3,631.8 74.28 HANGER FLEX-LOCK LINER HANGER 4.830 SURFACE,30.1-2,6619 ' 4,936.7 3,634.5 74.58 SBE 190-47 SEAL BORE EXTENSION 4.750 4,956.8 3,639.7 75.20 XO BUSHING CROSSOVER BUSHING 3.960 GAS LIFT;2,805.3 12,353.9 3,738.5 86.64 BUSHING DRILLABLE PACKOFF 3.960 Casing Description OD(in) ID(in) l Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(L..Grade Top Thread L1 LINER LEM 4 1/2 3.910 4,676.3 4,947.0 3,637.2 12.60 L80 IBTM Liner Details Nominal ID Top(ftKB) Top(ND)IRKS) Top Incl(°) Item Des Corn (in) GAS LIFT;4,505.7 4,676.3 3,564.8 74.87 PACKER ZXP LINER TOP PACKER 4.970 4,695.6 3,569.9 74.86 SBR 190-47 Casing Seal Bore Extension 4.750 NIPPLE;4,614.3 4,760.1 3,586.7 74.86 NIPPLE CAMCO 3.75"'DB'Nipple 3.750 . 4,805.5 3,598.6 74.88 HANGER Upper LEM Assembly HOOK HANGER 3.910 GAUGE;4.625.6 - 4,812.5 3,600.4 74.80 HANGER Lower LEM Assembly HOOK HANGER 3.990 ® 4,867.9 3,615.3 73.90 NIPPLE BAKER 2.75"'D'Nipple 2.750 a 4,943.7 3,636.3 74.80 SEAL ASSY 192-47 SEAL ASSEMBLY 3.930 Tubing Strings li Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(11a/ft) Grade Top Connection ' LOCATOR;46848 TUBING WO 31/2 2.992 22.7 4,713.5 3,574.5 9.30 L80 EUE8RD Completion Details SEAL ASSY;4,695.4 _- '�. Nominal ID I Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 22.7 22.7 0.10 HANGER VETCO GRAY TUBING HANGER w/PUP 4.500 55.6 55.6 0.25 XO 4.5x3.5 3.500 516.3 516.2 4.04 NIPPLE CAMCO'DS'NIPPLE 2.875 4,614.4 3,548.7 74.59 NIPPLE CAMCO'DS'NIPPLE 2.812 4,625.6 3,551.6 74.90 GAUGE Baker Guardian Gauge 2.992 4,673.6 3,564.1 74.87 XO-Enlarging 3 1/2"EUE box X 4 1/2"IBTM pin Crossover 2.992 4,684.8 3,567.1 74.87 LOCATOR 4 1/2"IBTM Coupling w/Locator Ring 3.900 I 4,695.4 3,569.8 74.86 SEAL ASSY GBH-22 Seal Assembly(2 9 space out) 3.870 D SAND LINER;4,8122- 123830 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) D SAND WINDOW;4,8160- Top(TVD) Top Incl 0.828'0 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 32.0 32.0 0.14 HEAT TRACE HEAT TRACE 2/4/2009 0.000 Perforations&Slots . Dens , _. TOP(ND) Btm(TVD) Shot (shotstt Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com !! I) 5,272.0 5,669.0 3,695.0 3,716.5 WS B,1E-121 1/26/2005 32.0 IPERF ALL Alternating 11 SLOTS/BLANKS w/constrictor packers @ 5671',5886',6494', L1 LINER LEM:4.676.34,947 0 • AS 6744',12023',12248' mom 5,886.0 6,496.0 3,726.4 3,741.7 WS B,1E-121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 6,745.0 12,003.0 3,749.1 3,731.4 WS B,1E-121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 12,258.0 12,350.0 3,733.2 3,738.2 WS B,1E-121 1/26/2005 32.0 IPERF ALL Alternating INTERMEDIATE;26.5.5,267.0 SLOTS/BLANKS Mandrel Inserts • IPERF;5,272.05.669.0 St all C on Top(TVD) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(IN Sere Type , Type , (in) (psi) Run Date m ' IPERF;5,8860.6,496.0 1 2,805.3 2,508.3 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/4/2009 2 4,505.7 3,514.8 CAMCO KBMG 1 GAS LIFT OV BK-5 0.313 0.0 2/12/2009 Notes:General&Safety • End Date Annotation IPERF;6,745,0-12,003.0 2/6/2005 NOTE:TREE-ABB VETCO GRAY/Horz/4-1/16""5M(w/PENETRATOR WIRE) 2/6/2005 NOTE:TREE CAP CONNECTION:9""OTIS 2/6/2005 NOTE:MULTI-LATERAL WELL-1E-121(B-SAND),1E-121L1(D-SAND) 11/2/2008 NOTE:WILL ATTEMPT TO FLOW AROUND STUCK ESP PUMP 11/6/2008 NOTE:WELL CONVERTED FROM ESP TO GAS LIFT IPERF;12,258.0-12,3500 2/6/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0REV 5/18/2011 NOTE:RESTRICTION @ 4637"CTMD,COULD NOT DRIFT 2.80" B SAND LINER;4,905.0- 12,388.0 1E-102 to 1E-121 B Sand MBE Fullbore Crystal Seal Treatment A Matrix Bypass Event (MBE) occurred 6-6-06 in 1E-102 B Lat to offset producer 1E-121. A 6-26-06 IPROF found an MBE at -9480' MD half way down 1E-102 lateral. Another MBE occurred in Dec. 2009 in 1E-102L1 D lateral to 1E-121L1 producer. A 9-3-11 Crystal Seal treatment successfully sealed the D MBE, and this MBE continues to behave sealed. A 9-23-12 Crystal Seal treatment was pumped to seal the B MBE, but this treatment broke down after -3 months. An 8/9/13 Crystal Seal retreatment was pumped to seal the B MBE, but the retreatment only held -1 month. Both B MBE treatments only resulted in small volumes of Crystal Seal entering this `tight' acting MBE feature. Of 9 West Sak MBE's treated to date with Crystal Seal, 1E-102 B MBE has been the most difficult to fill with Crystal Seal. Thus, It is proposed that a high rate fullbore Crystal Seal job be pumped to help open the MBE near wellbore to enable it to take larger volumes of Crystal Seal. The 2 CT jobs treating this B MBE resulted in only 1500 lbs & 1600 lbs of Crystal Seal away at 1.5 - 2 bpm prior to screen outs. These jobs are by far the smallest volume jobs pumped to an MBE. Successful jobs average -2400 lbs Crystal Seal prior to Flush. It is proposed that Crystal Seal slurry be fullbore pumped at -4 bpm (target) down tubing to the B MBE, per the proposed procedure: Coil Tubing: 1) RIH & pull 3.562" DB Plug at 6059' RKB (set 12/4/13 for B MBE isolation & `D only PWI' service). 2) RIH & set an Iso-Sleeve in the D LEM at 6006' RKB. E-line: 3) RIH with 5' perf gun on tractor to shoot 6 spf, 60 deg ph large hole add perfs at 9460 - 9465' RKB. This adds more perfs in 5.5" slotted liner near the B MBE at -9480' RKB. Fire gun. POOH. RD. Note, 5' of Perfs were shot 9/23/12 at 9470 - 9475' RKB. Adding more perfs may better help enable more 4 mm Crystal Seal particles to pass through the slotted liner(with 2.5"x 0.125"slots) Pumping: 4) Pump SRIT with Seawater down tubing to B MBE (Vol to MBE -144 bbls). Select steady treatment rate (target +/- 4 bpm) to be held constant during treatment through Flush to monitor MBE response to treatment and observe Crystal Seal screen out development during slurry pumping. Use 2% KCL for making Crystal Seal slurry (or Seawater) and pump slurry down 4.5" tubing as follows: a) 2% KCL Water w/0.10 ppg Crystal Seal, or go to Flush (step d) if screen out develops. b) 2% KCL Water w/0.15 ppg Crystal Seal, or go to Flush if screen out develops. c) 2% KCL Water w/0.20 - 0.25 ppg Crystal Seal, or go to Flush if screen out develops. d) When screen out occurs, pump Flush (targeting 107 bbls Seawater, followed by 37 bbls Diesel FP) to displace all Crystal Seal from well to B MBE. RD. Wait 6 hours before returning 1 E-102 to PWI. Coil Tubing: 5) RIH with jet swirl nozzle and tag top of Crystal Seal in well, then jet through Crystal Seal to deep as possible in the B Lat to shear/ mechanically break Crystal Seal remaining in the liner. POOH w/CT. 6) RIH with IPROF BHA to memory log down and up passes in the B Lateral. Wait 2 hours. Log cool back pass. POOH with CT. RD CTU. Return 1E-102 to PWI. Evaluate when to pull the D Iso-Sly. · . 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. ~ 0 l:/:- - ~ ~ it; Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: Î 'if (Count does ;nclude cove, sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date: L+/ 1d-107 If NO in stage 1, page(s) discrepancies were found: Organizing (done) o Two-sided 1111/111111111 111/1 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~iskettes, No~ o Other, NolType: o Poor Quality Originals: o Other: NOTES: BY: ~ Date: Lf, I:J- 07 Project Proofing BY: ~ Date: 4-, I d- 07 ~ x 30 = to 0 + Date 4/1:J- 0 7 Scanning Preparation BY: ~ (( IVI""I'" ) BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 111111111111111111/ OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: mP 151 11111111111111 ,,11/ 151 mP J ïJ = TOTAL PAGES '7 (count does not include cover stleet I!\A{) 151 r V Vr 11111111111111 ,,11/ YES NO 151 WI P NO 151 11111111111111 "III 1111111111111' ,,11/ 151 Quality Checked 1111/11111111/1111I 10/6/2005 Well History File Cover Page.doc • OF ri • • w`��� \ \I % %ys� THE STATE Alaska Oil and Gas F, „ III LAsKA Ccnisezvation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue * h: OF Q. Anchorage, Alaska 99501 -3572 ALASY' Main: 907.279.1433 SCANNED MAY 1 0 2013 Fax: 907.276.7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. _ + 1 — � P.O. Box 100360 `7' + Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E -121 Sundry Number: 313 -223 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. F. erster Chair DATED this /�T da of May, 2013. Encl. • STATE OF ALASKA C iP2 /OKA OIL AND GAS CONSERVATION COM ION 3 , •s i ° APPLICATION FOR SUNDRY APPROVALS '' ./6-(3 .1\41\Y 0 7 2013 20 AAC 25.280 � 1. Type of Request: Abandon E Rug for Redrill f Perforate New Pool I Repair w ell I Change Apb& I1V ((���., Q01 Suspend E Rug Perforations r Ferforate j"" Rill Tubing r Time Extension E Operational Shutdown r Re -enter Susp. Well E Stimulate la After casing E Other MBE Sealing td4 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development W. 6 Exploratory E 204 -246 • 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 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 Si 1 E - 121 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25651, 25648 • Kuparuk River Field / West Sak Oil Pool • I I I 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): 12415- 3742 12386' 3740' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20 108' 108' SURFACE 2632 10.75 2662' 2394' INTERMEDIATE 5240 7.625 5267' 3694' B SAND LINER 7483 4.5 12388' 3740' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5272 - 5669, 5886 - 6496, 6745 - 12003, 12258 - 12350 3695 -3717, 3727 -3742, 3748 -3734, 3733 -3738 3.5 L80 4714 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - ZXP LINER TOP PACKER MD =4676 TVD =3565 PACKER - ZXP LINER TOP PACKER MD= 4905 TVD =3620' NIPPLE - CAMCO DS NIPPLE MD =516 TVD =516 a ' 12. Attachments: Description Summary of Proposal I;i • 13. Well Class after proposed work: Detailed Operations Program F BOP Sketch r Exploratory I — Stratigraphic l -- Development Si Service 1 — 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2013 Oil F • Gas r WDSPL r Suspended I 16. Verbal Approval: Date: WINJ r GINJ I" WAG E Abandoned r Commission Representative: GSTOR r SPLUG j 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(Oconocoohillios.com Printed Name John Peirce Title: Wells Engineer Signature; Phone: 265-6471 Date c/6/13 Commission Use Only Sundry Number:' 2 J) 5 -2.23 Conditions of approval: Notify Commission so that a representative may witness v Plug Integrity F BOP Test r Mechanical Integrity Test C" Location Clearance E Other: Spacing Exception Required? Yes ❑ No Q Subsequent Form Required: iv - 1° APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: J ' /6 /3 oved application is valid for 12 months from the date of approval. Form 10 -403 (Revised 10/2012) 1/'Z- F Submit Form and Attachments in Duplicate ORIGINAL J---////.3 �3 1,0 0 • • 1E-102 to 1E-121 `B' MBE Crystal Seal Retreatment A Matrix Bypass Event (MBE) occurred on 6 -6 -06 in 1E-102 in the B sand lateral. A 6 -26 -06 (PROF saw the B MBE at 9480' RKB behind the 4.5" slotted liner. Almost all PWI was exiting the slotted liner at this MBE. A 9 -23 -12 Crystal Seal treatment sealed the B MBE, but the treatment broke down within 3 months that resulted in SI of PWI to 1E-102 on 12 -8 -12. A 3 -27 -13 IPROF in 1E -102 confirmed the B MBE at —9480' RKB Crystal Sealed 9 -23 -12 was once again open taking all PWI. The 1E-102L1 D MBE was isolated with an Iso -Slv on 9 -18 -12 (for the 9 -23 -12 B MBE Crystal Seal treatment), and the D Iso - Sleeve remains set, so 1 E -102 is currently configured to perform a B MBE retreatment with Crystal Seal. It is proposed that 1E-102 B MBE will be resealed with Crystal Seal pumped down coil tubing. No well work needs to be done to prepare for 1E-102 for a retreatment. Large hole perforations already exist in 1E-102 across the B MBE, which were shot prior to pumping the initial B MBE treatment. A post - Crystal Seal IPROF will likely be run in 1E-102 to verify success of the job. Coil Tubing Procedure: RIH with either a large down port or side port nozzle on 2 "coil tubing. Park nozzle across the large hole perforation interval at 9470 - 9475' RKB in the 4.5" slotted liner just above the MBE at 9480' RKB. Pump a Crystal Seal retreatment as follows: a) Seawater down coil. Determine a steady treatment rate (likely between 1.5 - 2 bpm) to be held constant during the treatment through Flush (step f) to monitor MBE response to treatment and to note a CrystalSeal screenout during slurry pumping. Swap from Seawater to 2% KCI, b) 2% KCI Water with 0.05 ppg Crystal Seal (we will use 4 mm mesh for all stages b through e) down coil. Each stage volume is TBD during pumping based on the treating pressure response seen during stage. When called, continue pumping, c) 2% KCI Water w /0.10 ppg Crystal Seal down CT, or go to Flush (step f) if we see screen out. d) 2% KCI Water w/0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCI Water w /0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. f) If screen out is seen, open CT x Tbg annulus to return tank, and pump 1 CT volume Seawater Flush to displace Crystal Seal slurry from coil to well while POOH. If screen out has not been seen prior to Flush, leave CT x Tbg annulus SI and pump 1 full CT volume of Seawater Flush to displace remaining Crystal Seal Slurry from coil to liner while POOH to D LEM, then swap to 53 bbls of Diesel FP down coil, followed by 1 CT volume of Diesel ( -40 bbls) to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait at least 6 hours to let Crystal Seal become fully swollen and seal off the MBE before returning 1E-102 to PWI for treatment evaluation. Coil tubing will be used to perform a post - CrystalSeal treatment tag, a possible Crystal Seal cleanout, and a memory IPROF depending on post job PWI and offset producer responses. 0 4 11 11 ' KUP • 1 E -121 ConocoPh llips s Well Attributes Max Angle & MD TD Alaska. k-C Wellbore API /UWI Field Name Well Status loci ( °) MD (ftKB) Act Btm (ftKB) C ,..,,,;11 Sla 500292323800 WESTSAK PROD 93.31 11,629.07 12,415.0 Comment H2S (pprn) Date Annotation End Date KB - Ord (ft) Rig Release Date Well Gonna: tE 121.tinf2012102757AM SSSV: NIPPLE I 30 9/15/2010 Last WO: 2/5 /2009 33.61 2/6/2005 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: CTMD 4,183.0 11/2/2008 Rev Reason: PULL PLUG ninam 11/7/2012 Casing Strings Casing Description String 0... String ID ... Top (MB) Set Depth (1... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR 20 19.124 33.0 108.0 108.0 62.50 H WELDED l' " .. r. . I Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 10 3/4 9.794 30.1 2,661.9 2,394.5 45.50 L BTC i_ &e. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 75/8 6.875 26.5 5,267.0 3,693.7 29.70 L - 80 BTCM HANGER, 23 " 1 ?„ Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd `. D SAND WINDOW 75/8 6.825 4,816.0 4,828.0 3,604.6 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd L1 LINER LEM 4 1/2 3.910 4,676.3 4,947.0 3,635.7 1260 L80 IBTM CONDUCTOR, I Liner Details 108 Top Depth (TVD) Top Intl Nomi... NIPPLE, 516 '1 ' Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 4,676.3 3,564.8 74.87 PACKER ZXP LINER TOP PACKER 4.970 HEAT TRACE, 32 l ,( 4,695.6 3,569.9 74.86 SBR 19047 Casing Seal Bore Extension 4.750 t 4,760.1 3,587.3 75.65 NIPPLE CAMCO 3.75 "'DB' Nipple 3.750 SURFACE, 1 l 4,805.5 3,598.6 74.91 HANGER Upper LEM Assembly HOOK HANGER 3.910 66 / 4,812.5 3,600.4 74.80 HANGER Lower LEM Assembly HOOK HANGER 3.990 4,867.9 3,615.5 73.90 NIPPLE BAKER 2.75" 'D' Nipple 2.750 GAS LIFT, 4,943.7 3,634.6 73.51 SEAL ASSY 192-47 SEAL ASSEMBLY 3.930 2,805 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd B SAND LINER 4 1/2 3.958 4,905.0 12,388.0 3,740.6 12.60 L -80 DWC /IBT Liner Details Top Depth GAS LIFT, (TVD) Top Inc! Ronk... 4.506 Top (R103) (RKB) P) Rem Description Comment ID (In) 4,905.0 3,620.4 71.33 PACKER ZXP LINER TOP PACKER w /HRD PROFILE 4.970 NIPPLE,4,614 4,924.0 3,627,7 72.40 NIPPLE 'RS' NIPPLE 4.875 4,926.9 3,628.8 72.56 HANGER FLEX-LOCK LINER HANGER 4.830 GAUGE. 4,626 { 4,936.7 3,632.2 73.12 SBE 190-47 SEAL BORE EXTENSION 4.750 - 4,956.8 3,638.8 74.25 XO BUSHING CROSSOVER BUSHING 3.960 ME 12,353.9 3,738.5 86.64 PACKOFF DRILLABLE PACKOFF 3.960 - Tubing Strings Tubing Description String 0... String ID ... Top (k KB) Set Depth (f... Set Depth (TVD)... String Wt... String... String Top Thrd LOCATOR, ki TUBING 31/2 2992 22.7 4,713.5 3,574.5 9.30 L80 EUE8RD 4,685 Completion Details SEAL ASSY, 1st Top Depth 4,695 (TVD) Top Inc! Nomi... I Top (ftKB) (ftKB) 11 Item Description Comment !D (in) 22.7 22.7 0.50 HANGER VETCO GRAY TUBING HANGER w /PUP 4.500 DSAND 55.6 55.6 0.50 X04.5x3.5 3 a816 - 516.3 516.1 4.04 NIPPLE CAMCO 'DS' NIPPLE ' 2.875 L1 LINER LEM, 4,6764,947 4,614.4 3,548.7 74.90 NIPPLE CAMCO 'DS' NIPPLE 2.812 NTERMEDIATE, 275,267 4,625.6 3,551.6 74.90 GAUGE Baker Guardian Gauge 2.992 IPERF, 5,2725.669 4,673.6 3,564.1 74.87 XO - Enlarging 3 1/2' EUE box X 4 1/2" IBTM pin Crossover 2.992 IPERF, 5,8865.496 4,684.8 3,567.1 74.87 LOCATOR 4 1/2' IBTM Coupling w/ Locator Ring 4.500 IPERF, 033 6.745 4,695.4 3,569.8 74.86 SEAL ASSY GBH - 22 Seal Assembly (2 ft space out) 3. 870 72,258 -12,350 DSAND ND 1 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) LINER, Top Depth 4,612- 12.383 (TVD) Top Inc! Top (MB) (RKB) ( °) Description Comment Run Date ID (in) 32 32.0 0.50 HEAT TRACE HEAT TRACE 2/4/2009 0.000 Perforations & Slots II & Shot ■ Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (RKB) Zone Date (60•.. Type Comment 5 ,272 5,669 3,694.8 3,716.5 WS B, 1E -121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS w /constrictor packers @ 5671', 5886', 1 1 6494', 6744', 12023', 12248' 5,886 6,496 3,726.7 3,741.7 WS B, 1E -121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 6,745 12,003 3,748.2 3,734.0 WS B, 1E -121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 12,258 12,350 3,733.2 3,738.2IWS B, 1E -121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS Notes: General & Safety End Date Annotation I 2/6/2005 NOTE: TREE CAP CONNECTION: 9' "' OTIS 2/6/2005 NOTE: MULTI - LATERAL WELL- 1E -121 (B- SAND), 1E -121L1 (D -SAND) 2/6/2005 NOTE: TREE - ABB VETCO GRAY / Horz / 4- 1/16 "" 5M (w/PENETRATOR WIRE) - - -- 11/2/2008 NOTE: WILL ATTEMPT TO FLOW AROUND STUCK ESP PUMP 11/6/2008 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT 2/6/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV 5/18/2011 NOTE: RESTRICTION @ 4637' CTMD, COULD NOT DRIFT 2.80" Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) MB) ( °1 Make Model (in) Sery Type Typo (!n) (psi) Run Date Com... 1 2,805.3 2,508.4 36.39 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 2/4/2009 B SAND LINER, 2 4,505.7 3,514.6 69.08 CAMCO KBMG 1 GAS LIFT OV BK-5 0.313 0.0 2/12/2009 TD (1E-121), D 288 T 12 72,415 6 STATE OF ALASKA AL,CA OIL AND GAS CONSERVATION COASION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon { Repair w ell ) — Rug Perforations r Perforate E Other ]"i.: MBE Sealing Alter Casing f Pull Tubing E Stimulate - Frac J Waiver f Time Extension (— Change Approved Program EOperat. Shutdow n (- Stimulate - Other 1 Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development (;-, Exploratory E r 204 -246 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service - 50 029 - 23238 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651, 25648 r 0- 1E-121 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): v none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12415 feet Plugs (measured) none true vertical 3742 feet Junk (measured) none Effective Depth measured 12386 feet Packer (measured) 4676, 4905 true vertical 3740 feet (true vertical) 3565, 3620 Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20 108 108 SURFACE 2632 10.75 2662 2394 B SAND LINER ER 7483 4.5 12388 3740 RECEIVED FEB 2 ± 1 . 2013 ► Perforation depth: Measured depth: 5272 -5669, 5886 - 6496, 6745 - 12003, 12258 - 12350 AQGCC True Vertical Depth: 3695 -3717, 3727 -3742, 3748 -3734, 3733 -3738 Tubing (size, grade, MD, and TVD) 3.5, L80, 4714 MD, 3575 TVD SCANNED APR Packers & SSSV (type, MD, and TVD) PACKER - ZXP LINER TOP PACKER @ 4676 MD and 3565 TVD PACKER - ZXP LINER TOP PACKER © 4905 MD and 3620 TVD SSSV - CAMCO DS NIPPLE © 516 MD and 516 TVD 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 Casing Pressure Tubing Pressure Prior to well operation 867 1167 306 -- 211 Subsequent to operation 173 1246 509 -- 210 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development . Service r Stratigraphic 1 16. Well Status after work: , Oil Gas E WDSPL E Daily Report of Well Operations XXX GSTOR f VVINJ E WAG r GINJ 1° SUSP [°°` 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: 311 -180 Contact John Peirce( 265 -6471 Email John .W.Peirce(conocophillips.com Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date 2 /20/i- cy4 7.::: L DMS FEB 2 21013 VU' Form 10 -404 Revised 10/2012 /ph 2/ 6 Submit Original Only V- KUP 0 1 E -121 ConocoPhillips 01 Well Attributes Max Angle & MD TD Alaska Inc Wellbore API /UWI Field Name Well Status Intl (°) MD (ftKB) Act Btm (ftKB) 500292323800 WEST SAK PROD 93.31 11,629.07 12,415.0 • '° Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "'" SSSV: NIPPLE 30 9/15/2010 Last WO: 2/5/2009 33.61 2/6/2005 Well Con Ap'. - 1 21, 11 /]/2012 10:27:57 AM sc Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: CTMD 4,183.0 11/2/2008 Rev Reason: PULL PLUG ninam 11/7/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 33.0 108.0 108.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.794 30.1 2,661.9 2,394.5 45 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 75/8 6.875 26.5 5,267.0 3,693.7 29.70 L - 80 BTCM HANGER, 23 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd D SAND WINDOW 75/8 6.825 4,816.0 4,828.0 3,604.6 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd L1 LINER LEM 4 1/2 3.910 4,676.3 4,947.0 3,635.7 12.60 L80 IBTM Liner Details CDNDUCTOR, __ Top Depth 33 -106 (TVD) Top Inc! Noml... NIPPLE, 516 MI Top (ftKB) (ftKB) (") Item Description Comment ID (In) 4,676.3 3,564.8 74.87 PACKER ZXP LINER TOP PACKER 4.970 HEAT TRACE, 32 i I 4,695.6 3,569.9 74.86 SBR 190-47 Casing Seal Bore Extension 4.750 4,760.1 3,587.3 75.65 NIPPLE CAMCO3.75 ''DB' Nipple 3.750 4,805.5 3,598.6 74.91 HANGER Upper LEM Assembly HOOK HANGER 3.910 ' SURFACE, 30 2.662 4,812.5 3,600.4 74.80 HANGER Lower LEM Assembly HOOK HANGER 3.990 4,867.9 3,615.5 73.90 NIPPLE BAKER 2.75" 'D' Nipple 2.750 GAS LIFT, 4,943.7 3,634.6 73.51 SEAL ASSY 192 -47 SEAL ASSEMBLY 3.930 2.805 MI in Casing Description String 4 1/2 I 0... Stri 58 ID ... Top (ftKB) 4 Set 12 (t Depth ... Set Depth 3 (ND) ... I String 12 1St L - 80 Wt... ring I - String DWC / lop IBT Thrd B SAND LINER Liner Details Top Depth ,388.0 I GAS LIFT, 1 (ND) Top Inc! Nomi... 4.506 Top (ftKB) (ftKB) (') Item Description Comment ID (in) - 4,905.0 3,620.4 71.33 PACKER ZXP LINER TOP PACKER w /HRD PROFILE 4.970 NIPPLE. 4.614 UM 4,924.0 3,627.7 72.40 NIPPLE 'RS' NIPPLE 4.875 4 ,926.9 3,628.8 72.56 HANGER FLEX -LOCK LINER HANGER 4.830 56 GAUGE, 4,626 ® 4,936.7 3,632.2 73.12 SBE 190-47 SEAL BORE EXTENSION 4.750 MI III 4,956.8 3,638.8 74.25 XO BUSHING CROSSOVER BUSHING 3.960 MI 12,353.9 3,738.5 86.64 PACKOFF DRILLABLE PACKOFF 3.960 AL Tubing Strings - Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LOCATOR, ! TUBING 31/2 I 2.992 I 22.7 I 4,713.5 3,574.5 I 9.30 L80 EUE8RD 4,685 ; Completion Details SEAL ASSY, "" ' Top Depth 4,695 - (TVD) Top Ind Nomi... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 22.7 22.7 0.50 HANGER VETCO GRAY TUBING HANGER w /PUP 4.500 0 SAND 55.6 55.6 0.50 XO 4.5x3.5 3.500 4,816 516.3 516.1 4.04 NIPPLE CAMCO'DS' NIPPLE 2.875 L1 LINER LEM, 4,676 4,614.4 3,548.7 74.90 NIPPLE CAMCO 'DS' NIPPLE 2.812 NTERMEDIATE, 27 - 5,267 4,625.6 3,551.6 74.90 GAUGE Baker Guardian Gauge 2.992 IPERF. 5.272 - 5,669 4,673.6 3,564.1 74.87 XO - Enlarging 3 1/2' EUE box X 4 1/2' IBTM pin Crossover 2.992 IPERF, 5,8868,496 4,6848 3,567.1 74.87 LOCATOR 4 1/2' IBTM Coupling w/ Locator Ring 4.500 IPERF, 6,745 - 12.003 ( 4,695.4 3.569.8 74.86 SEAL ASSY GBH - 22 Seal Assembly (2 ft space out) 3.870 IPERF, 12,258 - 12.350 D SAND � Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) LINER, Top Depth 4,812 12.38 (TVD) Top Inc! 1 - Top (ftKB) (ftKB) ( Description Comment Run Date ID (!n) 32 32.0 0.50 HEAT TRACE HEAT TRACE 2/4 /2009 0.000 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens ■ Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (aft- Type Comment 5,272 5,669 3,694.8 3,716.5 WS B, 1E -121 1/26/2005 32.0 IPERF ALL AlternatingSLOTSBLANKS w /constrictor packers @ 5671', 5886', 1 6494', 6744', 12023', 12248' I 5,886 6,496 3,726.7 3,741.7 WS B, 1E -121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS 6,745 12,003 3,748.2 3,734.0 WS B, 1E -121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS . , . 12,2581 12,3501 3,733.21 3,738.2 WS B, 1E -121 1/26/2005 32.0 IPERF ALL AlternatingSLOTSBLANKS Notes: General & Safety End Date Annotation 2/6/2005 NOTE: TREE CAP CONNECTION: 9' "' OTIS 2/6/2005 NOTE: MULTI - LATERAL WELL -1E -121 (B- SAND), 1E -121L1 (D -SAND) 2/6/2005 NOTE: TREE - ABB VETCO GRAY / Horz / 4- 1/16 "" 5M (w /PENETRATOR WIRE) 11/2/2008 NOTE: WILL ATTEMPT TO FLOW AROUND STUCK ESP PUMP 11/6/2008 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT 2/6/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV 5/18/2011 NOTE: RESTRICTION @ 4637' CTMD, COULD NOT DRIFT 2.80" Mandrel Details Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,805.3 2,508.4 36.39 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 2/4/2009 B SAND LINER, 2 4,505.7 3,514.6 69.08 CAMCO KBMG 1 GAS LIFT OV BK -5 0.313 0.0 2/12/2009 TD (1 ( D 16-141 268 T 12 12,415 5 DATE SUMMARY 1E-121 and 1E-121L1 Well Work Summa 10/17/2012 PERFORMED FLUFF AN TUFF USING SLICK DIESEL TO TOP 0 THAT WAS SET AT 4843' CTMD. FISHED IBW1 4843' CTMD. WELL FREEZE PROTEC D. JOB COMPLETE. THIS SUNDRY WAS TO SUPPORT THE MBE WORK ON 1E-102 AND 1E-102L1. THE FLUFF AND STUFF WAS THE ONLY WELL WORK PERFORMED. • • sEllnif[E 0 15- ARANEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E -121 Sundry Number: 311 -180 4 2.01 Dear Mr. Peirce: y Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. 174 Chair DATED this day of June, 2011. Encl. STATE OF ALASKA CA)9' ALASK,� AND GAS CONSERVATION COMMISSIO• I I C APPLICATION FOR SUNDRY APPROVALS W 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension " Operational Shutdown r Re -enter Susp. Well r Stimulate I"" Alter casing r g Ot her: MBE Sealing • p 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development R," . Exploratory E 204 -246 . 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23238 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes E No J 1E -121 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25651 25648' 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): 12415 ` 3742 . 12386' 3740' 4850' Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20 108' 108' SURFACE 2632 10.75 2662' 2394' INTERMEDIATE 5240 7.625 5267' 3694' B SAND LINER 7483 4.5 12388' 3740' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): i272' 5669', 5886 6496', 6746 12006, 12258' - 1235(3695' 3717', 3727' 3742', 3748' 3734', 3733' - 3738' 3.5 L80 4714 Packers and SSSV Type Packers and SSSV MD (ft) and TVD (ft) PACKER - ZXP LINER TOP PACKER MD= 4676 TVD= 3565 PACKER - ZXP LINER TOP PACKER w /HRD PROFILE MD =4905 TVD =3620 NIPPLE - CAMCO 'DS' NIPPLE MD= 516 TVD= 516 12. Attachments: Description Summary of Proposal J' 13. Well Class after proposed work: Detailed Operations Program l BOP Sketch r Exploratory Development I ' Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/1/2011 Oil i✓ - Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r" WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce © 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature ` f /mac l .� •� Phone: 265 -6471 Date j2 111 J am ,,... -- Commission Use Only Sundry Number:31 (---f ko Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test ) Location Clearance f' �.., ,4A`' � .t11. Other: Alaska Oil & G Cans. (*UMW o0 Subsequent Form Required: /0 — 4/Q `/ 4 i"t rage APPROVED BY ti// / Approved b COMMISSIONER THE COMMISSION Date: r rr hz J� Sal l/ Form 10 -4FIS+1 0 2 ° � ��� ORIGINAL. Submit in Dup ate ,7h' • • Sealing 1E-102L1 to 1E-121L1 MBE A matrix bypass event (MBE) occurred May 2010 in 1E-102L1 (D lateral) during Viscosity Reducing Injection (VRI) with breakthrough to 1E-121L1 producer. A diverter was set in the D LEM at 5994' RKB and a 5 -13 -10 IPROF in 1E-102L1 found an MBE at —8900' RKB. 1E-102 has been shut -in since May 2010 due to MBE's in both the B and D laterals. Halliburton CrystalSeal is intended for treating injector wells to restore water flood sweep efficiency by remediating direct communication paths through the formation to offset producers. CrystalSeal M is a water swellable dehydrated crosslinked synthetic gel polymer available in various granular mesh sizes. CrystalSeal swells to 400 times initial size in presence of water by hydrating and absorbing water. Due to swellability of CrystalSeal it is often used to fill highly conductive large voids or channels (MBE's) that readily accept very high rates of injection. Procedure: Slickline: 1) Pull DV's from GLM's at 3156' & 5453' MD; set memory T & P gauges in each of the GLM's. Coil Tubing: 2) RIH with perf gun & shoot 10' of big hole perforations in 4.5" slotted liner at 8900 - 8910' RKB to enable CrystalSeal entry past the slotted liner to the MBE. POOH with perf gun. 3) RIH w /Active -Coil until nozzle is across perf interval at 8900 - 8910' MD, then pump 40 bbls 2% KCI Pad down coil at initial rate of 0.7 bpm. Work rate to max rate allowable while taking any returns from the CT x Tbg annulus, followed by 5 bbls 2% KCI with 0.1 ppg CrystalSeal (4 mm size) at max rate allowable while taking returns from CT x Tbg, followed by 5 bbls 2% KCI with 0.25 ppg CrystalSeal (4 mm size) at max rate allowable while taking returns from CT x Tbg, followed by 20 bbls 2% KCI with 0.4 ppg CrystalSeal (4 mm size) at max allowable rate while taking returns from CT x Tbg, followed by 5 bbls 2% KCI with 0.4 ppg CrystalSeal (4 mm size) while ramping rate down to 0.7 bpm and taking returns from CT x Tbg, followed by shut -in of CT x Tubing annulus, followed by 60 bbls (target) 2% KCI with 0.4 ppg CrystalSeal (4 mm size) down coil at steady target rate of 0.7 bpm to stay below frac gradient while squeezing slurry to MBE and monitoring treating pressure at nozzle. Cycle nozzle up and down over perf interval to mitigate screen out, and to help remove any bridging buildups of CrystalSeal across perf interval. If screen out (pressure spike) is seen during pumping, stop mixing slurry and open CT x Tbg annulus to take returns to surface to halt the squeeze, followed by a swap to displacement to push remaining CrystalSeal in coil to liner. If pumping proceeds OK to target of 60 bbls, open CT x Tbq at completion of this stage and take returns, if any, to surface to halt the squeeze on the MBE, then swap to pumping displacement of 50 bbls 2% KCI down coil at 0.5 bpm to push all CrystalSeal from the coil to the liner while POOH with nozzle to D LEM at 6006' MD, followed by POOH with coil pumping 45 bbls of Diesel for FP, followed by 1 CT volume of Diesel to fully displace all 45 bbls of Diesel FP into the tubing. RD CTU. Wait at least 6 hours to let the CrystalSeal fully hydrate before returning 1E-102L1 to PWI to evaluate effectiveness of treatment in sealing the MBE. Return 1 E -102L1 to PWI slowly in step rate fashion (ie: 0.25 bpm, 0.4 bpm, 0.6 bpm) to observe post- treatment PWI rate vs. WHIP, and to evaluate if injectivity has changed as a result of treatment. . • KU P • 1 E -121 . tf ' Collips a Well Attributes . Max Angle & MD TD A)ask Inc ; 1 W Ilbore APL/UWI !Field Name Well Status Ilncl ( °) IMO (ftKB) Act Btm (ftKB) Gra n,XtnlNt� 500292323800 I I WEST SAK PROD 9331 11,62907 12,4150 • ' ' Comment -- H - 2S (ppm) Date Annotation End Date KB Grd (ft) Rig Release Date Well confg 1E 121 s1e2 5 ?NI SSSV NIPPLE 30 9/15/2010 Last WO: 2/5/2009 3361 2/6/2005 _ s,,, c ACtual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: CTMD 4,183M 11/2/2008 Rev Reason: SET PLUG ninam 5/18/2011 Casing Strings [Casing Description String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ,, CONDUCTOR 108.0 62.50 H-4 20 19.124 33.0 108.0 1080 WELDED ,a- e _.. _.. 4 ' Casing Description String 0... String ID -.- Top (ftKB) Set Depth (f. - Set Depth (ND) - -- String Wt... Siring String Top Thrd ". SURFACE 104 30.1 2 661.9 2,394.5 - BTC T s Casing Description String 3/ 0... 9.794 String ID ... Top (kK Set Depth (f. Set Depth (ND ... String 45.50 NM... String ... String Top hrd INTERMEDIATE _ 75/8 6.875 26 5 ,267.0 3, 693.7 29.70 L _ BTCM HANGER 23 . ' Casing Description String 0... String ID ... Top (fI B) Set Depth (f... Set Depth (ND) . String Wt... String ... String Top Thrd ) F. 3 D SAND WINDOW 7 5/8 6 4,816.0 4,828.0 3,604.6 ' Casing Description String 0. D .. String ID ... Top (ftKB) Set Depth (f.. Set Depth (TVD) . !String Wt... String . String Top Thrd 1 L1 LINER LEM 4 1/2 3 910 4,676.3 4,947 0 3,635.7 i 12.60 L80 IBTM CONDUCTOR, Liner Details 33 -108 Top Depth NIPPLE, 516 - (TVD) Top Intl N mi... Top (ftKB) (ftKB) ( °) Item Description Comment 10 (in) NEATTRACE, 4,676.3 3,564.8 74.87 PACKER ZXP LINER TOP PACKER 4.970 32 4,695.6 3,569.9 74.86 SBR 190-47 Casing Seal Bore Extension 4.750 4,760.1 3,587.3 75.65 NIPPLE CAMCO 3.75 "'DB' Nipple 3.750 SURFACE, _,� 4,805.5 3,598.6 74.91 HANGER Upper LEM Assembly HOOK HANGER 3.910 30 4,812.5 3,600.4 74.80 HANGER Lower LEM Assembly HOOK HANGER 3.990 I • 4,867.9 3,615.5 73.90 NIPPLE BAKER 2.75" 'D' Nipple 2.750 GAS LIFT, _____ -- - - - - _ - _ 2,805 - 4,943.7 3,634.6 73.51 SEAL ASSY 192 - 47 SEAL ASSEMBLY 3.930 Casing Description String 0.. String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) String Wt... !String ... String Top Thrd ,. B SAND LINER 4 1/2 3.958 I 4,905.0 I 12,388 0 I 3740.6 12.60 I L-80 I Thrd DWC /IBT at Liner Details 4 _ GAS LIFT, I Top Depth 6,506 ,.. (TVD) Top Inc!' Norm... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) Mt 4,905.0 3,620.4 71.33 PACKER ZXP LINER TOP PACKER W /HRD PROFILE 4.970 NIPPLE, 4,614 , , i trrp .P ,.• 4,924.0 3,627.7 72.40 NIPPLE 'RS' NIPPLE 4.875 GAUGE, 4,626 - - w'. 4,926.9 3,628.8 72.56 HANGER FLEX -LOCK LINER HANGER 4.830 : 4,936.7 3,632.2 73.12 SBE 190-47 SEAL BORE EXTENSION 4.750 - 4,956.8 3,638.8 74.25 X0 BUSHING CROSSOVER BUSHING 3.960 1 12,353 9 3,738.5 86.64 PACKOFF DRILLABLE PACKOFF 3.960 Tubing Strings LOCATOR, e ` Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... Str g _. String Top Thrd 4,685 TUBING 31/2 2.992 22.7 4,7135 I 3,574.5 9.30 L80 EUE8RD SEAL ASSY, 2 Completion Details 4,695 - Top Depth (ND) Top Intl Nomi... 0 SAND Top (kKB) (ftKB) (°) Item De Comment ID (in) WINDOW, 22.7 22.7 0.50 HANGER VETCO GRAY TUBING HANGERw /PUP 4.500 4,816 - 4,828 PLUG, 4,850 55.6 55.6 0.50 X0 4.5x3.5 3.500 11 LINER LEM, 4,6764,947 ;) . 516.3 516.1 4.04 NIPPLE CAMCO 'DS' NIPPLE 2.875 NTERMEDIATE, 27 - 5,267 4,614.4 3,548.7 74.90 NIPPLE CAMCO 'DS' NIPPLE 2.812 IPERF, 5,272 - 5,669 4,625.6 3,551.6 74.90 GAUGE Baker Guardian Gauge 2.992 IPERF. 5.886 - 6,496 4,673.6 3,564.1 74.87 XO - Enlarging 3 1/2" EUE box X 4 1/2" IBTM pin Crossover 2.992 IPERF, _ _ 6,745 12.003 4,684.8 3,567.1 74.87 LOCATOR 4 1/2" IBTM Coupling w/ Locator Ring 4.500 IPERF. 12,258 12.350 4,695.4 3,5698 74.86SEAL ASSY GBH - 22 Seal Assembly (2 ft space out) 3.870 D SAND i 4,812- 12,Z383 3 -' LINER, ether In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (kKB) (kKB) ( °) Description Comment Run Date ID On) 32 32 0 0. 50 HEAT TRACE HEAT TRACE 2/4/2009 0.000 4.850 3.610 7 14 19 'PLUG BRIDGE PLUG 1.375" FISH NECK OAL=11 ('9 5/15/2011 0 000 t Perforations & Slots _ � - Shot Top (TVD) Btm (ND) Dens Top (ftKB) Btm ( ftKB ) (ftKB) (ftKB) Zone Date (sh- Type Comment g 5,272 5,669 3,694.8 3,716.5 WS B, 1E -121 1/26/2005 32.0 IPERF ALL Attempting SLOTS/BLANKS 'i , f� w /constrictor packers @ 5671', 5886', I I 1 1 / 6494', 6744', 12023', 12248' IIi Ili 5,886 6,496 3,726.7 3,741.7 WS B, tE -121 1/26/2005 32.0 IPERF ALL Alternating SLOTS/BLANKS III 6,745 12,003 3,748.2 3,734.0 WS B, 1E-121 1/26/2005 32.0 IPERF ALL Alternating SLOTS /BLANKS III 12,258 12,350 3,733.2 3,738.2 WS 6, 1E -121 1/26/2005 1320IPERF ALL Alternating SLOTS/BLANKS 1I I 1 1 I Notes: General & Safety 1 ` l End Date Annotation I 2/612005 NOTE: TREE CAP CONNECTION: 9 OTIS __ 2/6/2005 NOTE: MULTI - LATERAL WELL - 1E -121 (B SAND), 1E -121L1 (DSAND) II 2/6/2005 NOTE: TREE - ABB VETCO GRAY / Harz / 4- 1/16 "" 5M (w/PENETRATOR WIRE) - -� 11/2/2008 NOTE: WILL ATTEMPT TO FLOW AROUND STUCK ESP PUMP 11/6/2008 NOTE: WELL CONVERTED FROM ESP TO GAS UFT III 2/6/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0REV 5/18/2011 NOTE: RESTRICTION @ 4637" CTMD, COULD NOT DRIFT 2.80" y , r" r ,*„( 1`:.: Y R.4,' ^!,��L _:.' Mandrel Details ,�° S. x z .- 1 , °. •Via.. ..t^`° Top Depth Top 9 Pori (TVD) Inc! OD Valve Latch Sae TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (in) Son Type Type (in) (psi) Run Date Com... 1 2,805.3 2,508.4 36.39 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/4/2009 B SAND LINER, 4,605 2 4,505.7 3,514.6 69.08 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 2/12/2009 TD (1E-1211 12,415 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ',EC EIVEC February 14, 2011 AdItiVELI FEB FEB 1 72 Commissioner Dan Seamount GI & Gas Cons. Convnission Alaska Oil & Gas Commission linchat' ae 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Lo "6 v 3--14 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped February 10 -12, 2011.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 2/15/2011 1B,1D,1E,1Q,1Y / 3F,3G,3J PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement t piopegj cement date inhibitor sealant date ft bbls ft gal 1B-01 50029204650000 1800400. SF ' N/A 19" N/A 1.4 2/11/2011 10-119 50029228360000 1972220 2" N/A 23" N/A 4.2 2/10/2011 1E -117 5002923251 0000 2050260 12" N/A 12" N/A 4.2 2/12/2011 e 1E-121 50029232380000 2042460.. , 6" N/A 18" N/A 4.4 2/12/2011 10-21 50029225910000 1951330 5" N/A 5" N/A 5.2 2/12/2011 1Q-22 50029225950000 1951400 5" N/A 5" N/A 3.2 2/12/2011 1Y -06A 50029209580100 1971340 6" N/A 6" N/A 5.2 2/12/2011 1Y-08 50029209440000 1830620 6" N/A 6" N/A 3.3 2/12/2011 3F -19A 50029226800100 2040160 8" N/A 8" N/A 3.4 2/11/2011 3G -16 50103201350000 1901040 16" N/A 18" N/A 3 2/11 /2011 3J -17 50029227000000 1961460 SF N/A 19" N/A 3.3 2/11/2011 i WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 - RE: Gas Lift Survey: 1E-121 Run Date: 8/7/2010 • August 9, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E-121 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23238-00 ~ ° ~',-;4 +t PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.w BUG ~ x.2010 Date: Signed: ~ , ~~ . to ~~~~~ v ~~v rage i or F Maunder, Thomas E (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, January 06, 2010 3:32 PM To: Pierson, Chris R Cc: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: FW: MBE event in West Sak VRWAG project (1 E-102 PTD 204-232) p~,~ -1' ~~ `~ ~ ~~ Chris, Just got in the 403 sundry to convert to water Injection for 1 E-102. This will effectively ban further Mi injection into 1 E-102 until the MBE event(s) has been diagnosed and fixed. As part of the sundry follow-up for the 10-404 please submit the diagnostics results as soon as they are finished. We are keenly interested in what the results may be concerning the nature and type of the MBE. Regards, P.S. could you please forward this to Mellisa Gangl , I don't have her email Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) Mi~~~~~'~c~~ ,~L;i_ F. ~ ~(`)Ft rom: Schwartz, Guy L (DOA) t: Monday, January 04, 2010 3:34 PM To: y, David S (DOA); Foerster, Catherine P (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Subject. E: MBE event in West Sak VRWAG project I hope it is the p leaking in 1 E-102 ... don't think it is likely though as it is a standard DB plug set in a nipple. They don't usually ~ st" start leaking and if they do it would have to be a huge leak in order to restart an MBE in the lower B lateral. ~f it truly is a D lateral MBE... (very rare .. think there is only one other I know ot) it doesn't bode well for VR G. Will be interesting to follow the diagnostics on this one........ Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Roby, David S (DOA) Sent: Monday, January 04, 2010 2:53 PM To: Roby, David S (DOA); Foerster, Catherine P (DOA); Maunder, Regg, James B (DOA) Subject: RE: MBE event in West Sak VRWAG project E (DOA); Schwartz, Guy L (DOA); I just heard more from CPAI on this event. The MBE occurred between the 1 E-1 injection well and the 1 E-121 producer on the 29th. They noticed pressure falling off on the injector and shortly the after the offset producer began producing at higher GOR. They did shut this well in as soon as the noticed a pro m and they also shut in the other well that was injecting gas, the 1 E-117, as part of this project despite the fact that re was no indication of any problems with it or its offset producer. Samples taken from the 1 E-121 well sh MI from the 1 E-102 well. 1 E-121 remains on production with a decreasing GOR. There has not been any ind~ tion of any sort of containment failure. 7/29/2010 • • Maunder, Thomas E (DOA) Yage 1 of l From: Schwartz, Guy L (DOA) Sent: Monday, January 04, 2010 3:34 PM To: Roby, David S (DOA); Foerster, Catherine P (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: RE: MBE event in West Sak VRWAG project I hope it is the plug leaking in 1 E-102 ... don't think it is likely though as it is a standard DB plug set in a nipple. They don't usually "just" start leaking and if they do it would have to be a huge leak in order to restart an MBE in the lower B lateral. So if it truly is a D lateral MBE... (very rare .. think there is only one other I know of) it doesn't bode well for VRWAG. Will be interesting to follow the diagnostics on this one........ Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) ___ From: Roby, David S (DOA) Sent: Monday, January 04, 2010 2:53 PM To: Roby, David S (DOA); Foerster, Catherine P (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) ~OV1-~~~ ~'a~-l(~, Subject: RE: MBE event in West Sak VRWAG project I just heard more from CPAI on this event. The MBE occurred between the 1 E-102 injection well and th 1 E-121 ~'~ producer on the 29~'. They noticed pressure falling off on the injector and shortly there after the offset producer began producing at higher GOR. They did shut this well in as soon as the noticed a problem and they also shut in !.~! the other well that was in'ectin as, the 1 E-117, as part of this project despite the fact that there was no 0 mica ion o any pro ems wit it or its o et producer. Samples taken from the 1 E-121 well show MI from the 1 E-102 well. 1 E-121 remains on production with a decreasing GOR. There has not been any indication of any sort of containment failure. The 1 E-102 and 1 E-117 both remain shut in. CPAI plans to return the 1 E-117 to gas injection service when they have completed gas analyses from its offset producer to ensure there has been no MI breakthrough in that well. The plan proposed plan forward for the 1E-102 is to convert it back to produced water injection service so that ad~-l ~~~ they can run logging tools to diagnose the problem. The well had a previous MBE in the lower lateral, the B-sand, which was isolated in October 2006 by installing a plug in the mother bore to shut off injection into this lateral. They need to determine whether this plug is leaking, which would be the easier fix, or if an MBE has occurred in the upper lateral, the D-sand. They wilt be sending in a 403 to convert the well to water injection and describe in more detail what diagnostic work they plan to do. They also said that they would not have expected a new MBE to occur so quickly, so they are leaning towards a leaking plug that allowed gas to flow through the existing MBE or an MBE was forming in the D-sand while the well was on water injection and would have still occurred even if the well was not converted to gas injection. Dave Roby (907)793-1232 From: Roby, David S (DOA) Sent: Monday, January 04, 2010 1:08 PM To: Foerster, Catherine P (DOA); Maunder, Thomas E (DOA); Schwarz, Guy L (DOA); Regg, James B (DOA) Subject: MBE event in West Sak VRWAG project 7/29/2010 rage ~ o~ ~ I just got a call from Scott Redman with CPAI about a MBE occurring in one of the wells they are injecting gas in as a part of the West Sak VRWAG pilot project. The well was on gas injection for approximately one month prior to the MBE event occurring and is a well that previously had a MBE event when on water injection. At this time they don't know if it is a new MBE channel or if the plug isolating the previous one has failed. They will most likely be switching this well back to water injection so that they can perform diagnostics and determine whether the MBE is a new one or the old one reopened and how to shut it off. I believe he said, but can't remember for certain, that the well was shut in when the MBE was detected. Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 7/29/2010 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 07, 2009 7:50 AM To: Dave Roby; Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: FW: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1 E-102 & 1J-170L1 Attachments: Picture (Metafile); Picture (Metafile) Dave, et al, Here is some information regarding a call I got yesterday on MBE events and isolations in these segments. Have the sundries to convert been approved? Tom From: NSK Prod Engr Specialist .[mailto:n1139Ca>conocophillips.com] Sent: Tuesday, October 06, 2009 5:28 PM To: Maunder, Thomas E (DOA) Cc: Hollar, Eric Andrew; Pierson, Chris R; NSK Well Integrity Proj; NSK Prod Engr & Optimization Supv Subject: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1E-102 & 1J-170L1 Tom, As the startup of the Wsak VRWAG Pilot Project approaches (estimated commencement date of 11/15/09), I have been asked to review the 10-403 Sundry applications submitted in February of this year. Below are the records pertaining to zone isolations due to Matrix Breakthrough Events (MBE) on wells 1 E-102 and 1J-170L1 that were not included in the 10-403 submittals. Well 1 E-102 MBE to offset Producer 1 E-121. e~- Date Well 1E-102 PTD# 204-231 10/25/2006 BRUSH DB NIPPLE @ 6060' RKB. SET 3.562 DBP PLUG @ 6060' RKB. SET P-PRONG INSIDE DB PLUG BODY @ 6060' RKB (13/8 FISH NECK-43" OAL ). (( B-SAND IS ISOLATED )). JOB COMPLETE. Well 1J-170L1 MBE to offset Producer 1J-166 3-~~-1;~ Date Well 1J-170L1 PTD# 206-063 8!10/2008 PULL B-SAND DIVERTER AND SET B-SAND ISOLATION SLEEVE AT 6818'. JARS RAN ON FIRST RUN, NOT NEEDED. HIPP TRIPPER RUN TO ENSURE ISOLATION SLEEVE SET. Please provide direction as to what is needed to move the process forward. Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. • Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Wednesday, March 25, 2009 9:06 AM To: Maunder, Thomas E (DOA) Subject: RE: 1 E-121 (204-246) Attachments: 1 E-121 Addendum to 10-404.pdf Tom, Page 1 of 1 Attached is the pre/post rig work summaries and a better schematic. I only included the pre-rig work relevant to the workover. At the end of the workover, they forgot to note that the BPV was set, they simply said "secure and dress tree", so I included the Well Service Report that followed the rig workover and you can see on the second line that the valve crew was on location and pulled the BPV prior to the Slickline work. Let me know if you need any more detail. Thanks, Drilling BC'WeOs 4Norkauer Engineer `GVork# (907) 265-6845 Ce[I# (907) 230.8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Saturday, March 21, 2009 3:05 PM To: Packer, Brett B Subject: 1E-121 (204-246) Bret, I am reviewing the 404 for the recent workover on this well and have some requests. 1. At the end of the well work, a TWC is set for ND BOP and NU and test tree. It is not indicated in the operations report that the TWC was pulled for freeze protecting and a a BPV installed for move off. Were those actions accomplished? 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-121? Thanks in advance. Email is fine. Tom Maunder, PE AOGCC 3/25/2009 • STATE OF ALASKA ~ ~~~~~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~R a ~ ~oo~ 1. Operatiohs Performed: Abandon ^ Repair Well ~ Plug Pertorations ^ Stimulate ^ Other AfiChOf Alter Casin g ^ Pull Tubing Q ~ Perforate New Pool ^ 'Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ~ - Exploratory ^ 204-246 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23238-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', 93' AMSL 1 E-121 8. Property Designation: 10. Field/Pool(s): ADL 25651, 25648 Kuparuk River Field /WestSak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 12415' feet true vertical 3742' , feet .Plugs (measured) Effective Depth measured 12386' feet Junk (measured) true vertical 3740' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 2634' 10-3/4" 2662' 2394' INTERMEDIATE 5239' 7-5/8" 5267' 3694' LINER 7483' 4.5" 12388' 3740' Perforation depth: Measured depth: 5272'-5669', 5886'-6496', 6745'-12003', 12258'-12350' true vertical depth: 3695'-3717', 3727'-3742', 3748'-3734', 3733'-3738' Tubing (size, grade, and measured depth) 3.5", L-80, 4713.5' MD. Packers & SSSV (type & measured depth) ZXP liner top pkr, ZXP liner top pkr @ 4s05', a676' Camco'DS' nipple @ 516' 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 932 ~ 480 407 -- 264 Subsequent to operation 525 993 137 -- 254 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 Br Packer ~C-7 Signature ~ ~Wp _~ Title Phone: 265-6845 Wells Engineer e, Date ~~S ~ / Pre a d b Sha n Allsu -Drake 263-9612 ~5.~ s'F /(r, -C' l ,~l ~/ate Form 10-404 Revised 04!2006 3 , e,s ~ (~~ ~ ~ ~.~ ~, '~ I~~~( ~, LdU~ Submit Original Only `Conductor, 20" X 30" Insulated, set at 80'. Tubing String ~ 3-112" 9.3#, L-80, 8rd EUE 2.992" ID, 2.867" Drift 516' MD - 2.875" DS Nippie 10-3/4" 45.5#\,` Casing Shoe, ~ set @ 2650' MD, 2395' ND / Heat Trace Cable to 3008' MD )5' MD -GLM, Cameo 3-112" X 1" KBMG 4506' MD -GLM, Cameo 3-112" X 1" KBMG 4614' MD - 2.812" DS Nipple 4626' MD -Guardian Gauge Carrier 4714' MD -Bottom of Seal Assembly 4.75" Seal / OD 4760' MD - 3.75" DB Nipple 4675' MD - 5-112" X 7-S18" ZXP Liner Top Packer wl Hold Downs 695' MD -Casing Sealbore Receptacle 4.75" ID Assembly .-~- 5-112" X 7SI8" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID 3.75" DB Nipple Orienting Profile ~-/ Automatic Alignment of LEM Positive Latching Collet ~~ Indicates Correct Location Seal Bore for Lateral Isolation - 3.68" ID Access Window I~ Positive Lateral Access Via \ Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID ~~ Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID RWO 09 BAKER HUGHES Baker Oil Tools Latera With D l Entry Module (LEM1 iverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbore Dritt) 'GS' ProRle for - Coll Connector iRUnninglRehleving ~ (1.00' Length) Snap In/Snap Out Positive Locating " r Back Pressure Valve Coll t (1.60' Length) e Lateral Isolation r Fbw-Thru Swivel Seals (1.25' Length) .Lateral Diverter - Hydraulic ~ ~ Ramp ' ' Disconnect Isolation/ Mainbore'"- (1.50' Length) Diverter Sleeve ___-GS Spear i -" (1.50' Length) Lateral Isolation 6.85 H Approx. Seals OAL' 'Jars may be required In highly deviated li 6 th l ' - ' cations ( appro: eng ). or tleep app ig,5 Diverter Length 18.5 Sleeve Length ~ 4805' MD -Lateral Entry Module (LEM) 'D' Sand Lateral Orienting Profile D-sand Window @ 4776' MD, 4-1/2" 1z.s#, L-8o, IBTM, ..' 3587 TVD Slotted Liner -112" X 7-5/8" t~s-~_-. >del'B' HOOK - Hanaer / 4867 MD - 2.75" D bing String: 4-1/2" 12.6#, L-80, iM SCC, (4.920" OD) 5-1 /2" X 7-518" ZXP Liner Top Packer "~; with Hold Downs ~`~~ 5-112" X 7S/8" ~ Flex Lock ~; ner Hanger I Packe~~ Liner Hanger Assembly at ~ casing Sealbore 4900' MD, 3619' TVD Receptacle 4.75" ID, 6.25" OD 20' Length 3-1/2" Bent Joint -- 3-1/2" Guide Shoe 3-1 /2" Casing Shoe, 12.6#, L-80 IBTM Pack-off Set @ 12419' MD, 3647' TVD Bushing 4947' MD -Bottom of Seal Assembly 4.75" Seal OD 'B' Sand Lateral 4-112" 12.6#, L-80, IBTM, Slotted Liner 4-1/2" Eccentric Guide Shoe Equipment Specifications 4-112" X 7-518" HOOK Hanger Mainbore Drift: 5.32" 4.63" Lateral Drift, no diverter or LEM: 1.68" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-112" 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: Diverter and Sleeve Length: ~~ 4-1 /2" Casing Shoe, 12.6#, L-80 IBTM Pack-off Bushing Set @ 12426' MD, 3709' TVD 7-518" Casing Shoe, Set at @ 5085' MD, 3661' TVD, 89 deg Baker Hughes 2003. This document may not be reproduced or dlsmbuhq In whole ar In part, In any form or by any means ekchonlc a mechanical, Inclutling photocopying, recording, or by any Inromutlon stooge and retrieval system now known or hereaner Invented, witl,out written permission hom Baker Hugh<s Inc. ]D06 West Sak TSIk" Dual LateralCompletlon -Producer ConocoPhillips West Sak 7-5/8" Producer 1 E-121 Dual Lateral Completion As Completed • `..~~ KUP ~ 1 E-121 ~ _ _ ~(MOCO~'11~~i 5 )Nell Attributes ~ Max Mgle & MD STD p ,1,..,^ __ ~ Wellbora API/UWI Field Name Well Status Prod/Inj Type ~'Incl (°) MD (ftK8) I ~ACt Btrn (ftK8) / 500292 32 38 00 WEST SAK 11,629 ,PROD 93.31 12415 Comment H25 (plxn) Date (Annotation '(End Date '.KB-Grd (ft) ',Rig Release Data -- -- -- - '~' - -SSSV~ NONE 20 ( 7/1/2008 Last WO: I 2/5/2009 33.61 2/6/2005 HANGER, tl CONDUCTOR, 0-106 NIPPLE. 516 HEAT TRACE, 3Z ~ SURFACE, 30-2,664 GAS uFr. z.eos GAS LIFT, 4,sos NIPPLE.4.614 GAUGE, 4,628- ~^~' SEAL ASSV, 4sss D SAND LINER. 1,812-12,383 Casing Description String 0... String ID ... Top (HKB) Sat Depth (i... Set Depth (ND) ... String Wt... String ... String Top Thrtl CONDUCTOR 20 19.124 0 108 1080 62.50 H-40 WELDED ',Casing Description String 0... String ID ... Top (ftK8) Set Depth (i... Set Depth (ND) ... String Wt... String ... String Top Thrtl SURFACE 10 3/4 9.794 30 2,662 2,394.6 45.50 L-80 BTC Casing Description String 0... String ID ... Top (ftK8) Sat Depth (f... Set Depth (ND) ... (String WL.. String ... Stn ng Top Thrd INTERMEDIATE 75/8 6.875 27 5,267 3,693.7 i 29.70 L-80 BTCM Casing Description String 0... String ID ... Top (ftK6) Sat Depth (f... Set Depth (ND) ... String Wt... String... String Top Thrd D SAND WINDOW 7 S/8 6.825 4,816 4,828 3,604.6 _ Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String... iSWng Top Thrd LEM L1 4 V2 3.910 4,676 4,947 3,635.7 12.60 L80 IBTM IGasing Description ~ String 0... (String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String... String Top Thrd I'IB SAND LINER '1 ' 41/2 i 3.958 4,905 12,388 3,740.6 1 12.60 L-80 DWC/IBT Liner Details TOP Depth', -_ (ND) .l op Inel Top (HKB) (HKeI (°) Item Description Commard ID (in) 4,9051 3,620.4 i 71.33 PACKER ZXP LINER TOP PACKER w/HRD PROFILE 4.970 4,9241 3,627.7 72.40INIPPLE 'RS'NIPPLE - - - ~----4.875 4,927 3,628 8 72.S6IHANGER FLEX-LOCK LINER HANGER 1 4.830 4,937 3,632.21 190-07 SEAL BORE EXTENSION 73.12~SBE 4.750 4,957 3,638.81 74.25(X0 BUSHING iCROSSOVER BUSHING 3.960 12,354 3,738.5( 86.64IPACKOFF 'DRILLABLE PACKOFF -_ 3960 Tubing _Strings Tubing Description 'String 0... String ID ... Top (ftK6) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 23 4,713 3,575 9.30 L-80 EUESrd Com letion Det ails _ Top Depfh (ND) Top Incl Top (HKB) _ -_ (HKB) (°) Item Description Comment ID (in) 23 22J 0.50 HANGER VETCO GRAY MB 222 TUBING HANGER 3.900 516 516.1 I 4.04 NIPPLE CAMCO'DS' NIPPLE 2.875 _. 4,614. 3,548.7 74.90 NIPPLE CAMCO'DS' NIPPLE w/RHC PLUG on 2.81"CR LOCK w/BALL & ROD 2.812 4,626 3,551.6 ~ 74.90 GAUGE BAKER GUARDIAN PM 925 GAUGE 2.992 4,695 3,569.8 Perforations 74.86 SEAL ASSY BKAER GBH-22 SEAL ASSEMBLY 3.870 snot Top (TVD) Btm (ND) Dens ~ftKB~ Btm (ftK8) i (ftK8) (HKB) ~ Zone _~ Date (sh-~ Type Commend 5,272 5,669'1 3,694.8 3,716.S~WS 8, 1E-121 1/26/2005 32.0 IPERF ALL AItemating SLOTS/BLANKS ~, ~~ w/constrictor packers @ 5671', 5886', 6494',6744', 12023', 12248' 5,886 -- 6496 3,726.7 3, 741.7'WS B, 1E-121 +1/26/2005 32.0 ~ IPERF ALL AItemating SLOTS/BLANKS 1 6,745 12,003' 3,748.2 3, 734.O~WS B, IE-121 1/26/2005 32.0 IPERF ALL AItemating SLOTS/BLANKS 12,258 12,350 3,733.2 3,738.21'WS 8, 1E-121 1126/2005 320 1PERF ! ALL AItemating SLOTSlBLANKS Notes: General 8 Safet ' End Date Annotation '2/6/2005 NOTE: TREE - ABB VETCO GRAY / Horz / 4-1116"" SM (w1PENETRATOR WIRE) '2!6/2005 NOTE: MULTI-LATERAL WELL- 1E-121 (B-SAND), 1E-121L7 (D-SAND) 2/6/2005 NOTE: TREE CAP CONNECTION: 9"" OTIS 11/2/2009 NOTE: WILL ATTEMPT TO FLOW AROUND STUCK ESP PUMP 11/612008 NOTE WELL CONVERTED FROM ESP TO GAS LIFT 2!6/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details __ - __ Top Depth Top Port (TVD) Incl 'I OD Valve Latch Size 'TRO Run Stn Top (HKB) (ftK6) (°) Make Model (in) Serv Type Type (in) (psi) Run Data Comm... __ _._ 1 2,805 2,508.4 36.39 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/4/2009 2 4,506 3,514.6 69.08 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/4/2009 ~ Well Date Event Descri lion 1E-121 8/26/08 TAG AND TART I FROM 3883' TO 3971' LM 200' ABOVE PUMP. JOB SUSPENDED FOR CLEAN OUT. 1 E-121 8/31/08 PULLED SLIP STOP & PACKOFF FROM 4197 CTMD AFTER CLEANOUT RUN, WILL RTN IN A.M. TO PULL ESP. 1E-121 9/1/08 PULLED ESP FROM 4206 CTMD, SET PUMP IN DEPLOYMENT FLANGE, READY FOR S/L. 1 E-121 9/5/08 P D 44.2' ESP PUMP FROM DEPLOYMENT FLANGE. SET CATCHER SUB @ 4247' RKB, PULLED SHEARED SOV @ 3594' RKB AND REPLACED W/ NEW 2000 PSI TBG. SHEAR VALVE. PULLED EMPTY CATCHER SUB @ 4247' RKB. NEED TO RUN NEW PUMP WHEN AVAILABLE. 1 E-121 9/14/08 (PRE-RWO) UPPER TPOT -PASSED. UPPER T PPPOT -PASSED. LOWER TPOT -PASSED. LOWER T PPPOT - PASSED. IC POT UNABLE TO TEST IC DUE TO LEAKING ALEMITE FITTING 1 E-121 9/22/08 SET 4-112" x 44' ESP @ 4236' WLM. SET 4-1/2" PACK OFF ASS'Y, TOP @ 4189' WLM (100" OAL, KOBE 35-1/2" FROM TOP, 89" TO CHECK . TESTED PACKOFF, GOOD. COMPLETE. 1 E-121 10/10/08 ATTEMPTED DRIFT TBG, ENCOUNTERED OBSTRUCTION AT /NEAR TBG HANGER @ 2' SLM. ATTEMPTED BAIL SAMPLE, NO RECOVERY. PUMPED 30 BBL HOT DSL, FAILED TO CLEAR. IN PROGRESS. 1 E-121 10/11/08 IDENTIFIED OBSTRUCTION @ 2' SLM: PACKOFF ASS'Y. PULLED SAME, MISSING ELEMENT. TAGGED 3.8" x 44' ESP 9' SLM. READY FOR CTU. 1 E-121 10/15/08 ABLE TO MOVE ESP PUMP DOWN HOLE 18' CTMD (27' FROM HANGER), HIT OBSTRUCTION AND WAS UNABLE TO GAIN ANY ADDITIONAL FOOTAGE UTILIZING HIPP TRIPPER AND PUMPING DOWN THE CTxTBG ANN. AT 4 BPM WITH HOT OIL TRUCK, PUMP MOVES FREELY UP HOLE, PUMPED OFF FISH ON BTM, TURN OVER TO SLICKLINE. Y K COIL PUMPED 226 BBLS DIESEL HOT OIL PUMPED 75 BBLS DIESEL ~ a w 1 E-121 10/20/08 ENGAGED 4-1/2" x 44' ESP (a) 29' WLM. UNABLE TO INITIATE MOVEMENT IN EITHER DIRECTION. PUMPED 45 BBL a HOT DSL DOWN TBG 8 RE-ENGAGED PUMP. UNABLE TO INITIATE MOVEMENT IN EITHER DIRECTION. JOB SUSPENDED. 1E-121 10/26/08 LOST TOOL STRING WHILE ATTEMPTING TO KNOCK ESP PUMP DOWN HOLE @ 27' SLM .RECOVERED COMPLETE TOOL ASSY @ 382' SLM. KNOCKED PUMP DOWN HOLE FROM 403' SLM TO 2652' (""'PUMP ACROSS TOP MANDREL @ 2675' RKB'"*~. UNABLE TO PUSH FURTHER DOWN HOLE. RAN 3" PUMP BAILER TO 2652' LM. F N N JOB SUSPENDED UNTIL A CRANE IS AVAILABLE. 1E-121 10/28/08 PULLED TOP SECTION OF PUMP (OAL= 57"/ BTM OD FLARED OUT TO 3.875" FROM 2662' SLM. *'*PUMP WAS PARTE H EADED SECTION ABOVE INTERNAL FINS"*". TAG TOP OF PUMP WITH 3.70" LIB @ 4156' SLM. OBTAINED CLEAR PICTURE OF .75" ROD LOOKING UP HOLE CENTER OF TBG .JOB SUSPENDED. 1E-121 11/2/08 ATTEMPTED TO PUSH ESP DOWN HOLE, TAG @ 4183' CTMD, RATTLED ON IT WITH HIP TRIPPER AND TRIED USING JARS, WAS UNSUCSEFULL IN MOVING. CONTACTED WEST SAK ENG, HE WAS OK WITH DEPTH. LEFT WELL SHUT IN AND FREEZE PROTECTED. 1 E-121 11/6/08 GAUGED TBG TO 2.79" TO 4160' SLM. SET SLIP STOP & CATCHER @ 4160' SLM. PULLED SOV @ 3594' & DV @ 2675' RKB. SET GLV 2675', OV 3594' RKB. PULLED CATCHER 4159' SLM. COMPLETE. 1E-121 1/23/09 SET CATCHER @ 4160' SLM, PULLED OV @ 3594' RKB &GLV @ 2675' RKB, REPLACED W/ DVs, PULLED CATCHER @ 4160' SLM, PULLED SLIP STOP @ 4164' SLM, RDMO. DHD SHOT FLUID LEVEL (-3000'), LRS PUMPED 95 BBLS DIESEL DOWN IA VERIFYING COMMUNICATION. 1E-12'1 1127/09 MIRU Nordac Rig 3, set down and bermed up. RU to Kill Tank.. Loaded pits w/ 8.8 pp9 6% KCL. PT kill lines @ 2 S00 si. Pull BPV. Bleed down well: KiIP well w KWF. ND Tree. 1E-121 1128/09 ND tree, NU BOP, open and inspect BOP's for debri from previous well, rack and tally 3 1J2" completion tbg, RU and test ROPE ull han er to floor circ hot kill fluid to clean tb LD han er. 1E-121 1129/09 POOH LD ESP completion string, clean floor and off load equipment, RU and make first cleanout run on 3 1/2" DP. 1E-121 1/30109 RIH making second cleanout run with lateral wash tool, POOH LD BHA, MU and RIH with outer string, MU ZXP assembly, MU inner string, RIH with ZXP and LEM assembly, shallow test MWD, RIH and orient LEM. 1E-121 2/1/09 RU slickline unit, RIH with caliper tool and could not pass through hook hanger, tools stackincj out at 4,830', w caliper up out of hook hanger and POOH RD slickline, RIH w/ cleanout BMA and passed through hookhanger, O POOH LD cleanout assembly, MU milling BHA, RIH and milled through hookhanger with 4:75" and 5.25" string Y milts POOH to 1 H36. ~ 1E-121 1131/09 Oriented LEM and attempted to latch hook hanger numerous times with no success, POOH LD innner and outer ~ LEM string assembly, sent seal assembly joint to Baker Machine and had 4" bend made, MU dummy run BHA c9 with seal assembly, RIH to 4,765', made numerous attempts to pass through hook hanger window but could no ~ M et ast 4830' bottom of window POOH for cali er run. ~ 1E-121 1/31/09 PERFORM CALIPER SURVEY FROM 4831' SLM TO 4600' SLM ***JOB COMPLETE*"* p 1E-121 2;2109 Cont POOH LD milting assembly, MU bullnose and lateral wash toots, RIH and cleanout hookhanger pumping p down drill string and IA simultaniously, POOH LD cleanout assembly, PU RIH with seal assembly dummy run, z POOH LD seal assembly and redressed,'MU inner and outer strings, RIH with LEM assembly to 3,770'. 1E-121 2/3/09 Cont RIH w/ LEM, orient and locate LEM, set LEM, test IA and ZXP, POOH LD HRD running tool, prep rig floor and PU sin le in hole with 3 1 2" com letion and heat trace to 3 056'. 1E-121 214!09 Cont RIH to 4,712' with 3 1/2" completion, space out, MU hanger and landing joint, spot inhibited seawater, land hanger, test tbg and IA, shear SOV, LD landing jnt and remove ISO sleeve, install 2 way check, ND BOP, NU tree. 1E-121 2/5/09 Freeze protect well, secure and dress tree, RDMO 5E-121. Nordic Rig #3 released from 1E-121 on 02-OS-2009 @ 07:30 am, 1E-121 2/12/09 PULL BALL & ROD @ 4614' RKB, PULL SOV @ 4506' RKB, SET 1" OV (5/16" PORT) @ 4506' RKB, PULLED RHC BODY @ ~ 4614' RKB, «RHC BODY STUCK @ 492' SLM» IN PROGRESS. ~ F 1E-121 2/13/09 PULLED RHC BODY FROM'DS' NIP @ 516' RKB. ((KEY RETAINER HOUSING HAS METAL EMBEDDED INTO THE OD)) N JOB COMPLETE. a ConocaPhil~ips Time Log & Summary ~yet,.~~, ~eb Re~°~,ng Report -_ - - - --- Well Name: 1 E-121 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1/27/2009 3:00:00 AM Rig Release: 2/5/2009 7:30:00 AM ', Time Logs Date From To Dur S. Depth E Depth Phase Code 5ubcode T Comment __ _ - - - --- 1/27/2009 24 hrSummarv MIRU Nordic Rig 3, set down and bermed up. RU to Kill Tank. Loaded pits w/ 8.8 ppg 6% KCL. PT kill lines 2,500 si. Pull BPV. Bleed down well. Kill well w/ KWF. ND Tree. 02:00 03:00 1.00 0 0 COMPZ MOVE OTHR P Shuffle mats to RU on from 1-170 to 1 E-121 03:00 05:30 2.50 0 0 COMPZ MOVE OTHR P Accept Nordic Rig 3 (a7 0300 hrs on 1-27-09 Spot and set T mats and 40' Double RU mats. Build ramp to assist in drivin ri u on double mats. 05:30 10:30 5.00 0 0 COMPZ MOVE PSIT P Spot rig over well, berm cellar, spot tanks and mudshack, MU hardline to kill tank. 10:30 11:30 1.00 0 0 COMPZ RPCOM OTHR P Pressure test hardline at 250/2,500 si - ood test. 11:30 12:00 0.50 0 0 COMPZ RPCOM RURD P RU lubricator to ull BPV. 12:00 14:30 2.50 0 0 COMPZ RPCOM OTHR T Pulled BPV master valve leaking, re-set BPV. Wait on valve crew to come to location and service master valve -service master valve. 14:30 15:00 0.50 0 0 COMPZ RPCOM RURD P Pull BPV, RD lubricator, 300 psi on OA, 480 si on IA, 670 si on tb . 15:00 16:30 1.50 0 0 COMPZ RPCOM OTHR P Load ESP spooler, spool and crate of uards with crane. 16:30 18:30 2.00 0 0 COMPZ RPCOM OTHR T Thaw ice plug in cellar. 18:30 20:30 2.00 0 0 COMPZ WELCTL CIRC P Bled gas cap off IA and tbg to kill tank, pumped down tbg with 8.Sppg kill fluid one tbg volume (65bbls) at 5 bpm - 80 psi, tbg pressure increased to 1,900 psi then dumped pressure back to 90 psi, possibly shoved ESP pump part down the tubing, lined up and pumped down IA at 5 bpm - 130 psi, 180 bbls 8.8ppg, never had fluid. returns at kill tank, shut down pump and blew down hardline. 20:30 21:00 0.50 0 0 COMPZ WELCTL OWFF P Shut in and monitored well for 30 min, tbg pressure increased from 0 to 90 si. 21:00 22:00 1.00 0 0 COMPZ WELCTL CIRC: P Pumped 65 bbls 8.8ppg kill fluid down tbg then 112 bbls down IA with no returns, shut in well. 22:00 22:30 0.50 0 0 COMPZ WELCTL OWFF P Monitored well for 30 minutes, well static. 22:30 23:00 0.50 0 0 COMPZ WELCTL OTHR P RD circ lines and installed BPV. _ ~~ ~ F~age '! ~f ~ r~ Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 COMPZ RPCOM NUND P ND tree, RU on well head to fill hole with 50 bbls eve hour. 1 /28/2009 ND tree, NU BOP, open and inspect BOP's for debri from previous well, rack and tally 3 1/2" completion tbg, RU and test BOPE, ull han er to floor, circ hot kill fluid to clean tb , LD han er. 00:00 01:30 1.50 0 0 COMPZ RPCOM NUND P Cont ND tree, inspect and hang off in cellar, inspect lift threads, install test dart, ins ect LD studs. 01:30 04:00 2.50 0 0 COMPZ RPCOM OTHR P Install 13 5/8" BOP stack, open all ram doors and inspect ram cavities for debri from previous well, rack and tall 3 1/2" tb 04:00 07:30 3.50 0 0 COMPZ RPCOM NUND P NU 13 5/8 BOP stack with lower variables. 07:30 08:00 0.50 0 0 COMPZ RPCOM OWFF P Bleed down IA with 120 psi. Pump 50 bbl down the IA. Monitor well. 08:00 11:00 3.00 0 0 COMPZ RPCOM SFEO P PT BOPE 250/2500 psi, with 3-1/2" and 4-1 /2" pipe. Test waived by AOGCC Rep Lou Grimaldi at 05:00 am 1-28-09 11:00 11:30 0.50 0 0 COMPZ RPCOM OWFF P Suspend BOP test, pump 50 bbl down the IA, monitor well. 11:30 14:00 2.50 0 0 COMPZ RPCOM SFEQ P Continue pressure testing BOPE. 14:00 14:30 0.50 0 0 COMPZ RPCOM OTHR P Pull test dart and BPV. 14:30 16:00 1.50 0 0 COMPZ RPCOM OTHR T Found a 2-3' section of Tech ire laying on top of hanger, attempted to retrieve from rig floor with no luck. Set BPV. 16:00 18:00 2.00 0 0 COMPZ RPCOM NUND T ND BOP stack and lifted enough to retrieve Tech Wire. 18:00 21:00 3.00 0 0 COMPZ RPCOM NUND T NU BOP stack, pull BPV and installed 2 wa check. 21:00 21:30 0.50 0 0 COMPZ RPCOM SFEQ T Test BOP breaks at 250/2,500 psi on chart, ood test. 21:30 22:00 0.50 0 0 COMPZ RPCOM RURD P Pull 2 way check and MU landing jnt, circ hose. 22:00 22:30 0.50 0 0 COMPZ RPCOM OTHR P BOLD's attem ted to unseat hanger' pulling to 180K, wrapped well head with steam blanket to heat up well head, pulled hanger loose at 130K, pulled hanger to rig floor, up weight 87K. 22:30 23:30 1.00 0 0 COMPZ RPCOM CIRC P Flush IA with 150 bbls of 160 degree hot 8.8 ppg brine at 5 bpm, 50 psi, with no returns u the tb . 23:30 00:00 0.50 0 4,248 COMPZ RPCOM PULD P LD hanger and landing jnt. 1 /29/2009 POOH LD ESP completion string, clean floor and off load equipment, RU and make first cleanout run on 3 1/2" DP. 00:00 00:30 0.50 4,309 4,309 COMPZ RPCOM RURD P String ESP cable through overhead sheave and MU on s ooler. 00:30 05:30 5.00 4,309 2,165 COMPZ RPCOM PULD P m~letion• filling hole with triple displacement +50 b h, from 4,248'. 05:30 06:00 0.50 2,165 2,165 COMPZ RPCOM OTHR T Repair ESP spooler. i~~c~~ 2 0( ~ • Time Logs __ ___ _ Date From To Dur S. De th E. De _th Phase Code Subcod_e_ T Comment 06:00 11:30 5.50 2,165 75 COMPZ RPCOM PULD P Continue POOH with 4 1/2" ESP com letion 11:30 14:00 2.50 75 0 COMPZ RPCOM PULD P Top of ESP pump located ~ 6' into joint #1. Break down and lay down ESP com letion. 14:00 18:00 4.00 0 0 COMPZ RPCOM OTHR P Clean floors. Set wear bushing. Off toad ESP boxes. Load 3-1/2" IBT, stra Re-order DP in derrick. 18:00 19:30 1.50 0 463 COMPZ RPCOM TRIP P MU cleanout BHA #1. 19:30 20:30 1.00 463 4,725 COMPZ RPCOM TRIP P RIH with 3 1/2" DP to 4,725', up wei ht 88K, down wei ht 74K. 20:30 21:30 1.00 4,725 4,954 COMPZ RPCOM CIRC P Obtain arameters and wash down from 4 725' to 4,954' um inq at 3 b m - 3,000 si, ettin no returns to W shed throu h D-lateral hook han er and throu h B-lateral ZXP liner to a total of 3 times. 21:30 00:00 2.50 4,954 0 COMPZ RPCOM TRIP P POOH from 4,954' and LD BHA. 1 /30/2009 RIH making second cleanout run with lateral wash tool, POOH LD BHA, MU and RIH with outer string, MU ZXP assembl , MU inner strip ,RIH with ZXP and LEM assembl ,shallow test MWD, RIH and orient LEM. 00:00 01:30 1.50 0 472 COMPZ RPCOM TRIP P MU cleanout BHA #2. 01:30 03:00 1.50 472 4,734 COMPZ RPCOM TRIP P RIH on 3 1/2" DP to 4,734', up weight 97K, down wei ht 74K. 03:00 04:00 1.00 4•,734 4,954 COMPZ RPCOM CIRC P Obtain pump parameters and wash down to 4 954' pumping at 6 bpm - 1,700 psi down drill pipe. Washed through D-lateral hook hanger and through B-lateral ZXP liner top a total of 3 times, lined up on kill line and um ed 50 bbls down IA at 6 b m to flush an debri down hole at hook han er and ZXP liner to . 04:00 08:00 4.00 4,954 0 COMPZ RPCOM TRIP P Blow down top drive and POOH, LD BHA #2. 08:00 10:00 2.00 0 0 COMPZ RPCOM OTHR P Clean rig floor. Load and arrange tools for LEM run. 10:00 12:30 2.50 0 0 COMPZ RPCOM RURD P Crane on location, remove used ESP cables ool from ri floor. 12:30 14:00 1.50 0 0 COMPZ RPCOM WOEQ T Needed to have plug removed from ni le to allow um in for MWD. 14:00 18:00 4.00 0 282 COMPZ RPCOM PULD P PU and MU LEM BHA with inner strip . 18:00 23:00 5.00 2.82 4,725 COMPZ RPCOM TRIP P RIH one stand and shallow test MWD, good test, cont RIH on 3 1/2" DP to 4,725' at 30 fpm, up weight 98K, down wei ht 78K. 23:00 00:00 1.00 4,725 4,819 COMPZ RPCOM CIRC P Break circ at 3 bpm - 420 psi to orient LEM with MWD, slowly washed down to 4,819'. 1 /31 /2009 Oriented LEM and attempted to latch hook hanger numerous times with no success, POOH LD innner and outer LEM string assembly, sent seal assembly joint to Baker Machine and had 4" bend made, MU dummy run BHA with seal assembly, RIH to 4,765', made numerous attempts to pass through hook hanger window but could not et ast 4,830' bottom of window ,POOH for call er run. P~~ 3 of ~ n • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment _ 00:00 01:30 1.50 4,819 4,830 COMPZ RPCOM OTHR P __ _ Oriented LEM and attem ted to ass . throu h hook hanger numerous times with no success. 4 3/4" seal assembly not going through hook hanger window. Contacted Well Engineer and decision made to POOH - LD LEM assembl . 01:30 03:00 1.50 4,816 4,816 COMPZ RIGMNT SVRG P Blew down top drive, POOH one stand and hung off blocks, slipped and cut drill line. 03:00 08:00 5.00 4,816 282 COMPZ RPCOM TRIP T PO H with tom lete LEM assembl standing back 3 1!2" DP, LD inner and outer LEM assembl . 08:00 10:00 2.00 282 0 COMPZ RPCOM PULD T RD and LD LEM and MWD BHA e ui ment 10:00 15:30 5.50 0 0 COMPZ RPCOM WOEQ T Sent seal assembly to Baker to have seal assembly joint bent to aid in uidin seal assembl throu h to the 'n well bore. 15:30 17:30 2.00 0 0 COMPZ RPCOM RURD T Seal assembly back on location. Load and MU seal assembly dummy run. 17:30 20:30 3.00 0 4,765 COMPZ RPCOM TRIP T MU bent'oint Seal Assembly BHA and RIH on 3 1/2" DP to 4,765', up wei ht 95K, down wei ht 75K. 20:30 22:30 2.00 4,809 4,830 COMPZ RPCOM OTHR T Attempt to pass throu h hook han er numerous times, tagged top of hook han er at 4 809' PU and rotated 180 and worked down to 4,822'. Pulled out of hook hanger top, rotated string and slacked off past 4,822' but tackin out at 4 830' bottom of hook h n r numerous times. Called Well Engineer and decision made to POOH for caliper run. 22:30 00:00 1.50 4,830 2,825 COMPZ RPCOM TRIP T Blow down top drive and POOH stand back 3 1/2" DP from 4,830' to 2, 825'. 2/01 /2009 RU slickline unit, RIH with caliper tool and could not pass through hook hanger, tools stacking out at 4,830', caliper up out of hook hanger and POOH RD slickline, RIH w/ cleanout BHA and passed through hookhanger, POOH LD cleanout assembly, MU milling BHA, RIH and milled through hookhanger with 4.75" and 5.25" strip mills, POOH to 1,836. 00:00 02:30 2.50 2,825 4,830 COMPZ RPCOM TRIP T Cont POOH stand back 3 1/2" DP, LD seal assembly BHA. Mule shoe had extensive ou es. 02:30 07:00 4.50 4,830 0 COMPZ RPCOM SLKL T PJSM, RU to run 2 3/4" 26 finger memo tali er on slickline RIH to 4,830'. Unable to run dee er. . POOH with slickline and PDS caliper log. RD slickline. Cali er to showed the tool t in to run into a 07:00 08:30 1.50 0 185 COMPZ RPCOM RURD T PU and MU 4.5" nozzle run to confirm that hanger has not moved since revious clean out runs. Time Logs Date___ From To r Phase Code Subcode T Comment D u S, De th E. De t h 08:30 _ 10:00 _ _ _ 1.50 185 _ __ 4,750 COMPZ RPCOM TRIP T ____ __ RIH with 4.5" wash nozzle. 10:00 11:00 1.00 4,750 4,953 COMPZ RPCOM TRIP T BHA at 4,750'. Up wt = 97 K#, down wt = 73 K#. RIH to 4,953', no idications of taking weight. PUH to 4,813', RIH to 4,836', did not to e an wei ht. 11:00 14:30 3.50 4,953 185 COMPZ RPCOM TRIP T POOH standing back 3-1/2" DP. 14:30 15:30 1.00 185 0 COMPZ RPCOM RURD T LD wash string BHA, clean rig floor while waitin on delive of mills 15:30 19:00 3.50 0 386 COMPZ RPCOM RURD T Load millin tools build tally, PU and MU millin BHA. 19:00 21:00 2.00 386 4,858 COMPZ RPCOM TRIP T RIH on 3 1/2" DP to 4,858' and tag up, up weight 90K, down weight 75K, rot weight 85K, off bottom torque 2,500 ft/Ibs. 21:00 22:30 1.50 4,858 4,885 COMPZ FISH MILL T Mill throu h hook han er window with 4.75" and 5.25" string mills at 40 rpm, torque at 3,000 to 4,000 ft/Ibs max, pumping down IA with kill line at 3 bpm, to 4,885', did not enter ZXP, stopped rotation and worked throu h hook han er twice with no roblems. 22:30 00:00 1.50 4,885 1,836 COMPZ RPCOM TRIP T POOH from 4,858' to 1,836'. 2/02/2009 Cont POOH LD milling assembly, MU bullnose and lateral wash tools, RIH and cleanout hookhanger pumping down drill string and IA simultaniously, POOH LD cleanout assembly, PU RIH with seal assembly dummy run, POOH LD seal assembl and redressed, MU inner and outer strip s, RIH with LEM assembl to 3,770'. 00:00 02:00 2.00 1,836 0 COMPZ RPCOM TRIP T Cont POOH LD milling assembly. 02:00 03:30 1.50 0 472 COMPZ RPCOM PULD T MU lateral wash tool cleanout BHA. 03:30 05:00 1.50 472 4,734 COMPZ RPCOM TRIP T RIH on 3 1/2" DP to 4,734', up weight 97K, down wei ht 74K. 05:00 05:30 0.50 4,734 4,954 COMPZ RPCOM CIRC T Obtain parameters and washed down to 4 954'. Isolated rig pumps and pumped at 6 bpm down drill pipe at 1700 psi and 6 bpm down IA simultaniously. Washed through D-lateral hook han er and throu h B-lateral ZXP liner to a total of 3 times with no roblems. 05:30 08:00 2.50 4,954 470 COMPZ RPCOM TRIP T Blew down top drive and POOH with cleanout assembl . 08:00 09:30 1.50 470 0 COMPZ RPCOM PULD T DP on surface. Rig down lateral wash tool cleanout BHA. 09:30 11:00 1.50 0 470 COMPZ RPCOM PULD T MU seal assembly dumm run BHA 11:00 13:00 2.00 470 4,956 COMPZ RPCOM TRIP T RIH with seal assembly to 4,800', up wt = 97K, down wt = 73K. Pass through the hook hanger and _, land seal assembly into the bottom of the SBE with 10K at 4,956'. 13:00 16:00 3.00 4,956 0 COMPZ RPCOM TRIP T POOH stand back 3-1/2" DP, LD seal assembl . P~c~ 5 c~C~ €~ Time Logs _ Date From To Dur S. De th E. De th Phase Code Sub_code T Comment 16:00 17:30 1.50 0 0 COMPZ RPCOM RURD T Redress seal assembly, off-load Baker tools, RU floor to MU LEM assembl . 17:30 19:30 2.00 0 282 COMPZ RPCOM PULD T PU and MU LEM BHA with inner strip . 19:30 00:00 4.50 375 3,770 COMPZ RPCOM TRIP T RIH one stand and shallow test MWD, good#est, cont RIH on 3 1/2" DP to 3,770' at 30 fpm, up weight 85K, down wei ht 70K. 2/03/2009 Copt RIH w/ LEM, orient and locate LEM, set LEM, test IA and ZXP, POOH LD HRD running tool, prep rig floor and PU sin le in hole with 3 1/2" com letion and heat trace to 3,056'. 00:00 01:30 1.50 3,770 4,737 COMPZ RPCOM TRIP T Cont RIH with LEM assembly on 3 1/2" DP from 3,770' to 4,737', warm u to drive and wash i e. 01:30 04:30 3.00 4,737 4,946 COMPZ RPCOM HOSO P Break circ at 3 bpm - 420 psi to orient LEM with MWD, slowly washed down to 4 946' mule shoe de th, with LEM at 6 de rees left and assed throw h hook hap er with no roblem. Latched in and orientation went to 47 de rees ri ht. Re-oriented numerous times working for ue out of strip ,landed and latched LEM at 3 de rees left of hi hside. Seal assembl mule shoe at 4 946' To of ZXP Packer at 4 672' 04:30 05:30 1.00 4,946 4,946 COMPZ RPCOM HOSO P Set string in slips, dropped 1.75" ball and pumped down string. Pressured u on workstrin o 2 0 0 s~ ZXP neutralized pusher tool, bled off workstrin . 05:30 06:00 0.50 4,946 4,946 COMPZ WELCTI OWFF T Crew started to break off top drive for blow down and Driller noticed flow down the flow line. MU top drive and closed upper pipe rams. Had 60 psi on DP and IA max. Bled off DP an IA to 0 si with no additional increase in ressure. 06:00 06:30 0.50 4,946 4,946 COMPZ RPCOM PRTS P Filled IA with charge pump down kill line, RU and tested ZXP x IA at 2 500 si on chart for 5 minutes. Good test. Notified AOGCC Rep John Crisp and Well Engineer of ram closure at 6:30 AM, 2/3/2009. __ ~~ F'~c~~v 6 ©~ ~ r~ Time Logs _ _ _ Date _ From To_ _Dur S. Depth _E_ _ De th Phase Code Subcode T Comment 06:30 _ 08:00 1.50 4,946 4,916 COMPZ WELCTL OWFF T Close annular and strip up workstring 30', pulling the setting tool from the ZXP packer. No pressure increases were observed. One annular volume (167 bbl) and one drill pipe volume (37 bbl) was pumped. With the annular and drillpipe SI the well was monitored for 30 min with no pressure increase in the annulus or drill i e. 08:00 11:30 3.50 4,916 0 COMPZ RPCOM TRIP P POOH standing back the 3-1/2" DP. RD MWD and settin tools. 11:30 13:00 1.50 0 0 COMPZ RPCOM BOPE P Pull wear ring. Set test plug. Test u er variable rams for 3-1 /2" at 250/2500 si. Remove test lu . *** TEST PLUG O-RING MISSING FROM TEST PLUG WHEN PULLED TO SURFACE *** 13:00 14:30 1.50 0 0 COMPZ RPCOM RURD P RU floor to run completion. 14:30 00:00 9.50 0 3,056 COMPZ RPCOM RCST P PU and single in hole to 1,705', start heat trace and cont RIH to 3,056' checking TEC wire and heat trace every 1,000', up weight 60K, down wei ht 57K. 2/04/2009 Cont RIH to 4,712' with 3 1/2" completion, space out, MU hanger and landing joint, spot inhibited seawater, land hanger, test tbg and IA, shear SOV, LD landing jnt and remove ISO sleeve, install 2 way check, ND BOP, NU tree. 00:00 06:00 6.00 3,056 4,672 COMPZ RPCOM RCST P Cont PU and single in hole with 3 1/2" com letion heat trace and Tec wire from 3,056' to 4,672', checking electrical integrity every 1,000', up wei ht 75K, down wei ht 60K. 06:00 0730 1.50 4,672 4,684 COMPZ RPCOM HOSO P Up wt = 75 K#, down wt = 60 K#. Sitting down 20K at 4,684', made several attempts to work through. Needed to rotate completion 90 deg 3 times before seal assembly could pass. RIH and no oat 4 717', sat down 10 K#. Load IA with fluid to surface. Pull up hole 18', drag dropped 3 K# and IA fluid level dro ed. 0730 09:00 1.50 4,713 4,713 COMPZ RPCOM HOSO P Space out completion with 2' space out. MU han er and landin 'oint. 09:00 11:00 2.00 4,713 4,713 COMPZ RPCOM OTHR P Make up heat trace and TEC wire s lices. Test both. 11:00 11:30 0.50 4,713 4,713 COMPZ RPCOM CRIH P Pump 175 bbl of corrosion inhibited seawater (1% CRW-132) down the IA. P~grr 7 of 8 Time LAS __ -- Date From To Dur S De th E. De th Phase Code Subcode T Comment _ 11:30 12:30 1.00 0 0 COMPZ RPCOM HOSO P Land hanger, RILDS. Test tubing packoff assembly to 5,000 psi. USED: 9 x SS bands, 51 single channel couplings, 93 dual channel couplings, 458 x 5' clamps, 3 x 4' clamps, 3 x 3' clamps, 2 x 4' clam s. 12:30 14:30 2.00 0 0 COMPZ RPCOM DHEO P Dro ball and rod. Test tubing to 3,000 si / 15 min. Bleed tubing to 2,250 psi. Test IA to 3,000 qsi / 30 in A nd tubin pressure. Pressure up IA to 1,300 psi and shear out the SOV in GLM #2 at 4,505'. 14:30 15:00 0.50 0 0 COMPZ RPCOM OTHR P Set two wa check. 15:00 21:00 6.00 0 0 COMPZ RPCOM NUND P ND BOP, remove annular and install lifting plate, re-install annular on stack and rack back on stum . 21:00 23:00 2.00 0 0 COMPZ RPCOM DHEQ P Splice Tec wire and test, test heat trace, tests ood. 23:00 00:00 .1.00 0 0 COMPZ RPCOM NUND P NU tree/ 2/05/2009 Freeze protect well, secure and dress tree, RDMO 1 E-121. Nordic Ri #3 released from 1 E-121 on 02-05-2009 07:30 am. 00:00 00:30 0.50 0 0 COMPZ RPCOM NUND P Cont NU tree. Test tec wire and heat trace inte ri ood tests. 00:30 02:30 2.00 0 0 COMPZ RPCOM PRTS P Test hanger and void at 250/5,000 psi for 10 minutes, good test. RU LRS and test circ lines and tree at 250/5,000 si, ood tests. 02:30 04:30 2.00 0 0 COMPZ RPCOM FRZP P Freeze protect well with 120 bbls down IA at 3 bpm, taking returns to pits, shut down LRS and allow diesel toe ualize. 04:30 07:30 3.00 0 0 COMPZ RPCOM DMOB P Clean pits and cuttings box, blow down circ hoses, secure well and dress tree, secure pipe in derrick for rig move, Nordic Ri #3 released from 1 E-121 on 02-05-2009 07:30 am. 121 Pre and Post Rig Well Work Summary DATE SUMMARY 8/26/08 TAG AND START BAILING SAND FROM 3883' TO 3971' SLM, 200' ABOV _ UMP. JOB SUSPENDED FOR CLEAN OUT. 8/31/08 PULLED SLIP STOP & PACKOFF FROM 4197 CTMD AFTER CLEANOUT RUN, WILL RTN IN A.M. TO PULL ESP. 9/1/08 PULLED ESP FROM 4206 CTMD. SET PUMP IN DEPLOYMENT FLANGE, READY FOR S/L. 9/5/08 PULLED 44.2' ESP PUMP FROM DEPLOYMENT FLANGE. SET CATCHER SUB @ 4247' RKB, PULLED SHEARED SOV @ 3594' RKB AND REPLACED W/NEW 2000 PSI TBG. SHEAR VALVE. PULLED EMPTY CATCHER SUB @ 4247' RKB. NEED TO RUN NEW PUMP WHEN AVAILABLE. 9/14/08 (PRE-RWO) UPPER TPOT -PASSED. UPPER T PPPOT -PASSED. LOWER TPOT - PASSED. LOWER T PPPOT -PASSED. IC POT (UNABLE TO TEST IC DUE TO LEAKING ALEMITE FITTING) 9/22/08 SET 4-1/2" x 44' ESP @ 4236' WLM SET 4-1/2" PACK OFF ASS'Y, TOP @ 4189' WLM (100" OAL, KOBE 35-1/2" FROM TOP, 89" TO CHECK). TESTED PACKOFF, GOOD. COMPLETE. 10/10/08 ATTEMPTED DRIFT TBG, ENCOUNTERED OBSTRUCTION AT /NEAR TBG HANGER @ 2' SLM. ATTEMPTED BAIL SAMPLE, NO RECOVERY. PUMPED 30 BBL HOT DSL, FAILED TO CLEAR. IN PROGRESS. 10/11/08 IDENTIFIED OBSTRUCTION 2' SLM: PACKOFF ASS'Y. PULLED SAME, MISSING ELEMENT. TAGGED 3.8" x 44' ESP @ 9' SLM. READY FOR CTU. 10/15/08 ABLE TO MOVE ESP PUMP DOWN HOLE 18' CTMD (27' FROM HANGER), HIT OBSTRUCTION AND WAS UNABLE TO GAIN ANY ADDITIONAL FOOTAGE UTILIZING HIPP TRIPPER AND PUMPING DOWN THE CTxTBG ANN. AT 4 BPM WITH HOT OIL TRUCK, PUMP MOVES FREELY UP HOLE PUMPED OFF FISH c)N RTM Tl1RN OVER TO SLICKLINE. _ COIL PUMPED 226 BBLS DIESEL HOT OIL PUMPED 75 BBLS DIESEL 10/20/08 ENGAGED 4-1/2" x 44' ESP @ 29' WLM. UNABLE TO INITIATE MOVEMENT IN EITHER DIRECTION. PUMPED 45 BBL HOT DSL DOWN TBG & RE-ENGAGED PUMP. UNABLE TO INITIATE MOVEMENT IN EITHER DIRECTION. JOB SUSPENDED. 10/26/08 LOST TOOL STRING WHILE ATTEMPTING TO KNOCK ESP PUMP DOWN HOLE @ 27' SLM .RECOVERED COMPLETE TOOL ASSY @ 382' SLM. KNOCKED PUMP DOWN HOLE FROM 403' SLM TO 2652' ("`'`*PUMP ACROSS TOP MANDREL @ 2675' RKB**"). UNABLE TO PUSH FURTHER DOWN HOLE. RAN 3" PUMP BAILER TO 2652' SLM. F/N ON PUMP CLEAN. JOB SUSPENDED UNTIL A CRANE IS AVAILABLE. 10/28/08 PULLED TOP SECTION OF PUMP (OAL= 57"/ BTM OD FLARED OUT TO 3.875") FROM .2662' SLM. '"`'`PUMP WAS PARTED Cad THREADED SECTION ABOVE INTERNAL FINS*"" TAG TOP OF PUMP WITH 3.70" LIB @ 4156' SLM. OBTAINED CLEAR PICTURE OF .75" ROD LOOKING UP HOLE (CENTER OF TBG). JOB SUSPENDED. 11/2/08 ATTEMPTED TO PUSH ESP DOWN HOLE. TAG (c~ 4183'~I~IID. RATTLED ON IT WITH HIP TRIPPER AND TRIED USING JARS, WAS UNSUCSEFULL IN MOVING. CONTACTED WEST SAK ENG, HE WAS OK WITH DEPTH. LEFT WELL SHUT IN AND FREEZE PROTECTED. 11/6/08 GAUGED TBG TO 2.79" TO 4160' SLM. SET SLIP STOP & CATCHER @ 4160' SLM. PULLED SOV @ 3594' & DV @ 2675' RKB. SET GLV @ 2675', OV @ 3594' RKB. ~~~ PULLED CATCHER @ 4159' SLM. COMPLETE. ~ .~stF~~ Ord ~V '' 1/23/09 SET CATCHER @ 4160' SLM, PULLED OV @ 3594' RKB &GLV @ 2675' RKB, d-S ~~~~ REPLACED W/ DVs, PULLED CATCHER @ 4160' SLM, PULLED SLIP STOP @ 4164' SLM, RDMO. DHD SHOT FLUID LEVEL (3000'), LRS PUMPED 95 BBLS DIESEL DOWN IA VERIFYING COMMUNICATION. 1/31/09 PERFORM CALIPER SURVEY FROM 4831' SLM TO 4600' SLM ""*JOB COMPLETE"** 2/12/09 PULL BALL & ROD t~ 4614' RKB, PULL SOV @ 4506' RKB, SET 1" OV (5/16" PORT) @ 4506' RKB, PULLED RHC BODY @ 4614' RKB, «RHC BODY STUCK @ 492' SLM» IN PROGRESS. 121 Pre and Post Rig Well Work Summary 2/13/09 PULLED RHC BODY FROM 'DS' NIP Cad 516' RKB. ((KEY RETAINER HOU~G HAS METAL EMBEDDED INTO THE OD)) JOB COMPLETE. Ram Closure on 1E-121 • Page 1 of 1 l~ iZct I L - (z ~ Regg, James B (DOA) n~ 2t14 _ Zq,~ From: Nordic 3 Company Man [n1433@conocophillips.com] Sent: Tuesday, February 03, 2009 9:44 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Fleckenstein, Robert J (DOA) Cc: Packer, Brett B; Nordic 3 Company Man Subject: Ram Closure on 1 E-121 ~ Gentlemen, 05:30 AM: Nordic Rig 3 had just oriented and set an LEM assembly and ZXP packer in well 1 E-121. At 5:45 AM the crew had just bled off 3,500 psi from the workstring, and was in the process of breaking off the top drive to blow it down. The driller observed flow at the flow line via the flow paddle sensor on the driller's console. Driller then closed the upper variable pipe rams and made up the top drive on the drill string. SIDP and SICP reached a maximum pressure of 60 psi. after 15 minutes of closure. Both the drill string and IA were then bled off and no further pressure was obtained. Both the IA and workstring were isolated to the formations by the ZXP packer and the 1.75" seated ball. 06:00 AM: the crew filled the 7 5/8" IA with a charge pump through the kill line and performed a successful ZXP x IA pressure test of 2,500 psi for 5 minutes as per the well plan. 06:30 AM: the annular was closed and workstring was pulled up 30', pulling the setting tool from the ZXP packer. No pressure increases were observed. One annular volume (167 bbl) and one drill pipe volume (37 bbl) was pumped. With the annular and drillpipe SI the well was monitored fro 30 min with no pressure increase in the annulus or drillpipe. 08:00 AM: Start pulling out of hole with 3-1/2" drillpipe workstring while pumping 100 bbl / hr of seawater with 6% KCL (8.8 ppg) into the annulus. Well continues to drink fluid. Please contact us if you require any further information. Peter Nezaticky /Rick Overstreet (Days) Rance Pederson /Randy Dolcater (Nights) Nordic 3 Company Man Office: 907-659-7446 Fax: 907-659-7566 2/5/2009 ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. F~ease acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport R,~ ~ayY~, ~; ~ `i (l ~~~ Suite C Anchorage, AK 99518 fax (907j 245-8952 ~~ 1 ] Caliper Report 01-Feb-09 1 E-121 2) ~o~l- ~I( 1 Report / EDE 50-029-23238-00 C~~~ 5 a ~ ~~ ~ t ,~ ~~ ~v ~~ ;~ Signed . p ~, a Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907245-8951 FAX: (907)245-88952 E-WAIL : ~at3sass~~4racteCr~s~n~~c:ryi~a.c~rra WEBSITE: r~.r;3e~acsrr73oq.ccar~ C:~Documerts and Settings\OamerlDesktop\TransRUt Conoco.doc~c • • Memory Mu~t~-Finger Caliper S ,,. L©g Results. Summary Company: ConocaPhillips Alaska, tnc. Well: 1 E-121 Log Date: February 1, 2009 Field: Kuparuk Log No.: 6742 State: Alaska Run No.: 1 API No.: 50-029-2323$-00 Pipet Desc.: 7.625" 29.7 Ib. L-80 Bl'CM Top Log Intvl1.: 4,578 Ft. (MD) Pipet Use: Casing Bot. Log Intvl1.: 4,816 Ft. (MD) Inspection Type : Restriction Inspection COMMENTS: This caliper data is fled into the top of the Baker B2 Flange Hook Hanger ~ 4,81 Z' (Driller's Depth). This log was run to identify restrictions at the 'D' sand lateral. A restriction prevented the caliper from reaching the desired log depth. As a result, the caliper recorded from the Baker 82 flange hook hanger at 4,816' to 4,578'. A second pass was nat made since the tool could not reach the target depth. No significant wall penetrations or areas of crass-sectional wall loss are recorded in the 7.625" casing logged. A 3-D log plot of the caliper recordings across the top of the Baker B2 flange hook hanger is included in this report. The joint numbering used in this report is an approximation based on average joint lengths. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 7%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> 4%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS : Np significant I.D. restrictions are recorded. ~_~ Field Engineer: N. Kesseru Analyst: C. Waldrop Witness: R. Peterson ProActive Diagnostic Services, Inc. / P.G. Box 1369, Stafford, TX 77497 Phone: {281) or {888) 565-9085 Fax: {281) 565-1369 E-mail: PDS~a!memoryiog.com Prudhoe Bay Field Gffice Phone: (907) 659-2307 Fax: {907) 659-2314 .~b~~-a~,~ l~s~ ~- • • PDS Multifinger Caliper 3D Log Plot ~._S """T "" Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1E-121 Date : February 1, 2009 Description : Detail of Calper Recordings Across Baker 62 Flange Hook Hanger at 4,81 Z' Comments Depth Max ID (111000 in.) 3-D Log Image Map 1ft:80ft 5400 7400 175° 0° 90° 180° 270° 0° Min ID (1!1000 in.) 5400 7400 Nominal ID (1!1000 in.) i ...................................................................... 5400 7400 Joint 1os 4780 _ ' - i r - _ 4765 - - - 4790 -~ _ ~ --='° Joint 109 4795 , - _ ~ -_ 4800 r _~ ~ _'~ _ ~- _ _ . _ 4805 Joint 110 - - 4810 r Orientation Slot in B2 _ __ -. -- ~ -- - - -- + ~ : ~ __- - - - Hook Hanger 4815 ~ __ - - - __ ,,,.. - Nominal ID (1/1000 in.) 5400 7400- Min ID (1!1000 in.) 5400 7400 Comments Depth Max ID (1/1000 in.) 3-D Log Image Map 1ft:80ft 5400 7400 175° 0' 90° 180° 270° 0° • PDS REPORT JOINT TABI. Pipe: 7.625 in 29.7 ppf L-80 BTCM Well: Body Wall: 0.374 in Field: Upset Wall: 0.374 in Company: Nominal I.D.: 6.876 in Country: Survey Date: • ELATION SHEET 1E-121 Kuparuk ConocoPhillips Alaska, Inc usA February 1, 2009 Joint No. )t. Depth (Ft.) P~~n. ul,~~~t (In>.) Pen. Body (Ins.) Pen. % ~Ic~~.~l Iris ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 105 4610 ~ ~ 0.01 ~ 6 1 106 46 4 c~ 0. 2 6 I 6.8 107 46 7 ~ ~ 0. 1 1 I .80 1 8 4740 ~~ 0 03 7 .79 109 4784 ~ ~ 0.01 3 1 6. 110 4804 ~ ~ .0 U -1 6.79 1 0.1 1 ~ ~ 0 ~ ~ 5.51 Baker odel B2 Flan a ook Han er ®Penetration Body Metal Loss Body Page 1 °A ConocoPhillips ~~ $9~rEr Ott TOOtt West Sak 7-518" Producer 1 E-121 Dual Lateral Completion MD, 2403' TVD, 37.2° -Gas Litt Mandrel, 4-117' X 1" KBG2 10-314" 45.5# Casing Shoe, set ~ 2662' MD, 2394' TVD Tubing String ~ 4-117' 12.6la~, L-80, IBTM 5.868" ID, 3.833" Drift 3593' MD, 3112' TVD, 64.6° -Gas Lift Mandrel, 4-1/T' X 1" KBG2 4309' MD, 3433' TVD, 64.7° -Bottom of Motor Centrizr -Electric Submersible Pump, Centralitt 418 HP Motor FINAL As Com Ip eted D-sand Window 'D' Sand Lateral ~ 4818' MD, 75 Deg Inc ' 4-1/2" 12.9k, L-~, IBTM, 4837' MD -Liner ~ ed Liner Swivel, 4.112" !!!/// ~ 3-1/2" Bent Joint ,-~ 3-1/2" Guide Shoe 4812' MD -4-112' X 7-618" Model'B' HOOK Hanger ~ 3-112" Casing Shoe, 12.6#, L-80 IBTM 12336' MD - Set ~ 12383' M D, 3670' TVD Pack-01r Bushing 5.112" X 7618" ZXP Liner Top Packer / with Hold Downs / 6.112" X 7-618" Flex Lock Liner Hanger /Packer Assembly Liner Hanger at 4905' MD 4937 MD -Casing Sealbore Receptacle 4.75" ID, 6.25" OD CONFIDENTIAL 20' Length 'B' Sand Lateral 4-1/2" 12.6q, L-80, IBTM, Slotted Liner Izfi Jolrrts DwC ~ottsd on batorn) 4-112" Eccentric Guide Shoe Eaulument SDeciflcations 4-1/2" X 7-618" HOOK Hanger Malnbor6 Drift: 5.57' Mdnbae dill, vMh dlvxter. 4.63" Cabral dIR, ro dlvxtx or LEM: 3.88" Latxal dfR, vel divxtx, ro L[1t1: 3.88" LataraVMalnbors Dlwrtx OD: 8.75" 41/2" Casing Shoe, 12.6#, L-80 IBTM 12354' MD- Set ~ 12388' MD, 3740' TVD 7-518" Casing Shce, Pack-ott Bushing Set at ~ 5267' M D, 3694' TVD e.wr ~x,4n•• 4o6a.1ni. a«°m.nr ...y nn 6• np•auwa er a.vt°uew, in wna• « in nwR ~n x,y roan er 6r .nr m••n. ~•.r,°m• °r Twn.nieai, ~nmuam0 ~~ VV••t ~~' PnaeeePNn6, n<erai,p, x or •nr hwonn•nen •er•6, .°° na+•ni .rre•m new wnewn er n•...rts inwrd•4 wnl.eut wna.n r..rmu•ion rrom e.w•. Huyn•. inc. Or0• Anuw .4006 ConocoPhillips Alaska, Inc. KRU 1 E-121 1 E-1 1 API: 500 92323800 Well T : PROD An le T : d TUBING ~o-aza7, oo:a.5oo SSSV Type: NONE Orig Com etion: 2/8/2005 Angle ~ TD: 88 deg ~ 12415 , ID:3.958) , ~ Annular Fluid: Last W/O: Rev Resaon: Set Padcoff, Sli st - ( ; Referen : 28' RKB Ref L Date: st U ets: 8 /2005 ' Lest Ta : TD: 12415 ftKB Last Tag Date: Max Hole e: 93 deg ~ 11629 ~""ED'A~ (0.5267 Casin Strin -COMMON STRINGS , o0:7.sz5, _ Desc ' lion ize Bottom TVD Wt G e Thread wt2s.7o> CONDUCT R 20.000 0 08 1 8 8 .50 H-4 WELDED SURFACE 10.750 0 2882 2394 45.50 L-80 BTC INTERMEDIATE 7.625 0 5287 3694 28.70 L-80 BTCM D,~~rye Casin Strin -LINER B-SAND Press. Sub escri lion Size To Bottom ND Wt Grade Thread (ai7t-ar7z, D 5 75 SLOTTED LINER .500 4905 12388 3741 2.80 0 WC/IB o : .8 ) Tubin Strin -TUBING PUMP ASSEMBLY Size T Bottum ND Wt Grade Thread (azza-az7i, 4.500 0 4247 3408 12.80 -80 IBT OD 3 790) SCREEN Pertorations Summa (aza7azae, Interval ND Zone Sta s Ft 5PF Date T mmen OD:5.130) sEA~ (4257-4271, OD:5.130) (4271-4305, oD:s.szo) 5272 - 5869 3895 - 3717 W5 B 397 32 1/28/2005 IPERF FOR ALL PERFS: Slotted liner altemeting w/blank pipe, w/constrictor packers ~ 5871', 5888', 6494', 6744', 12023', 1224$' 5888 -6496 3727 - 3742 WS B 610 32 1/26/2005 IPERF 8745 - 1 003 3749 - 3732 WS B 5 58 32 1/26/20 IPERF 12258 - 12350 3733 - 3738 WS B 92 32 1/26/2005 IPERF ;.~ ,. . Ga s Lift M andr elsNalve s GAUGE (a3o5-a3o7, `~~°` St MD ND Men Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt ~+~) ~~ 1 2675 2404 CAMCO KB - DMY 1.0 BK-5 0. 0 05 2 3594 3113 CAMCO KBG-2 SOV 1.0 BK-5 0.000 0 1 1. 2000# TUBING Other I s ui .etc. - C MMON JEWELRY D ND T Deacri tion ID HANGERte 33 33 HANGER VETCO GRAY HANGER w/MCA TOP CONNECTION 4.500 ~~ (4aiz-aaza, OD:7.625) 4171 3375 Discharge Press. S b A-WELL DISCHARGE PRESSURE SUB 3.958 wiNDOw ~ o0~0~7) 4224 3398 PUMP ASSEMBL SET 44' 2" ESP PUMP ~ 4271' RKB. SET 3/14/2005 SET 4 iR PACKOFF ASSEMBLY ~ 4224' RKB / 4191' SLM (109" OAL-36 12' FROM F.N. TO KOBE KNOCK OUT-43112" FROM F.N. TO FLAPPER ). SET 41/2 SLIP STOP ONTOP OF PACKOFF ASSEMBLY ~ 4183' SLM aet 8/5/2005 0.000 PACKER 47 34 8 S R EN CEN RILIFT C /INTAKE SCREE OSS OV R .830 (+9°~+~~ 57 3412 S L C NT I IFT TAND M SEAL SECTIO GS833 DB AB / S PF 4.630 oD.7.soo) 4271 3418 MOTOR CENTRILIFT MOTOR KMH 1418 HP! 2810 V ! 98 A 0.000 rt P 4305 3433 GAUGE CENTRILIFT A-1 PUMP GAUGE 0000 PSI w/DISCH PRESS 0.000 e (5z7z-ssas) - 4307 Centrelizer CENTR LIFT MOTOR CENTRALIZER .000 I 4812 3800 HANGER to L1 BAKER MODEL B2 FLANGE HOOK HANGER TO D-SAND LATERAL L1 4.500 Other u s ui ,etc. - B-SAND J WELRY De th ND T Descri lion ID Pert ~ ~ 4816 3601 WINDOW WINDOW TO D-SAND LINER 6.875 (~~'64~) 4905 3828 PACKER ZXP LIN R TOP PAC R 5500 ~ 12354 3738 PACK FF 4.5" BAKER DRILLABLE PACKOFF 3.950 Gener al Notes Date Noss 2/5/2005 MULTI-LATERAL WELL -THIS IS B-SAND VIEW• LATERAL L1 DSAND 2/6/2005 TREE: ABB VETCO GRAY/ Horz14-1/16' 5M (w/PENETRATOR WIRE) REE CAP CONN CTION: 9' OTIS Part ~2zsa-i235o) I ~ ~ I ConocoPhillips Alaska, Inc. KRU 1 E-121 L1 1E-121L1 API: 500 32 60 I T : PRO T TUBING (a4za7, 0°:4"500, SSSV Type: NONE Orig Com etion: 2B/2005 Angle ~ TD: 90 deg ~ 12414 1°:3.958) TERMEDIATE _ __ -- "~ ~ Annular Fluid: Lsat WlO: Rev Reason: Set Packoff, Sli t0 (0.5267, o°:7 s25 eferen L 28' RK Ref L te: U ate: 8 . , wr2s.7o) Last Te TD: 12414 ttK6 ' Last Tag Date: Max Hole An le: 94 deg ~ 12143 Casin Strin -COMMON STRINGS Gas Llrt _ _~ ~Desc ' lion Siz To Bottom TVD Wt de Thread MarMreUVahe - ~ CONDUCTOR .000 0 108 10 82.50 H WELDED 2 (35943595 _ ~ ~ SURFACE 10.750 0 2882 2384 45.50 L-BO BTC , ~ fNTERMEDIATE 7.825 0 5287 3641 29.70 L-80 BTCM WINDO 7.825 481 4$2 36 0.00 Casin SVi -LINER D-SAND D 'lion Size T Bottom TVD Wt Grade Thread °IscAarye LINER D-SAN 4.5 4812 12 3 3871 1 .80 -80 IB Press. Sub (4f7f-ant, Tubin Strin -TUBING OD:5.875) Sim To om TVD Wt Grade Three 4.500 0 4247 3408 12.80 L-80 IBT PUMP AssEMI3LV Perforations Summer (azza-a27~• Into I TVD Zoe Status t SPF Dete T Co en OD 3 790) SCREEN (4247-4248, 0°:5.+30) sEAL 4904 -8831 3621 - 3708 WS D 3927 32 2/4/2005 IPERF ALL PERFS: Slotted tubing w/alternating slotted/blenk pipe w/constrictors ~ 8851', 9031' 11881' 12152' (4257-4z7f, 9048 -11986 3709 - 3674 WS D 18 32 2/4/2005 IPERF o°:s.f3o) MOTOR (4271-4305 12150 - 12335 3677 -3671 WS C,W3 D 185 32 2/412005 IPERF , 0°:5"620) Gas Lift M andr els/Velve s Si MD TVD Men Mfr Man Type V Mfr V Type V OD Latch Port TRO Dete Run Vlv Cmnt 1 2675 2404 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 218!2005 GAUGE (a305-4307 3594 3113 AMCO G SOY 1. BK-5 0. 0 /13/2005 1 o°:a.6oo) ~~ 1. 2000# T(181NG Cer>iralfm Other I s ui .etc. - D-SAND J LRY (4~~-a~~ De TVD T escri 'on ID OD 6"00°) 12354 3671 PACKOFF BAKER DRILLABLE PACKOFF 3.950 Other u ui .etc. -COMMON JEWELRY D TVD T e Descri bon ID 33 33 HANGER VETCO GRAY HANGER w/MCA TOP CONNECTION 4.500 HANOERTO 4171 3375 Dischar e A-WELL DISCHARGE PRESSURE SUB 3 958 L1 g ub . (~ ~tyj ~ ~ 4224 3398 PUMP ASSEMBt SET 44' 2' ESP PUMP ~ 4271' RKB 3/14/2005. SET 41/2 PACKOFF ASSEMBLY ~ 4224' RKB / 4191' SI.M (109' OAL-36 1/2' FROM F.N. TO KOBE KNOCK OUT-431/2' FROM F.N. TO FLAPPER ). SET 4 1/2 SLIP STOP ONTOP OF PACKOFF ASSEMBLY ~ 4183' SLM set 8/5/2005 0.000 LINER I 4247 3408 SCREEN CENTRILIFT TCC /INTAKE SCREEN TTC CROSSOVER 4.630 ° AND (4812-12363 4257 3412 SEAL CENTRI IFT TANDEM SEAL SECTION GSBEE DB A / S PF A 4. 0 , 00'4.500, 42]1 3418 MOTOR CENTRILIFT MOTOR KMH / 418 HP / 2810 V 198 A 0.000 ~/1t12°0> ' ' 4305 3433 GAUGE CENTRILIFT A-1 PUMP GAUGE 0-5000 PSI W/DISCH PRESS. 0.000 4307 3433 Centrelimr CENTRILIFT MOTOR CENTRALIZER 0.000 4812 3600 HANGER TO L1 BAKER MODEL B2 FLANGE HOOK HANGER TO D-SAND LATERAL L1 4.500 (49oa-aaij Gener al Note s ate Note 2/6/2005 TREE: ABB VETCO GRAY! Horz/4-1/16.5M (w/PENETRATOR WIRE) TREE CAP CONNECTION: 9" OTIS 2/6 5 MULTI-LATERAL WELL -THIS IS D-SAND L1 VIEW MAIN LEG BSAND Perf (904&11966) Perf 12160.12335) I ~ ~ I • ~ RECEI~E® STATE OF ALASKA DEC 2 9 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIQ~Sta oil & Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Welt ^ Plug Perforations ^ Stimulate ^ Other C Failed ESP to Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Gaslift Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development^ ' Exploratory ^ 204-246 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23238-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 99' 1 E-121 8. Property Designation: 10. Field/Pool(s): ALK 25651 ~& 25648 + Kuparuk River FieIdIVllest Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12415' feet true vertical 3742' feet Plugs (measured) Effective Depth measured 12386 feet Junk (measured) true vertical 3740 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 20" tos' 108' SURFACE 2563' 10-3/4" 2662' 2394' INTERMEDIATE 5168' 7-5/8" 5267' 3694' D SAND WINDO\ 12' 7-5/8" 4828' 3604' B SAND SLOTTE 7483' 4-1/2" 12388 3741' Perforation depth: Measured depth: 5272'-5669; 5886'-6496'; 6745'-12003'; 12258'-12350' true vertical depth: 3695'-3717'; 3727'-3742'; 3748'-3734'; 3733'-3738' Tubing (size, grade, and measured depth) 4-1/2", L-80, 4247 M0. M~ ~ Packers &SSSV (type & measured depth) Packer =None SSSV =None 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 Pressun; Tubin Pressure Prior to well operation 644 565 54 179 182 Subsequent to operation 484 281 29 789 319 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: 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: NIA contact B. Christensen/ D. Humphrey Printed Name R e . D. C ensen title Production Engineering Specialist Signature -- Phone: 659-7535 Date ~ as, Form 10-404 Revised 04/2004 t ~ vlt;~ ~ A i!EiQ ~~ ~. z • cy ~~~~J Submit ~ J • • 1 E-121 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/06/08 GAUGED TBG TO 2.79" TO 4160' SLM. SET SLIP STOP & CATCHER @ 4160' SLM. PULLED SOV @ 3594' & DV @ 2675' RKB. SET GLV @ 2675', OV @ 3594' RKB. PULLED CATCHER @ 4159' SLM. COMPLETE. ~~ KUP ~ 1 E-121 COIIOCOP~II~~IPS Well Attributes A49sr., t. In' Wellbore API/UWI Field Name Well Status Protl/Inj Well Type Inc! (°) MD (ftKB) TD (max) (/t... 500292323860 WEST SAK PROD 93.60 12,143.27 12,415.0 ••• NI ConA:-1E-721 no2o oe ss7 a4 AM Comment H2S IPPm) Date Annotation Entl Data KBl3rtl ((q SSSV: NONE 20 7/1/2008 Last WO: 33.61 Rlg Release Date 2/6/2005 emetic-Actu al Annotation Depth I(tK8) End Date Annotation End Date Last Tag: CTMD 4,183.0 11/2/2008 Rev Reason: Set Slipstop on ESP Pump remains, GLV C/O 11!7/2008 Casin Strin s Caaing Oescrlptlon String OD (~n) String ID (in) Top (ftl(B) Set Depth (RKB) Set Depm (TVD) (flNB) String Wt (Ibal(t) String Grade S[ring TOp Thrtl CONDUCTOR 2 0 19.124 0.0 108.0 108.0 62.50 Hv10 WELDED SURFACE 103/ 4 9.794 0.0 2,662.0 2,394.6 45.50 L-80 BTC INTERMEDIATE 75/ 8 6.875 0.0 5,267.0 3,693.7 29.70 L-80 BTCM coNOUCroft toe DSAND WINDOW 75/ 8 6.825 4,816.0 4,828.0 3,604.6 B SAND SLOTS 4 1/ 2 3.958 4,905.0 12,388.0 3,740.6 12.60 L-80 DWC/IBT Tubin Strin s SURFACE, 2662 Tubing Deacriptlon String OD tin) Slring 10 (in) Top (ftH B) Set Dap[h (RKB) Set Depth (TVD) (RKB) String Wt (IDsI(t) String Gratle String Top Thrtl TUBING 41/ 2 3.958 33.0 4,247.0 3,407.9 12.60 L-80 IBT G Other in Hole All Jewel :Tubi n Run 3 Retrievable Fish etc. AS uFT, 2675 Top (ftKB) Tap Depth (TVD) (RKB) Top Intl 1°) Desoriptlon Comment Run Dale ID (In) GAS LIFT 33.0 33.0 0.50 HANGER VETCO GRAY HANGER w/MCA TOP CONNECTION 2/6/2005 4.500 . 3ss4 2,675.0 2,404.8 37.82 GAS LIFT CAMCOIKBG2/1/GLV/BK5L188/1495/ Comment: STA 1 11/6/2008 3.938 3,594.0 3,111.9 56.45 GAS LIFT CAMCO/KBG2/ilOVIBKS/.313// Comment: STA 2 11/6/2008 3.938 4,160.0 3,371.4 65.20 SLIP STOP SLIP STOP/CATCHER SET ON TOP OF REMAINING ESP 11/612008 2.230 PUMP 4,171.0 3,375.9 65.17 DISCHARGE A-WELL DISCHARGE PRESSURE SUB 2/6/2005 3.958 olscHARGE, q~177 SLIP STOP. 4,186.0 3,382.2 65.12 FISH (ESP) Centrilift 109 P35 ESP w/Rotary gas separator STUCK @ 4183'. CTU tag & attempted pull 11Y1/2008 9Y22/2008 0.000 q'1fi0 4,247.0 3,407.9 64.94 SCREEN CENTRILIFr TCC /INTAKE SCREEN TTC CROSSOVER 2/6/2005 4.630 FISH (ESP), 4.1efi ~; ~ ~ 4,257.0 3,412.1 64.91 SEAL CENTRILIFTTANDEMSEALSECTIONGSBEEDBAB/ HSN PFSA 2/6/2005 4.630 4,271.0 3,418.1 64.87 MOTOR CENTRILIFr MOTOR KMH / 418 HP / 2610 V / 98 A 2/6/2005 0.000 4,305.0 3,432.5 64.77 GAUGE CENTRWFf A-1 GAUGE 0-5000 PSI W/DISCH PRESS. 2/6/2005 0.01)0 scREEN, o zo 4,307.0 3,433.4 64.76 CenValizer CENTRILIFT MOTOR CENTRALIZER 2/6/2005 5.000 - 4,812.0 3,600.3 74.81 L1 HANGER 0.SAND BAKER MODEL 82 FLANGE HOOK HANGER Z/4/2005 4.500 SEAL, 0,257 MOTOR, 0,277 Perforations GAUGE, 0,305 Cenhal¢er. 0 307 Top (TVD) Blm (TVD) Shot Dena , Lt HANGER, Top (ftNB) Btm (HNB) (RKB) (nKej Zone Data lah... Type Comment q.61z CSG WINDOW, e,ets F "` A I ZTVTT"' 5,272.0 5,669.0 3,694.8 3,716.5 WS B, 1E-121 1/26/2005 32.0 IPERF ALLAltematin SLOTS/BLANKS g w/constrictor packers @5671', 5886', Lt HANGER. 812 6494'.6744', 12023'. 12248' DsANO wlNOOw, 6ze 5,886.0 6,496.0 3,726.7 3,741.7 WS 8, 1E-121 1/26/2005 32.O IPERF ALLAltemati SLOTS/BLANKS n9 a. TERMEDIATE, 6,745.0 12,003.0 3,748.2 3,734.0 WS B, 1E-121 1/26/2005 32.0 IPERF ALLAltemati SLOTS/BLANKS n9 IPERF s z7z s 6w 12,258.0 12,350.0 3,733.2 3,738.2 WS 6, 1E-121 1126/2005 32.0 IPERF ALL Altemaerg SLOTS/BLANKS , . , IPERF, Notes: General 8 Safe 5,666-6.496 PERF End Date Annotation , 6.74s-tz,oo3 (PERF 2l6/2005 NOTE: TREE - ABB VETCO GRAY / Horz / 4-1/16"" SM (w/PENETRATOR WIRE) tz,2se-tz.3sd D SAND 2/6/2005 NOTE: MULTI-LATERAL WELL-tE-121 (BSAND), 1E-121L7 (0.SAND) sl.ors.1z,363 2/6!2005 NOTE: TREE CAP CONNECTION: 9"" OTIS 11/212008 NOTE: WILL ATTEMPT TO FLOW AROUND STUCK ESP PUMP 1176/2008 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT I e sANo sLOrs, tz,3ee TD (1E-127). 12,015 i FW: West Sak 1E-121 (PTD# 204-246) Convert To Gas Lift Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: .Monday, November 10, 2008 2;12 PM To: 'NSK Problem Well Supv' Cc: Regg, James B (DOA); NSK Prod Engr Specialist; NSK West Sak Prod Engr Subject: RE: West Sak 1 E-121 (PTD# 204-246). Convert To Gas Lift Walter, Submitting the 404 only is acceptable. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, November 03, 2008 3:51 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); NSK Problem Well Supv; NSK Prod Engr Specialist; NSK West Sak Prod Engr Subject: FW: West Sak 1E-121 (PTD# 204-246) Convert To Gas Lift Tom, An attempt was made to pull the pump in hopes of repairing the ESP instead. CTU was unable to pull the pump and it is stuck @ 4183' CTMD. The current plan is to gas lift the well until the RWO. Is it necessary to send in a 10-403 or will a 10-404 be sufficient? Please advise. Attached is a current schematic. «1E-121 schematic.pdf» Thank you. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 v' i~f,~D ilr7 From: NSK Problem Well Supv Sent: Friday, August 22, 2008 4:32 PM To: 'tom.maunder@alaska.gov'; 'jim.regg@alaska.gov' Cc: NSK Well Integrity Proj; NSK Problem Well Supv; NSK West Sak Prod Engr; CPFl DS Lead Techs; 7enkins, Lubbie Allen Subject: West Sak 3E-121 (PTD# 204-246) Convert To Gas lift Tom/Jim, 11/10/2008 FW: West Sak 1E-121 (PTD# 204-246) Convert To Gas Lift Page 2 of 2 West Sak ESP producer 1 E-121 (PTD# 204-246) was shut down on August 10, 2008 due to excessive motor temperature. CPAI has elected to not run the motor to failure, as this will prevent the downhole gauges from transmitting data to the surface. It is our intent to convert this well to gaslift and since it is not permitted with gaslift as a backup, we will submit a 10-43 requesting permission to do so. Attached is the most recent wellbore schematic and a 90 day TIO plot. «1E-121 Wellbore Schematic.pdf» «1E-121 TIO Plot.ppt» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 11/10/2008 ConocoP hi~l~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 ~~~~~~~ AUG ~ ~ 208 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • REC~~VE~ AUG 2 5 2008 Alaska pig & Gas Cons. cO~r+~~'~Slc~n Ancho.~ga ao~.- 6 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 2-17, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kle .~ ~ ~ Z ~~~ ~ ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off r)a+a ~~ Report of Sundry Operations (10-404) Kuparuk Field --- tf/7 //LUUS Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # cement um ed cement date inhibitor sealant date ft bbls ft al 2H-05 185-168 SF N/A SF N/A 5.10 8/2/2007 2H-17 200-019 6" N/A 6" N/A 1.27 8/2/2007 2K-27 201-169 10" N/A 10" N/A 8.92 8/2/2007 2M-03 191-141 16" N/A 16" N/A 2.13 8/2!2007 1B-14 194-030 SF N/A SF N/A 1.70 8/13/2008 1 B-18 194-061 9" N/A 9" N/A 8.07 8/13/2008 1 B-19 194-064 SF N/A SF N/A 5.10 8/13/2008 1B-20 203-115 21" N/A 21" N/A 5.95 8/13/2008 1 B-101 203-133 3" N/A 3" N/A 1.00 8/17/2008 1 B-102 203-122 4" N/A 4" N/A 1.00 8/17/2008 1Y-05 183-087 6" N/A 6" N/A 1.27 8/13/2008 1 Y-07 183-068 6" N/A 6" N/A 1.27 8/13/2008 1Y-17 193-068 SF N/A SF N/A 1.27 8/13/2008 1Y-22 193-070 SF N/A SF N/A 2 12 8/13/2008 1Y-26a 188-116 SF . N/A SF N/A 3.83 8/13/2008 1Y 30 188-090 SF N/A SF N/A 3.83 8/13/2008 1 E-112 204-091 14" N/A 14" N/A 5.95 8/17/2008 1 E-119 204031 14" N/A 14" N/A 4 67 8/17/2008 1 E-121 204-246 6" " . N/A 6 N/A 1.00 8/17!2008 1 E-123 204-074 5" N/A 5" N/A 1.00 8/17/2008 ~,~ • • KRU_1E-121_convert_to_gaslift_2008-0822.txt west Sak 1E-121 (PTD# 204-246) Convert To Gas LiftFrom: NSK Problem well Supv [n1617@conocophillips.com] Sent: Friday, August 22, 2008 4:32 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; NSK West Sak Prod Engr; CPFl DS dead Techs; Jenkins, ~ubbie Allen Subject: west Sak 1E-121 (PTD# 204-246) Convert To Gas gift Attachments: 1E-121 wellbore Schematic.pdf; 1E-121 TIO Plot.ppt Tom/Jim, west sak ESP producer 1E-121 (PTD# 204-246) was shut down on August 10, 2008 due to -~ excessive motor temperature. CPAI has elected to not run the motor to failure, as this will prevent the downhole gauges from transmitting data to the surface. It is our intent to convert this well to aslift and ince it is not permitted with gaslift as a bac up, we wi su mit a 10-43 requesting permission to do so. Attached is the most recent wellbore schematic and a 90 day TIO plot. ,~- « 1E-121 wellbore Schematic.pdf» «1E-121 TIO Plot.ppt» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem wells Supervisor ConocoPhillips Alaska Inc. office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 Page 1 • • i d- N ~J -~ ~ _~.L dwalfa~oy~ 00 ~°n °o ,°,s.~ o N r r _..~ . - - i' ~' : ~" :', ., ., ~ o : : : : : ~ .~ : r r N : : : : : :~ :~ : r ` W :~ r a: O ~ ~ ~ ~ D d ~ oo o D ~ ,.` -, I- o ~ ~ I ` :'~ :' i ." "~ ao o ~ Q , o ~ I ~ ~ r O w Y : ~: ~: o`er Q © °o o °0 0 0 °o 0 00 f~- Cfl 1S7 ~ M N r ISd `. ;, ~ ~ ~onocoPhilli~as A4aska, inc.. ~j E-121 API: 500292323800 Well T e• PROD An le TS~ de SSSV Type: NONE Orig 2/6/2005 Angle @ TD: 86 deg @ 12415 suRPACE (o-2ss2, Com letion: oD:1o.7so, Annular Fluid: Last W/O: Rev Reason: FORMAT UPDATE wt:as.so) Reference Lo 28' RKB Ref Lo Date: Last U date: 12!27/2007 ~~ Last Ta TD: 12415 ftK6 TUBING "-, Last Ta Date: Max Hole Angle_ 93 deg aQ 11629 (0~247~ . . - _ , _. __ Casing Stringy COMMON STRINGS ID:3.958) r- ~ Descri lion Size To ~ Bottom TVff~ Wt Grade Thread CONDUCTOR 20.000 0 108 108 62.50 H-40 WELDED _" -' _ SURFACE 10.750 0 2662 2394 45.50 L-80 BTC "'` INTERMEDIATE 7.625 0 5267 3694 29.70 L-RO BTCM _ ___ _ _ - I ~ - - assn trln LINER B- ~ SAND _ Description I Size Top ] B ttum TVD Nr de ~ Thread cra , ~ TERMEDiATE (0.5267, ,I r = _ , OTTED LINER_ 4.500 _ 4905 1238( 3741 ~ ~ L?.'. _ fBT i, L OD:7.625, ~ s- ~ -T TUbI~ String TUB Wt29.70) i _ ~ ~ r-J I - - ~ hread Top Bottom TVD ~Wt Csra~ie 4.500 ~ 0 i 4247 ~ 3408 i 12.60 c L-tsu i IB i Perforations Summer _ _ Discnarge - _ ___ Interval TVD ~ Zone Status Ft SPF Date T e Comment Press. Sub (a171-anz, 5272 - 5669 3695 - 3717 WS B 397 32 1/26/2005 IPERF FOR ALL PERFS: Slotted OD:5.875) ~ liner alternating wlblank PUMP 1 r - pipe, w/constrictor packers ASSEMBLY @ 5671', 5886', 6494', (4224-4271, oD:3.7so) 6744', 12023', 12248' 5886 - 6496 3727 - 3742 WS B 610 32 1126/2005 IPERF 6745 - 12003 3749 - 3732 WS B 5258 32 1/26/2005 IPERF seAL - i 12258 - 12350 3733 - 3738 _ WS B _92.32 1/2.6/2005 IPERF _ _ _ __ - (az57~271, .Gas Lift Mandrels/Va Ives ODt5.130) r - _ __ _ __ _ St MD TVD `Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv MOTOR -~- ~~ Cmnt (4271-4305, OD:5.620) 1 2675 2404 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 2/6/2005 2 3594 3113 CAMCO KBG-2 SOV 1.0 BK-5 0.000 0 11/5/2006 1 1. 2000# ruerrv~ ~~'~'~~ Other lu s e ui ., etc.~COMMON JEWELRY _ De th TVD T e Descri lion ID 33 33 HANGER VETCO GRAY HANGER w/MCA TOP CONNECTION 4.500 GAUGE ~ -a 4171 3375 Discharge A-WELL DISCHARGE PRESSURE SUB 3.958 (4305-4307, Press. SUb oD:a.soo) 4224 3398 PUMP SET 44' 2" ESP PUMP @ 4271' RKB. SET 3/14/2005 SET 4 1/2 0.000 - - ~ ~ ASSEMBLY PACKOFF ASSEMBLY @ 4224' RKB / 4191' SLM (109" OAL-36 1/2" i ~'-_---- FROM F.N. TO KOBE KNOCK OUT-431/2" FROM F.N. TO FLAPPER ). SET 4 1/2 SLIP STOP ONTOP OF PACKOFF ASSEMBLY @ 4183' SLM ~ Set 11/5/2006 HANGER to u \ ~ 4247 3408 SCREEN CENTRILIFT TTC i INTAKE SCREEN TTC CROSS OVER 4.630 (aa12-as2a, \ 4257 3412 SEAL CENTRILIFT TANDEM SEAL SECTION GSB33 DB AB / HSN PFSA 4.630 oD:7s2s) 4271 3418 MOTOR CENTRILIFT MOTOR KMH ! 418 HP! 2610 V / 98 A 0.000 j ~; \ 4305 3433 GAUGE CENTRILIFT A-1 PUMP GAUGE 0-5000 PSI w/DISCH PRESS 0.000 ~, ` ! 4307 3433 Centralizer CENTRILIFT MOTOR CENTRALIZER 0.000 4812 3600 HANGER D-SAND BAKER MODEL B2 FLANGE HOOK HANGER 4.500 to L1 - - PACKER - -~~ - - Other lugs equip. etc.) - B-SAND JEWELRY (aso5-asos, oD:zsoo> _ ` . - , , _ De th TVD T e Descri lion ID tt = 4816 3601 WINDOW B-SAND WINDOW 6.875 Perf ---- 4905 3626 PACKER B-SAND ZXP LINER TOP PACKER .5.500 (5272-5669) ~ ___-- 12354 3738 PACKOFF B-SAND 4.5"BAKER DRILLABLE-PACKOFF _ __. 3.950 _ I ,General Notes _ _ - - _ __ Date Note ~ 2/5/2005 NOTE: MULTI-LATERAL WELL - 1E-121 B-SAND , 1E-121 L1 D-SAND Perf ... ~ `....._-___. - (5886-6496) I ~ ~ - Perf _ ;12258-12350) I -' ' I ~I KRU 1 E-121 aii~;.._. ~_. _~ • MICRUFILMED 03/01/2Q~8 DU NUT PLACE AIVY NEW MATERIAL UNDER THIS PAGE F:1LaserFicl~iCvrPgs_Inserts~Articmfilm Macker.doc ~~ DATA SUBMITTAL COMPLIANCE REPORT 3/12/2007 Permit to Drill 2042460 Well Name/No. KUPARUK RIV U WSAK 1E-121 Operator CONOCOPHILLlPS ALASKA INC -----_._~._.~. MD 12415 -' TVD 3742 /' Completion Date 2/6/2005 ,/ --..------------- Completion Status 1-01L Current Status 1-01L - -------------- ----------_.._------.-.--------. REQUIRED INFORMATION -----~-_.. ------...---.--------------- Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Electr Digital Dataset Med/Frmt Number D Asc Log/ Data Zl~e ~D D Asc LÆb D Lis )Pt ~-~¡; Lis Name Directional Survey Directional Survey 13082 Induction/Resistivity 13082 Induction/Resistivity 13703 Induction/Resistivity 14458 Induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORM~ON Well Cored? Y /(W Chips Received? ~ Analysis ~ Received? Comments: --------------------~-~-----~~---~--------~.-_.. Samples No 5pq,¿ O.Jv- .{O~)- API No. 50-029-23238-00-00 UIC N H _ _____,,______ ~ -- ----- - Directional Survey Yes " __ _________.___________________ __ _______n____ (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH/ Scale Media No Start Stop CH Open 0 12415 Open 2636 12357 Open Received 5/4/2005 5/4/2005 3/16/2005 2636 12357 Open 3/16/2005 108 12415 Open 2/22/2006 2620 12415 Open 1/29/2007 Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? (1)N 0N Formation Tops ~---_..._~----~ - Comments IIFR MWD GR/EWR4/ AS I/RO P / ACALI PWD/GEOPILOT/MWD G R/EWR4/ AS I/ROP / ACALI PWD/GEOPILOT/MWD DGR EWR LIS Veri, FET, GR, ROP w/Graphics - DATA SUBMITTAL COMPLIANCE REPORT 3/12/2007 Permit to Drill 2042460 . , Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23238-00-00 Well Name/No. KUPARUK RIV U WSAK 1E-121 MD 12415 TVD 37~~_..__n ¡4omPletion Date 2/6/2005 Compliance Reviewed By: sj:::)-V____ Completion Status 1-01L Current :t::~~ 1-0~ ILpl~l~ - e . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14,2006 RE: MWD Formation Evaluation Logs: lE-102 LI Ll PBl PBl PB2, lE-104, lE-12l Ll. - - - - - The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 U'I~ d04 -dol I Û ~c.. ';Jó4-d3& lE-102_Ll_Ll PBl_PBl PB2: 1!...140ó Llt.../&( Digital Log Images: 1 CD Rom 50-029-23236-00, 60, 72, 70, 71 lE-104: UIc..eol.../-8d1- ¡,¡, l'-IL/5"'"? Digital Log Images: 1 CD Rom 50-029-23234-00 I~-/).I 1/5-0.1 hi lE-121_Ll: 2JO~/-d(/fo t£ 14LIS-Y ()O<.{ -d'-l9 * IL(4~ Digital Log Images: I 1 CD Rom 50-029-23238-00, 60 þ e - WELL LOG TRANSMITTAL ¿) (Y1, "- /)4-&) To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 !}04-841 RE: MWD Formation Evaluation Logs lE-121 + Ll, 18'1°3 1370/4- The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 lE-12l +Ll: LAS Data & Digital Log Images: 50-029-23238-00, 60 1 CD Rom ŒJíôQ1QQ it) {) \ 0 ø \ O~¡? · WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs lE-121, 1 LDWG formatted Disc with verification listing. API#: 50-029-23238-00 -- ¿)ot(- Zt/Cø #))63~ March 1, 2005 AK-MW-3458622 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COI>Y OF THE TRANSMITTAL LETTER TO THE A'ITENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed: . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 1 E-121 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 12,415.00' MD (if applicable) 28-Apr-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 tvvi ðMJ Date ç /"t-) M~ ç Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 'Ao ""'1- }.-'t 0 . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well 1 E-121 (mwd) Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 12,415.00' MD (if applicable) 28-Apr-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ç Mo.) t.ö ~ \" Signed 1k.r1 0 lJv¡ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) À~4 -)~~10 . Conoc6Phillips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 March 30, 2005 RECEIVED MAR 3 1 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage Subject: Well Completion Reports for 1E-121 and 1E-121L1 (APD#204-246/204- 247) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1E-121 and 1E-121L 1. If you have any questions regarding this matter, please contact me at 265-6830 or Steve Shultz at 263-4620. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ¡\fA L i 'J · STATE OF ALASKA. R· EC"ì).Eii'IVER\ AL~ OIL AND GAS CONSERVATION COM 'SION .... . IJ WELL COMPLETION OR RECOMPLETION REPORT AN~~ 2009 Oil 2] Gas U Plugged 0 Abandoned 0 Suspended 0 WAG 0 20AAC 25.105 20AAC 25.110 No. of Completions _ Other 1a. Well Status: GINJ 0 WINJ 0 WDSPL 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 973' FSL, 630' FEL, Sec. 16, T11N, R10E, UM At Top Productive Horizon: Total Depth: 2245' FNL, 1552' FWL, Sec. 15, T11N, R10E, UM 711' FNL, 1572' FEL, Sec. 10, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549890 ~ y- TPI: x- 552053 y- Total Depth: x- 554149 / y- 18. Directional Survey: Yes 2] No 0 21. Logs Run: GRlRes 22. CASING SIZE WT. PER FT. 62.5# 45.5# 29.7# 12.6# GRADE H-40 L-80 L-80 L-80 20" 10.75" 7.625" 4.5" 5960560 ~ 5962637 5969465 I Zone- 4 Zone- 4 Zone-4 5. Date Comp.. Susp., or Aband.: February 6, 2005 6. Date Spudded: January 12, 2005 7. Date TD Reached: January 24, 2005 ./ 8. KB Elevation (ft): 28' RKB 1 93' AMSL 9. Plug Back Depth (MD + TVD): 12386' MD 13740' TVD 10. Total Depth (MD + TVD): , 12415' MD /3742' TVD ' 11. Depth where SSSV set: none 19. Water Depth, if Offshore: NIA feet MSL CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 2662' 28' 2394' 28' 5267' 28' 3694' 4905' 12388' 3626' 3740' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number: if none, state "none"): slots in liner from 5272'-5669', 5886'-6496', 6745'-12003', 12258'-12350' 26. Date First Production March 17,2005 Date of Test Hours Tested 3/25/2005 12 hours Flow Tubing Casing Pressure press. 347 psi not available 27. TUBING RECORD DEPTH SET (MD) I PACKER SET 4309' 4905' swell packers @ 5671',5886',6494',6744',12023',12248' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 24. SIZE 4.5" 25. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Production for Test Period --> Calculated 24-Hour Rate -> 1 b. Well Class: DevelA: IH/r.t¡¡' illII ¿š¡ 6113 ~t&ømrriiü'on Service 0 Anc~hiC Test 0 12. Permit to Drill Number: ./ / 204-246 13. API Number: 50-029-23238-00 14. Well Name and Number: 1 E-121 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ALK 25651 & 25648 17. Land Use Permit: ADL 469 & 466 20. Thickness of Permafrost: 3353' MD HOLE SIZE AMOUNT CEMENTING RECORD PULLED 40" 385 sx AS I 490 sx AS Lite, 196 sx DeepCrete 293 sx DeepCrete slotted liner 13.5" 9.875" 6.75" OIL-BBL GAS-MCF 1709 878 OIL-BBL GAS-MCF 3304 1886 CORE DATA production shared with 1 E-121 L 1 WATER-BBL CHOKE SIZE 22 176 WATER-BBL OIL GRAVITY - API (corr) IGAS-OIL RATIO 571 45 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". Form 10-407 Revised 12/2003 NONE RBDMS BFL APR 0 4 2005 I '-- CONTINUED ON REVERSE not available ~-èô\~~Þ;~Ê~ft6~ir·'1 t DP.;Œ.ocr- r~Q~ ....,-- l'r ~ 28. GEOLOGIC MARKERS. 29. . FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 E-121 West Sak B West Sak B West Sak B 5180' 5874' 12225' 3680' 3725' 3732' 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 Shultz @ 263-4620 Printed Nam~ ~ Ran.d'!, Thomas Title: Signature \ ~ ~hone Kuparuk Drillina Team Leader '(.. 6~ b-B:3 ò ~ (~ö /0 ç Date Prepared by Sharon AlIsu~Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/612005 Group: 1/8/2005 00:00 - 01 :00 1.00 MOVE I RURD MOVE 01 :00 - 02:30 1.50 MOVE MOVE MOVE , i 02:30 - 05:30 3.00 MOVE MOVE MOVE 105:30 - 08:30 3.00 WAlTON EQIP MOVE ! 08:30 - 12:00 3.50 MOVE MOVE MOVE 12:00 - 15:00 3.00 MOVE MOVE MOVE 15:00 - 18:00 3.00 WELCTL NUND MOVE 18:00 - 00:00 6.00 DRILL OTHR MOVE 1/9/2005 00:00 - 12:00 12.00 WAlTON WOW RIGUP 12:00 - 00:00 12.00 WAlTON WOW RIGUP 1/10/2005 00:00 - 12:00 12.00 WAlTON WOW RIGUP 12:00 - 20:00 8.00 WAlTON WOW RIGUP 20:00 - 21 :30 1.50 DRILL OTHR RIGUP 21 :30 - 23:00 23:00 - 00:00 1.50 DRILL i PULD RIGUP 1.00 WAITONlwow RIGUP I 8.00 WAITONlwow RIGUP I , I I I 1/11/2005 00:00 - 08:00 Disconnect Electrical Service lines and interconnects for modules. Move and stage pipe shed and other rig modules to other side of pad. Working on cleaning rig diesel tank. Used 4000 gal of fuel wI the 1430 gal that was in tank to try and eliminate contamination in tank. Sent 5430 gal (129 bbls) to hydrocarbon recycle. RU tow bar on rig sub. Move sub off well 1 E-1 02 @ 0330 hrs. Manuever rig down the pad, around the corner. Moved approx 1/4 mile (1/2 of move distance). Slick pad, temperature +30 deg. One cat did not have enough traction to pull rig in turn at end of pad. Wait on another cat to come fl Prudhoe f/ Peak Oilfield Services to help move the rig to 1 E-121. Slick pad. RU 2nd cat to rig sub. Move rig to 1E-121. Spot sub over well1E-121@ 1100 hrs. Move and spot pit module. Spot pump module, motor module, boiler module and pipe shed. Spot Rockwasher. While spotting pipe shed, the pipe shed hit a electrician box van which was not seen, during Phase 3. Phase 3 weather came up quick @ about 1330 hrs. RU pipe skate, NU riser. Rig acceptance @ 1600 hrs 1/8/2005 on 1E-121. Phase 3 weather. Phase 3 Weather: Change out saver sub on top drive fl 4" XT 39 to 4 1/2" IF. Adjust grabbers, serviced top drive. change floor tools to 5" Shut down rig operations due to Phase 3 weather conditions. Test Hi and Low alarms fl LEL and H2s. Rebuild accumulator and recharge to 800 psi on top drive. Change out bolts on saver sub wear plate. Prep dog collar. Inspect drag chain in pits and rock washer. Service mud pump oil cleanouts. Check fluid level in agitators in pits room. Table top drill: Diverting shallow gas. Table top drill: H2S. Shut down rig operations due to Phase 3 weather conditions. Service top drive counter balance accumulator. Inspected drawworks chain. Serviced and greased drawworks. Install exhaust fan in mud pits. Inspect brake linkages. Soft line riser in # 5 pit. Table top drill: Diverting shallow gas. Shut down rig operations due to Phase 3 weather conditions. Inspect expansion joints on centrifical pumps. Clean snow fl heater ducts in pipe shed. Service loader in shop. Installed washdown pump in rock washer. Repaired # 2 pump pressure digital guage. Peak cat skinner slipped and hurt right leg, leaving shop after pre job safety meeting @ 0930 hrs. Finish plumbing wash down pump in rock washer. Install 3" valves on speed head for draining after cement job. Removed snow by pipe shed and spotted Tioga. Roads and pads equipment came out and cleaned enough snow to get around pad. Weather phase changed from phase 3 to phase 2 at 2115 hrs. Put BHA in pipe shed. Put 57 joints 5" dp, 29 joints 5" HWDP, and jars. Strap, & Caliper tools. PU ghost reamer, stabilizer and crossovers to rig floor. Shut down rig operations due to Phase 3 weather on pad. Fuel and water has been ordered to arrive. Phase 2/3 weather conditions. Rec'd one load of water fl pits @ 0030 hrs, rec'd load of fuel @ 0100 hrs, rec'd load of water fl pits @ 0300 hrs, rec'd load of water fl pits @ 0515 hrs, rec'd load of water f/ pits @ 0800 hrs, mix spud mud. Printed: 2/18/2005 10: 11: 19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRilLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 1/8/2005 2/6/2005 Spud Date: 1/12/2005 End: 2/612005 Group: 1/11/2005 08:00 - 10:00 2.00 WAlTON WOW RIGUP Phase 2/3 weather conditions. PJSM. PUlMU 5" drillpipe (rabbit). PU 57 jts, rack back in derrick. 10:00 - 11 :00 1.00 WAlTON WOW RIGUP Phase 2/3 weather conditions. Level rig. 11:00 -12:00 1.00 WAlTON WOW RIGUP Phase 2/3 weather conditions. Transfer 19 stands 5" dp to driller's dide of derrick. (Because of weather conditions, not able to get around in field, making plans to PU 4" and rack in derrick f/later in well). 12:00 - 12:30 0.50 WAlTON SFTY RIGUP Phase 2/3 weather conditions. PJSM on picking up dp. 12:30 - 14:00 1.50 WAlTON WOW RIGUP Phase 2/3 weather conditions. PUlMU rabbit 5" HWDP. Rack 10 stands (includes jars) on driller's side. 14:00 - 16:30 2.50 WAlTON WOW RIGUP Phase 2/3 weather conditions. Load 4" dp in pipe shed. 16:30 - 22:00 5.50 WAlTON WOW RIGUP Phase 2/3 weather conditions. PU/MU 30 stands Weatherford 4", S-135, XT-39 dp w/ Lo-Tads installed after the double (on top of bottom single). Stand back in derrick for use later in well. Rabbit pipe to 2". 22:00 - 00:00 2.00 WAlTON WOW RIGUP Phase 2/3 weather conditions. PU/MU 20 stands Weatherford 4", S-135, XT-39 dp. Stand back in derrick for use later in well. Rabit pipe to 2". 1/12/2005 00:00 - 02:00 2.00 WAlTON WOW RIGUP Phase 2/3 weather conditions. PU/MU 20 stands Weatherford 4", S-135, XT-39 dp. Stand back in derrick for use later in well. Rabit pipe to 2". 02:00 - 02:30 0.50 WAlTON WOW RIGUP Phase 2/3 weather conditions. Perform diverter function test w/ 5" dp. Witness of test waived by AOGCC inspector John Spaulding. 02:30 - 03:45 1.25 DRILL OTHR SURFAC PU/MU BHA # 1. 03:45 - 04: 15 0.50 DRILL OTHR SURFAC Orient MWD and Motor. Orient UBHO sub. 04:15 - 05:00 0.75 DRILL SFTY SURFAC PJSM w/ Halliburton wireline and rig crew. RU slickline. 05:00 - 05:30 0.50 DRILL CIRC SURFAC Fill conductor. Check for leaks. Test pit HI/Low level alarms @ driller's console. Test mud line to 1000 psi to check f/leaks after rig move. 05:30 - 08:00 2.50 DRILL DRLG SURFAC Spud well and drill 13 1/2" hole from 108' to 151', ART 1.6 Hrs. Increased vis of spud mud too quick w/ extender. Water mud back. Drill w/5-7K WOB, 85 spm, 360 gpm, 50 rpm 08:00 - 09:30 1.50 DRILL OTHR SURFAC PU to 70'. Flow line plugged off w/ gravel. Clean gravel and sticks out flow line. 09:30 - 10:15 0.75 DRILL DRLG SURFAC Drilled 13 1/2" hole from 151' to 195', ART .74 hrs. Drill w/ up to 10K WOB, 85-94 spm, 360 gpm-397gpm, up to 700 psi 10:15-11:00 0.75 DRILL SURV SURFAC Ran Sperry Sun gyro w/ Sperry Sun slick line unit at 195' (bit depth). Ran twice, failed 11 :00 - 12:00 1.00 DRILL TRIP SURFAC POOH f/195' to 70'. PU/MU 3 flex 7 3/4" NMDC's. 12:00 - 12:30 0.50 DRILL TRIP SURFAC RIH f/160' to 195', 3' fill. 12:30 - 13:00 0.50 DRILL SURV SURFAC Ran Sperry Sun gyro w/ Sperry Sun slick line unit at 195' (bit depth) 13:00 - 13:30 0.50 DRILL DRLG SURFAC Drilled 13 1/2" hole from 195' to 252', ART .5 hrs 13:30 - 14:15 0.75 DRILL SURV SURFAC Ran Sperry Sun gyro w/ Sperry Sun slick line unit at 251' (bit depth) 14:15 - 15:30 1.25 DRILL DRLG SURFAC Drilled 13 1/2" hole from 252' to 344', ART 1.45 hrs 15:30 - 16:00 0.50 DRILL SURV SURFAC Ran Sperry Sun gyro w/ Sperry Sun slick line unit at 343' (bit depth) 16:00 - 17:30 1.50 DRILL DRLG SURFAC Drilled 13 1/2" hole from 344' to 436', ART 1.45 hrs 17:30 - 18:00 0.50 DRILL SURV SURFAC Ran Sperry Sun gyro w/ Sperry Sun slick line unit at 435' (bit depth) 18:00 - 00:00 6.00 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 436' to 830' MD/ 827' TVD, ART 3.08 hrs, AST 1.6 hrs, 7-12K wob, 50 rpm's, 106 spm, 448 gpm, off btm pressure 900 psi, on btm pressure 1,000 psi, off btm torque 1 K ft-Ibs, on btm 2K ft-Ibs, PU wt 75K, SO wt 84K, Rot wt 79K 1/13/2005 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 830' to 1921' MD/1798' TVD, ART 6.4.35hrs, AST 4.24 hrs, 7-25K wob, 50-55 rpm's, 106-145 spm, 448-613 gpm, off btm pressure 900-2000 psi, on btm pressure 1,000-2200 psi, off btm torque 1-4K ft-Ibs, on btm 2-10K ft-Ibs, PU wt 75-96K, SO wt 84-96K, Rot wt 96K. MW 9.3 ppg, max gas 61 units Printed: 2/18/2005 10: 11: 19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 1/8/2005 2/6/2005 Spud Date: 1/12/2005 End: 2/612005 Group: 1/13/2005 12:00 - 18:00 6.00 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 1921' to 2669' MDI 2399' TVD, ART 3.46hrs, AST .22 hrs, 5-30K wob, 55 rpm's, 145-154 spm, 613-651 gpm, off btm pressure 2000-2300 psi, on btm pressure 2200-2500 psi, off btm torque 3-6K ft-Ibs, on btm 2-6K ft-Ibs, PU wt 96-125K, SO wt 96-98K, Rot wt 96-105K. MW 9.3 ppg, max gas 139 units. Pumped weighted (2ppg over) sweep on stand 17. 18:00 - 18:45 0.75 DRILL ICIRC SURFAC Finish circ 2ppg over (11.3 ppg) weighted sweep out of hole. 20% I increase in cuttings estimated @ shakers. Monitor well. 18:45 - 21 :45 3.00 DRILL I REAM SURFAC Backreamf/2269' to 1089' wI 55-60 rpm, 650-700 gpm, 2500 psi. 21 :45 - 22:30 0.75 DRILL PULD SURFAC UD 13 1/2" ghost reamer and (12) 5" HWDP. 22:30 - 23:00 0.50 DRILL TRIP SURFAC POOH (6) stands(includes jars)-- 5" HWDP 23:00 - 00:00 1.00 DRILL PULD SURFAC UD Sperry BHA, download MWD. 1/14/2005 00:00 - 00:30 0.50 DRILL PULD SURFAC Finish UD, Break bit, drain motor. 00:30 - 01 :00 0.50 DRILL OTHR SURFAC Clean rig floor. 01 :00 - 02:00 1.00 CASE RURD SURFAC Rig up to run 103/4" casing. 02:00 - 02:30 0.50 CASE SFTY SURFAC PJSM on running 10 3/4" surface casing. 02:30 - 05:00 2.50 CASE RUNC SURFAC Run 10 3/4" casing. Weatherford Model 303 float shoe, 2 joints 45.5ppf L-80, BTC,Weatherford model 402 FC, (1) joint 45.5ppf L-80 BTC casing, first three joints baker locked, pump thru and check float equipment, continue running 103/4" 45.5 ppf L-80 BTC casing to 1240'. 05:00 - 05:30 0.50 CASE CIRC SURFAC Break circ w/ Frank's fillup tool @ 3.5 bpm wI 200 psi. Circ total of 110 bbls. 05:30 - 06:45 1.25 CASE RUNe SURFAC Continue running 103/4" 45.5ppf L-80 BTC casing to 2138'. 06:45 - 07:00 0.25 CASE CIRC SURFAC Break circ wI Frank's fillup tool @ 3.0 bpm wI 400 psi. Circ total of 60 bbls. PU wt 115k, SO wt 95K 07:00 - 07:45 0.75 CASE RUNC SURFAC Continue running 103/4" 45.5ppf L-80 BTC casing to 2629'. 07:45 - 08:00 0.25 CASE OTHR SURFAC PU/MU Vetco/Gray hanger and landing joint. Run in hole to land @ 2661.85'. Ran total of 64 joints. 45.5 ppf L-80 BTC. Ran total of 15 centalizers and 2 stop rings. PU wt 155k, SO wt 105k. 08:00 - 09:45 1.75 CEMENT CIRC SURFAC CBU wI Frank's fillup tool, stage rate up f/1.5bpm wI 300 psi to 4 bpm w/ 300psi, then 5bpm @ 350 psi. stage to 7 bpm wI 350 psi. Circ 418 bbls. PU wt 142k, SO wt 102K. Recip 9' stroke. 09:45 - 10:15 0.50 CEMENT: RURD SURFAC UD Franks fillup tool. Blow down top drive. MU Dowell cement head. 10:15 -11 :30 1.25 CEMENl1 CIRC SURFAC Continue to circ and condition mud fl cement job. Circ @ 7 bpm w/400 I psi. PU wt 142k, SO wt 102K, Block 35K. Recip 9'. I 11:30-11:45 0.25 CEMENì CIRC SURFAC Hold PJSM w/ Dowell, rig crew and vac truck drivers on cement job while continue to circ and condition mud f/ cement job. Circ @ 7 bpm w/ I 400 psi. PU wt 142k, SO wt 102K, Block 35K. Recip 9'. Circ total of I I 525 bbls after Dowell cement head was applied. Total volume circ to I I I condition mud with pipe on bottom prior to cement job 943 bbls (3.25 hrs). Mud prior to conditioning was 9.3 ppg, 270 vis, 36 PV and 60 YP. ! ¡After conditioning mud 9.1 ppg, 51 vis, 20 PV, and 16 YP. 11 :45 - 13:45 2.00 CEMEN~ PUMP SURFAC Dowell pump 3 bbls water, test lines to 4000 psi., follow wI 50.1 bbls i CW 100 (8.3 ppg) @ 5 bpm 250 psi, follow w/ 45.8 bbls MudPush II w/ I red dye (10.3 ppg) @ 4 bpm 225 psi, Drop bottom plug. Dowell pump I I 389.1 bbls AS Lite (10.7 ppg) @ 5.6 bpm 250-370 psi, follow w/ 86.9 I bbls DeepCrete tail cement (12 ppg) @ 5.6 bpm 350-600 psi, Drop top I plug. 13:45 - 14:00 0.25 CEMENl! DISP SURFAC Dowell displace wI 20 bbls fresh water @ 5 bpm 150 psi then turn over i to rig. 14:00 - 14:45 0.75 CEMENTDISP SURFAC Rig displace cement w/9.1 ppg mud @ 6.8 bpm(initial press 320 psi, final press 615 psi) till 3 bbls prior to bump plug, then slow to 3 bpm 510 psi. Bump plug @ calculated displacement (2267 strokes), Printed: 2/18/2005 10: 11: 19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/612005 Group: 0.75 CEMENT DISP SURFAC increased pressure to 1010 psi. CIP @ 1445 hrs 1/14/2005. Had full returns on cement job. Had 102.7 bbls good 10.7 ppg cement returns to surface. 0.50 CASE DEQT SURFAC Test casing. Pressure test 10 3/4" casing to 3000 psi wI 9.1 ppg mud. Hold test fl 30 min. , chart test. Bleed off, check floats, OK. Note: reciprocated casing until 87 bbls prior to bump plug, then landed on hanger w/ 65k SO wt. Blocks were 35k of this wt. UD Dowell cement head. Break Dowell crossover fllanding joint. UD 10 3/4" landing joint. RID casing equipment. PJSM on N/D diverter and NU Vetco/Gray wellhead. NID Diverter System. Flush annular. NU VetcolGray 5k MultiBowl spool. Orient and test to 5000 psi f/1 0 min. OK. Nipple up 13 5/8" BOPE, connect choke and kill lines, install double valves on wellhead annulus. Change Top drive saver sub f/4 1/2" IF to 4" XT 39. Note: Rig Floor to Upper LDS 22.71'(Tubing Hanger) Rig floor to Lower LDS 26.55'(7 5/8" packoff) Rig floor to tubing hanger load shoulder 24.39' Rig floor to 7 5/8" hanger load shoulder 27.33' 1.00 WELCTL NUND SURFAC Install riser and RU to test BOPE. 4.50 WELCTL BOPE SURFAC Witness of BOPE test waived by AOGCC inspector Chuck Scheve. Test annular, upper 31/2" x 6" pipe rams wI both 4" and 5" test joint, test lower pipe rams w/7 5/8" test joint, test blinds. Test 4" floor safety valve and IBOP, test 5" floor safety valve and IBOP. Test top drive IBOP and all kill and choke line valves and choke manifold. All tests to 250 psi low and 3500 psi high. Test accumulator. UD test plugltest joint. Run Vetco Gray wear bushing. Install drilling bales and elevators to top drive. PU 9 7/8" bit, bit breaker, ghost reamer and float sub to rig floor. PUlMU BHA #2. MU Sperry Sun Geo Pilot, 9 7/8" Security/DBS bit, nmflex pony collar, stab, PWD, stab, HCIM, ACAL, TM HOC, float sub Upload MWD/LWD tools Press test Geo Span. Blow down top drive and geo span. Make up remaining BHA. Trip in hole to 2503'. Break in bearings on Geo Pilot MU top drive to 4" DP. Circ down and tag @ 2571', drlill cmt and plugs on top of FC @ 2576', Drill plugs, FC, cement, FS @ 2661.85', and 20' new hole to 2689'. PU wt 11 Ok, SO wt 85K, rot wt 95k. Drill wI 490-600 gpm, 1200-1700 psi, 85 rpm, torq 7k 0.75 DRILL CIRC SURFAC Circulate bottoms up (196 bbls) to change out mud in hole. Circ total of 230 bbls, 9.00 ppg mw. 1.25 DRILL LOT SURFAC Stand back 1 stand. Blow down top drive. RU to perform LOT using 9.0 ppg mw and apply pressure to 848 psi. Leak off @ 510 psi wlshoe @ 2662' MD/2394' TVD. Leak off 13.1 EMW. Bleed off pressure, RID test equipment 7.25 DRILL DRLG INTRM1 RIH 1 stand, Drilled 9 7/8" hole per directional plan from 2689' to 3436' MD/3006' TVD, ART 4.5hrs, 2-35K wob, 60-130 rpm's, 117-108 spm, 494-456 gpm, offbtm pressure 100-1150 psi, on btm pressure 100-1200 psi, off btm torque 4-12K ft-Ibs, on btm 5K ft-Ibs, PU wt 116-124K, SO wt 85-90K, Rot wt 98-104K, avg background gas 40 units Note: Had 2443 units gas while drilling @ 2700'. Note: Start playing wI parameters of geo pilot @ 3375' to try & get it working. I I i 1/14/2005 14:00 - 14:45 14:45 - 15:15 15:15-18:00 2.75 CASE RURD SURFAC 18:00 - 20:30 2.50 WELCTL NUND SURFAC 20:30 - 21 :30 1.00 WELCTL NUND SURFAC 21 :30 - 00:00 2.50 WELCTL NUND SURFAC 1/15/2005 00:00 - 01 :00 01 :00 - 05:30 05:30 - 06:00 0.50 WELCTY OTHR SURFAC 06:00 - 07:00 1.00 DRILL IPULD SURFAC I 07:00 - 08:00 1.00 DRILL IpULD SURFAC I 08:00 - 09:00 1.00 DRILL OTHR SURFAC 09:00 - 09:30 0.50 DRILL OTHR SURFAC 09:30 - 10:00 0.50 DRILL PULD SURFAC 10:00-11:15 1.25 DRILL TRIP SURFAC 11:15 -14:45 3.50 DRILL DRLG SURFAC 14:45 - 15:30 15:30 - 16:45 16:45 - 00:00 Printed: 2/1812005 10: 11: 19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1 E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/612005 Group: 1/16/2005 00:00 - 00:15 0.25 DRILL DRLG INTRM1 RIH 1 stand, Drilled 9 7/8" hole per directional plan from 3436' to 3460' MD/3025' TVD, ART .25hrs, 4K wob, 60-100 rpm's, 106 spm, 450 gpm, off btm pressure 1000 psi, on btm pressure 1070 psi, off btm torque 4K ft-Ibs, on btm 5K ft-Ibs, PU wt 124K, SO wt 90K, Rot wt 104K Note: Geo Pilot not working well. Need to build 5 deg per 100', staying flat, not hooking up. 00: 15 - 00:45 0.50 DRILL CIRC INTRM1 Monitor well, pump dry job. Blow down top drive. 00:45 - 01 :30 0.75 DRILL TRIP INTRM1 Pull 2 stands, hole tight & light swabbing. 01 :30 - 02:45 1.25 DRILL REAM INTRM1 Pump and backream wI 450 gpm f/3253-2503'. Monitor well. 02:45 - 03:30 0.75 DRILL CIRC INTRM1 Circ finish BU, max gas 140 units. Pump dry job. Change elevators to 5". 03:30 - 05:00 1.50 DRILL TRIP INTRM1 POOH fl 2503' to Sperry Sun tools 05:00 - 05:30 0.50 DRILL OTHR INTRM1 Download Sperry Sun tools. 05:30 - 07:00 1.50 DRILL PULD INTRM1 UD BHA #2. Clean rollers on Geo Pilot break bit UD Geo Pilot. Hole fill 39 bbls 07:00 - 07:15 0.25 DRILL OTHR INTRM1 Clean floor. 07:15 - 08:00 0.75 DRILL PULD INTRM1 PU/MU BHA #3. Adjust motor to 1.5 deg, MU bit, PU LWD/MWD tools, ; orient. 08:00 - 08:45 i 0.75 DRILL OTHR INTRM1 Upload Spery Sun MWD/LWD tools. 08:45 - 11 :30 2.75 DRILL TRIP INTRM1 Finish MU BHA.MU 1 stand flex collars, RIH wI dp. Pulse test MWD @ 843'. Change out elevators f/5" to 4". RIH, fill pipe @ 2503, RIH to bottom. 11 :30 - 12:00 0.50 DRILL DRLG INTRM1 Drilled 97/8" hole per directional plan from 3460' to 3500' MD/3053' TVD, ART .39 hrs, 10-30K wob, 80 rpm's, 120 spm, 507 gpm, off btm I pressure 1550 psi, on btm pressure 1800 psi, off btm torque 5-9K ft-Ibs, I on btm 8K ft-Ibs, PU wt 125K, SO wt 90K, Rot wt 105K 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled 97/8" hole per directional plan from 3500' to 4609' MD/3547' TVD, ART 3.66hrs, AST 2.87 hrs, 5-40K wob, 80-95 rpm's, 120-137 spm, 507-579 gpm, off btm pressure 1550-2000 psi, on btm pressure 1800-2200 psi, off btm torque 5-9K ft-Ibs, on btm 6-1 OK ft-Ibs, PU wt 125K, SO wt 90-85K, Rot wt 105-100K, avg background gas 30 units, . max while drilling @ 3550' was 233 units. 1/17/2005 00:00 - 02:45 2.75 DRILL DRLG INTRM1 ¡Drilled 9 7/8" hole per directional plan from 4609' to 4941' MDI 3635' TVD, ART 2.16hrs, AST 0.0 hrs, 5-35K wob, 95 rpm's, 135 spm, 571 gpm, off btm pressure 2000 psi, on btm pressure 2150-2250 psi, off btm torque 5-9K ft-Ibs, on btm 8K ft-Ibs, PU wt 125K, SO wt 85K, Rot wt 100K, avg background gas 30 units, flow check @ 4870' gas 300 units, no flow, continue drilling @ 4931' gas increased f/300 units to 2200 units. No gain in pits. ECD's 10 ppg. 02:45 - 04:45 2.00 DRILL CIRC INTRM1 Circ out gas cut mud. MW in 9.2 ppg, lightest MW out 8.1 ppg. Circ BU, max gas 3466 units, once 9.2 ppg mud to surf, shut down f/10 min, monitor well, dead, CBU, Gas 150-250 units. ECD's 10 ppg. 04:45 - 08:30 3.75 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan and geologist from 4941' to 5270' MDI 3694' TVD, 81.24 deg., ART 1.69hrs, AST .76 hrs, 25-35K wob, 95 rpm's, 135 spm, 571 gpm, off btm pressure 1950-2000 psi, on btm pressure 2150-2250 psi, off btm torque 5-9K ft-Ibs, on btm 8K ft-Ibs, PU wt 122K, SO wt 83K, Rot wt 97K, avg background gas 30 units, ECD's 10 ppg. 08:30 - 09:45 1.25 DRILL CIRC INTRM1 Circ weighted hi-vis sweep(11 ppg), monitor well. Estimated 15% cuttings return increase. 09:45 - 12:15 2.50 DRILL REAM INTRM1 Backream out of hole f/5270' to 3545' wI 570 gpm, 200-1700 psi, rot rpm 95. 12:15 - 13:15 1.00 DRILL CIRC INTRM1 Circ weighted hi-vis sweep(11 ppg), wI 570 gpm, 1700 psi, 95 rpm. PU Printed: 2/18/2005 10: 11: 19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: Spud Date: 1/12/2005 End: 2/612005 Group: 1/8/2005 2/6/2005 wt 125k, so wt 92K, rot wt 105k. Estimated 25% cuttings return increase. Monitor well, pump out 3 stands 3545'-3266', POOH f/3266' to 2513' POOH UD 5" dp f/2513' to 750' UD Weatherford 97/8" ghost reamer, UD 14 joints 5" HWDP, UD jars, rack back 1 stand of 5" HWDP. UD BHA, download Sperry Sun MWD tools, break oft bit. Clear rig floor. I Pull Vetco Gray Wear bushing. I RU Doyon casing tools to run 75/8" casing. I PJSM on running 7 5/8" 29.7 ppf, L-80, BTC-M casing. PUlMU 7 5/8" 29.7ppf L-80 BTCM casing. MU weatherford shoe, 2 jts, FC, 1jt, circ thru float equip wI Frank's fillup tool. Circ 15 bbls. Held PJSM with rig crew on running 7 5/8" csg RIH with 7 5/8" 29.7#, L-80 BTCM casing. Ran jts #4-61 to 2650'. Installed centralizers as follows: One tandem 10' above shoe, bow on collar of joint #1 , two tandem on joint #2 10' fl each end, tandem on ceneter of joint #3, then every 30 to joint #10. No centralizer on joint #1 or the 20' pup above, continue wI centralizers every 30' , last centralizer 10' down fl box on joint #56. Bows run on box. Tandems run on stops. Total of 19 bows, 56 tandem, 56 stops. Circ casing @ 2650' (103/4" shoe @ 2,662') circ csg capacity 122 bbls. Circ 272 BBls, @ 6bpm wI 480 psi initial, 400 psi final. MW out 9.6ppg, circ till 9.3 ppg mw in and 9.3+ ppg mwout. PU wt 107K, ON wt 73K. Cont RIH with 7 5/8" 29.7#, L-80 BTCM casing f/2650' to 5,267' with no problems, ran a total of 120 jts, 7 5/8", 29.7#, L-80 BTC-M csg with 2- pup jts, total csg with float equip and hanger = 5,240' Circ and cond mud while circ btms up thru Franks fill up tool, staged pump rate up to 6.5 bpm at 500 psi, st wt up 178K, dn wt 92K LD Franks fill up tool, MU Vetco Gray hanger with Dowell cement head and landed csg in hanger with float shoe at 5,267' and float collar at 5,182' Fin circ and cond mud for cementing, conditioned mud from 9.3 ppg, 55 vis, 16 PV and 27 YP to 9.2 ppg, 45 vis, 14 PV, 13 YP, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ. 1.00 CEMENT PUMP INTRM1 Dowell pumped 5 bbls CW 100 at 8.3 ppg, Pressure tested lines to i 3,500 psi, Then pumped 35 add. bbls of CW 100, Pumped 40 bbls of I MudPush at 10.5 ppg, Dropped btm plug then pumped 119.98 bbls, (293 sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 5.2 bpm at 225 psi, Reciprocated pipe with full returns, shut down, Washed up and dropped btm plug. 0.75 CEMENT DISP INTRM1 Rig displaced cement with 9.1 ppg OBM, Bumped plug on calc displacement after pumping 238 bbls MOBM (96% pump eft.) ave 6.5 bpm while displacing cmt, Max pressure 700 psi, Slowed pump rate to 3 bpm with 3 bbls left to pump and bumped plug to 1,100 psi, ck floats and held CIP at 14:00 hrs, Reciprocated pipe until 93.0 bbls cmt was around shoe when hole began getting tight and stopped reciprocating, landed csg with Shoe @ 5267', Float Collar @ 5182', Calc TOC @ 2790', Had full returns thru out job. 0.25 CASE DEQT INTRM1 RU and attempted to test csg to 3,000 psi, after pumping 3.8 bbls and at 2,050 psi, pressure began to bleed down 1.00 CASE OTHR INTRM1 Closed annular and held 400 psi on csg while testing surface equipment for leaks and lines checked ok 1/17/2005 12:15 -13:15 1.00 DRILL CIRC IINTRM1 I 13:15 - 15:15 2.00 DRILL TRIP INTRM1 15:15 -17:00 1.75 DRILL TRIP INTRM1 17:00 - 18:00 1.00 DRILL TRIP INTRM1 18:00-20:15 2.25 DRILL TRIP INTRM1 20: 15 - 20:45 0.50 DRILL OTHR INTRM1 20:45 - 21 :15 0.50 DRILL OTHR INTRM1 21:15-22:30 1.25 CASE RURD INTRM1 22:30 - 23:00 0.50 CASE SFTY INTRM1 23:00 - 00:00 1.00 CASE RUNC INTRM1 00:00 - 00:30 0.50 CASE SFTY INTRM1 00:30 - 03:45 3.25 CASE RUNC INTRM1 1/18/2005 03:45 - 04:30 0.75 CASE CIRC INTRM1 04:30 - 07:30 3.00 CASE RUNe INTRM1 07:30 - 10:30 3.00 CEMENTCIRC INTRM1 10:30-11:45 1.25 CEMENT PULD INTRM1 11:45-12:15 0.50 CEMENTCIRC INTRM1 12:15 - 13:15 13:15 - 14:00 14:00 - 14:15 14:15 - 15:15 Printed: 2/18/2005 10:11:19AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/612005 Group: 1/18/2005 15:15 - 17:30 2.25 CASE RURD INTRM1 RD cement head, LD landing jt and RD csg handling equipment, checked seals on landing jt and ck ok 17:30 - 18:30 1.00 WELCTL EQRP INTRM1 Installed 75/8" pack-off and tested to 5,000 psi for 1 0 min and ck ok 18:30 - 19:00 0.50 CASE DEQT INTRM1 Attempt to re-test csg, closed blind rams and pressured up on 7 5/8" csg to 3,000 psi, pressure bled down 1,000 psi in 3 min, no test 19:00 - 19:30 0.50 CASE OTHR INTRM1 RU on 7 5/8" x 103/4" annulus and flushed same with 120 bbls of water, at 2 bpm pressured up to 1,150 psi and broke down and cont to flush annulus, ave 3 bpm at 875 psi. 19:30 - 19:45 0.25 DRILL PULD INTRM1 MU Saker 7 5/8" Retrievamatic test packer 19:45 - 00:00 4.25 DRILL PULD INTRM1 RIH with Saker packer PU 24 jts of 4" HWDP and 45 jts of hybrid push pipe from pipe shed RIH to 2,104' 1/19/2005 00:00 - 02:45 2.75 DRILL PULD INTRM1 Cont RIH with Saker 7 5/8" retrieveamatic packer, RIH from 2,104' to 5,172', PU 99 jts of 4" XT -39 DP from pipe shed while RIH with packer 02:45 - 05:30 2.75 DRILL DEQT INTRM1 Set packer at 5,172' and attempted to test csg to 3,000 psi and would not test, moved packer up hole to 5,165', 5,157', 5,142' and 5,126' and still wouldn't test, determine packer had failed. Up wt 120k , Dn wt 83k 05:30 - 09:30 4.00 DRILL TRIP INTRM1 Pumped dry job and POOH to Saker packer, stood back HWDP and hybrid push pipe 09:30 - 09:45 0.25 DRILL PULD INTRM1 LD Saker packer, sent packer to Saker shop and found O-ring was cut in the piston of the packer 09:45 - 10:30 0.75 DRILL PULD INTRM1 LD 1 std of 5" HWDP from derrick 10:30 - 11 :00 0.50 DRILL PULD INTRM1 MU Halliburton 7 5/8" RTTS packer 11 :00 - 16:00 5.00 DRILL TRIP INTRM1 RIH with RTTS packer to 5,172', while RIH tested packer at 995' and 2,463' to 3,000 psi and packer ck ok, cont RIH to 5,172' and set packer, st wt up 120K, dn wt 83K 16:00 - 17:15 1.25 DRILL DEQT INTRM1 RU and tested 7 5/8" csg to 3,000 psi for 30 min, good test. Loss 120 psi over 30 min 17:15 - 21 :00 3.75 DRILL TRIP INTRM1 Pumped dry job and POOH, LD HES packer and cleared rig floor 21:00 -21:15 0.25 DRILL SFTY INTRM1 Held PJSM on MU 6 3/4" SHA #4 21:15-00:00 2.75 DRILL PULD i INTRM1 Segan PU and MU 6 3/4" SHA #4, MU 6 3/4" bit #4, Geo-pilot with MWD, uploaded MWD and programmed Geo-Pilot, RIH to 87' Note: Little Red freeze protected 7 5/8" x 10 3/4" annulus with 85 bbls of diesel 1/20/2005 00:00 - 01 :30 1.50 DRILL PULD INTRM1 Fin MU 6 3/4" SHA #4, PU Flex DC's, HWDP and jars RIH to 370', shallow tested MWD and Geo-Pilot 01 :30 - 04:00 2.50 DRILL TRIP INTRM1 RIH with SHA #4 from 370' to 5,037', PU an add. 12 jts of 4" DP from pipe shed while RIH 04:00 - 04:45 0.75 DRILL SFTY INTRM1 Held a stripping and well kill drill with rig crew 04:45 - 06:00 1.25 RIGMNT RSRV INTRM1 Slip and cut 85' of drilling line and serviced top drive 06:00 - 06:45 0.75 DRILL TRIP INTRM1 RIH from 5,037' to 5,179', washed down 93' and tagged plugs above I float collar at 5,179' 06:45 - 11 :45 5.00 CEMENTDSHO INTRM1 Drilled out plugs and float collar at 5,182', shoe track, float shoe at 5,267' and 20' of new formation to 5,290' MD/3,697' TVD, ART .5 hrs, 2-4K wob, 50 rpm's, 240 gpm, 1,600 psi, rot wt 85K, up wt 94K, dn wt I 76K 11:45 -12:15 0.50 DRILL CIRC INTRM1 Circ btms up at 5,290' evening MW in and out at 9.0 ppg MOSM, PU bit to inside of csg 12:15 -13:15 1.00 DRILL LOT INTRM1 RU and performed LOT to 12.8 ppg EMW with 9.0 ppg MOSM, 735 psi at 3,698' TVD 13:15 - 00:00 10.75 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "S" sand lateral with Geo-Pilot rotary steerable assembly from 5,290' to 6,262' MD/3,744' TVD (972'), ART 7.7 hrs, 5-12K wob, 85 rpm's, 85 spm, 300 gpm, off btm pressure 2,400 psi, on btm 2,500 psi, off btm torque 4K ft-Ibs, on btm 4K ft-Ibs, rot wt Printed: 2/18/2005 10: 11: 19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1 E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/612005 Group: 1/20/2005 13:15 - 00:00 10.75 DRILL DRLG PROD 80K, up wt 102K, dn wt 70K, 9.0 ppg MOBM, clean hole ECD was 9.8 ppg, ave ECD 10.5 ppg, ave BGG 100 units, max gas 540 units 1/21/2005 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 6,262' to 7,188' MDI 3,767' TVD (926'), ART 10.3 hrs, 3-12K wob, 85 rpm's, 85 spm, 300 gpm, off btm pressure 2,475 psi, on btm 2,525 psi, off btm torque 4.5K ft-Ibs, on btm 5K ft-Ibs, rot wt 85K, up wt 111 K, dn wt 66K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 100-250 units, max gas 400 units 12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 7,188' to 8,245' MD/3,765' TVD (1,057'), ART 8.64 hrs, 3-13K wob, 85 rpm's, 85 spm, 300 gpm, off btm pressure 2,600 psi, on btm 2,700 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 85K, up wt 114K, dn wt 69K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 300 units, max gas 468 units 1/22/2005 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 8,245' to 9,611' MD/3,777' TVD (1,366'), ART 7.86 hrs, 3-1 OK wob, 85 rpm's to 3,900' then 105 rpm's to 9,611', 85 spm, 300 gpm, off btm pressure 2,725 psi, on btm 2,775 psi, off btm torque 7.5K ft-Ibs, on btm 7K ft-Ibs, rot wt 85K, up wt 122K, dn wt 56K, 9.0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 300 units, max gas 468 I units, pumped weighted hi vis sweep at 9,147' with 10-15% increase in . cuttings 12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 9,611' to 10,552' MD/3,763' TVD (941 '), ART 9.2 hrs, 3-14K wob, 105 rpm's, 85 spm, 300 gpm, off btm pressure 3,000 psi, on btm 3,075 psi, off btm torque 7.5K ft-Ibs, on btm 8K ft-Ibs, rot wt 88K, up wt 130K, dn wt 56K, 9.0 ppg MOBM, ave ECD 11.1 ppg, ave BGG 200 units, max gas 396 units pumped weighted hi vis sweep at 9,895' with 5-10% increase in cuttings back 1/23/2005 00:00 - 09:00 9.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 10,552' to 11,076' MD/3, 752' TVD (524'), ART 6.44 hrs, 2-10K wob, 105-110 rpm's, 85 spm, 300 gpm, off btm pressure 3,075 psi, on btm 3,150 psi, off btm torque 8K ft-Ibs, on btm 8K ft-Ibs, rot wt 92K, up wt 131 K, dn wt 58K, 9.0 ppg MOBM, ave ECD 11.3 ppg, ave BGG 100 units, max gas 240 units, Note: While drilling calcite stringers, would slow rotary to 70 rpm's due to tool vibration. Torque spiked to 10,000 ft-Ib. 09:00 - 09:15 0.25 DRILL OBSV PROD Monitored well-static 09:15-15:45 6.50 DRILL WIPR PROD Began wiping hole to shoe, back reamed out of hole from 11,076' to 6,620', backreamed out at 85 rpm's with 7K ft-Ibs torque, 300 gpm at 2,700 psi, began pulling tight in shale section at 6,620' 15:45 - 18:15 2.50 DRILL REAM PROD Backreamed out of hole slow due to packing off in shale section from 6,560' to 6,480', 85 rpm's with 5K ft-Ibs torque, 300 gpm at 2,200 psi 18:15-19:30 1.25! DRILL WIPR PROD Backreamed out of hole from 6,480' to 5,800', backreamed out at 85 rpm's with 4K ft-Ibs torque, 300 gpm at 2,200 psi, began pulling tight in upper shale section at 5,800' 19:30 - 23:30 4.00 DRILL 'REAM PROD Backreamed out of hole slow due to packing off in shale section from I 5,800' to 5,689', 85 rpm's with 4K ft-Ibs torque, 300 gpm at 2,100 psi, I would drop down thru reamed area and did not have any problems i pulling thru spot 23:30 - 00:00 0.50 DRILL WIPR PROD Backreamed out of hole from 5,689' to 5,416', backreamed out at 85 rpm's with 4K ft-Ibs torque, 300 gpm at 2,000 psi, no problems backreaming in sand section, Note: lost 56 bbls of mud to hole while Printed: 2/1812005 10: 11: 19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 1/8/2005 2/6/2005 Spud Date: 1/12/2005 End: 2/612005 Group: 1/23/2005 23:30 - 00:00 0.50 DRILL WIPR PROD backreaming out 1/24/2005 00:00 - 00:45 0.75 DRILL WIPR PROD Fin wiping hole to shoe by backreaming out of hole from 5,416' to 5,211' (7 5/8" Shoe @ 5,267'), Backreamed out at 85 rpm's, 300 gpm at 2,100 psi with no problems 00:45 - 01 :30 0.75 DRILL CIRC PROD Circ 2X btms up at shoe with no increase in cuttings and was clean at shakers, circ at 300 gpm at 2,100 psi and 50 rpm's 01 :30 - 02:00 0.50 RIGMNT RSRV 'PROD Serviœd top drive and inspected XT-39 saver sub and ck ok 02:00 - 05:45 3.75 DRILL TRIP PROD RIH from 5,211' to 10,937', no problems RIH thru shale sections 05:45 - 06:30 0.75 DRILL REAM PROD Washed and reamed 139' to btm, washed from 10,937' to 11,076' 06:30 - 12:00 5.50 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "B" sand lateral with Geo-Pilot rotary steerable system from 11,076' to 11,417' MOl 3,748' TVD (341 '), ART 3.51 hrs, 3-14K wob, 115 rpm's, 80 rpm's thru calcite stringers, 89 spm, 317 gpm, off btm pressure 3,600 psi, on btm 3,700 psi, off btm torque 8K ft-Ibs, on btm 8.5K ft-Ibs, rot wt 97K, up wt 133K, dn wt 60K, 9.0 ppg MOBM, ave ECD 11.5 ppg, ave BGG 50 units, max gas 111 units 12:00 - 23:15 11.25 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 11,417' to 12,415' MDI 3,742' TVD (998'), (T.D.) ART 7.41 hrs, 4-12K wob, 115 rpm's, 80 rpm's thru calcite stringers, 87 spm, 310 gpm, off btm pressure 3,975 psi, on btm 4,100 psi, off btm torque 9K ft-Ibs, on btm 8.5K ft-Ibs, had 11 K ft-Ib spikes while drlg on calcite stringers, rot wt 116K, up wt 157K, dn wt 69K, 9.0 ppg MOBM, ave ECD 11.8 ppg, ave BGG 100 units, max gas 206 units, Note pumped 35 bbl weighted hi vis sweep (2# over rvwv) at 12,300', ECD peaked at 12.2 ppg soon after going out bit and began having mud losses while drlg stand down and circ out sweep, had a 20% increase in cuttings back from sweep and lost a total of 74 bbls of 9.0 MOBM, prior to sweep rot wt was 114K, up wt 172K, dn wt 35K, at TD had 15 stds of hybrid push pipe, 8 stds of 4" HWDP and 38 lo-tads in hole 23:15 - 23:30 0.25 DRILL OBSV PROD Monitored well and had slight breathing due to losses 23:30 - 00:00 0.50 DRILL WIPR PROD Began wiping hole to shoe, backreamed out from 12,415' to 12,303' 1/25/2005 00:00 -13:15 13.25! DRILL WIPR PROD Con!. wiping hole to shoe, backreamed out from 12,303' to 5,230', backreamed out at 110-115 rpm's and 315 gpm, initial pressure 3,700 psi, final 2,275 psi, pulled slowed thru shale sections due to packing off slightly, calc fill on trip out 56 bbls, actual fill 82 bbls 13:15 - 14:30 1.25 DRILL CIRC PROD Circ hole clean at shoe, pumped weighted hi vis sweep and had no ! increase in cuttings back from sweep, circ a total of 2x btms up and was clean at shakers, circ at 300 gpm, 2,150 psi, 80 rpm's with 4K ft-Ibs torque, st up wt 95K, dn wt 80K 114:30 - 14:45 0.25 DRILL OBSV PROD Monitored well at shoe-static 14:45 -19:15 4.50 DRILL TRIP PROD RIH from 5,230' to 12,213', no problems RIH thru shale sections 19:15 - 20:00 0.75 DRILL REAM PROD Wash and reamed 202' to btm at 12,415' with no problems 20:00 - 22:15 2.25 DRILL CIRC PROD Pumped hi vis sweep only and circ out of hole with no increase in cuttings, circ at 290 gpm, 4,000 psi, 115 rpm's and 8K ft-Ibs off btm torque, 9.0 ppg MOBM, ECD ave 11.8 ppg, max gas at btms up 160 units then ave 35 units, obtained Geo-Pilot pressure data for Sperry Sun after circ out sweep 22: 15 - 23:45 1.50 DRILL CIRC PROD Displaœd out 9.0 ppg MOBM to 9.0 ppg SFMOBM, circ at 300 gpm, 3,900 psi, 115 rpm's, 9K ft-Ibs torque, rot wt 115K, up wt 160K, dn wt I 45K 23:45 - 00:00 0.25 DRILL OBSV PROD Monitored well-static, preparing to POOH 1/26/2005 00:00 - 09:00 9.00 DRILL TRIP I PROD POOH wet from 12,415' to BHA at 270', no problems pulling thru shale sections 09:00 -12:15 3.25 DRILL PULD PROD POOH and stood back flex DC's, HWDP and jars, downloaded MWD Printed: 2/1812005 10: 11: 19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1 E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 1/8/2005 2/6/2005 Spud Date: 1/12/2005 End: 2/612005 Group: 1/26/2005 09:00 -12:15 3.25 DRILL PULD PROD and LD same with Geo-Pilot rotary steerable assembly, cleared rig floor 12:15 - 12:45 0.50 CASE RURD CMPL TN RU Doyon's 4 1/2" liner running equipment 12:45 - 13:00 0.25 CASE SFTY CMPL TN Held PJSM with rig crew, tong operator and Baker rep on running of liner 13:00 - 18:30 5.50 CASE PULR CMPL TN PU and RIH with 41/2",12.6#, L-80 DWC IIBTM Liner per well program to 7,428' (241Jts total), ran 41/2" ROT silver bullet guide shoe with no float, ran a total of 207 jts (6,600') of 4 1/2" 12.6#, L-80, IBTM slotted liner, (btm 26 slotted jts are DWC), ran 34 jts (1,056') of 4 1/2", 12.6# L-80 IBTM blank liner, ran 234 - 41/2" x 61/2" spiralglide centralizers 1/jt #1 thru # 233, ran 6 constrictor packers placed on blank liner to cover shale sections. 18:30 - 19:00 0.50 CASE PULR CMPL TN MU Baker 190-47 seal bore ext, 5 1/2" x 75/8" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH I to 7,483', st wt up 84K, dn wt 66K, 19:00 - 22:30 3.50 CASE IRUNL CMPL TN RIH with liner on 4" DP to 12,385', while RIH began to slack off 30-40K# at 12,270', worked liner thru tight spot from 12,270' to 12,323' then was able to cont RIH, RIH and tagged btm at 12,415', no problems thru shale sections in upper hole section, PU to 12,385' to put liner on depth, ran liner with 28 stds of 4" DP w/Lo-Tads, 8 stds HWDP w/Lo-tads, 15 stds Hybrid push pipe, st wt up 143K, dn wt 90K 22:30 - 22:45 0.25 CASE OTHR CMPL TN Dropped 1 3/4" ball and pumped down to seat, pumped at 2 1/2 bpm at 400 psi, with ball on seat pressured up to 2,500 psi to set Flexlock hanger, slacked off 40K, cont to set packer, pressured up to 4,200 psi and set ZXP packer, no problems setting hangerl packer, set "B" sand liner with TOL @ 4,905' MOl 3,626' TVD and shoe at 12,388' MOl 3,740' TVD 22:45 - 23:00 0.25 CASE DEQT CMPL TN Tested ZXP packer to 1,000 psi for 5 min & checked ok 23:00 - 23:45 0.75 CASE CIRC CMPL TN PU out of top of liner no problems and circ btms up, circ at 300 gpm, 0.251 DRILL 2000 psi, no gas at btms up, st wt up after setting liner 125K, 108K dn 23:45 - 00:00 OBSV CMPL TN Monitored well-static, preparing to POOH 1/27/2005 00:00 - 03:00 3.00 DRILL TRIP CMPL TN POOH wet and LD Baker liner running tool, cleared rig floor 03:00 - 06: 15 3.25 WINDOWPULD PROD2 Held PJSM, PU & MU Baker 7 5/8" whipstock assembly BHA #5 and RIH to 576', MU milling assembly and LD same, PU seal assembly, locator sub, unloader sub, then PU 2-DP pup jts, 1 jt of 3 1/2" HWDP for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD and RIH with 4 stds of hybrid push pipe to 576' 06:15 -10:15 4.00 WINDOWTRIP PROD2 RIH with whipstock assembly from 576' to 4,674', shallow tested MWD W/RIH 10: 15 - 11 :30 1.25 WINDOWOTHR PROD2 Made MADD pass from 4,674' to 4,758' and correlated MWD to K-13, cont to RIH orienting whipstock, RIH & tagged TOL at 4,905', logged K-13 at 250 gpm, 1,800 psi, st wt up 123K, dn wt 105K, RIH with whipstock milling assembly with 27 stds of 4" DP with Lo-tads, 8 stds of HWDP with Lo-tads and 11 stds of hybrid push pipe 11 :30 - 11 :45 0.25 WINDOWSETW PROD2 Oriented whipstock 6 deg left of high side, tagged TOL at 4,905', set whipstock and sheared off from same, top of whipstock at 4,816' 11:45-12:15 0.50 WINDOVVCIRC PROD2 Displaced out 9.0 ppg SFMOBM to 9.0 ppg MOBM, circ at 250 gpm, 1,800 psi, rot wt 107K, up wt 123K, dn 105K 12:15 - 17:45 5.50 WINDOWSTWP PROD2 Milled window in 7 5/8" casing for "D" sand lateral, top of window at 4,816', btm of window at 4,828", drilled 6 3/4" hole to 4,875' MD/3,617' TVD (59') ADT 4.7 hrs, 1-4K wob while milling, 5-12K while drlg formation, 80-120 rpm's, 315 gpm, 2,700 psi, torque 3-7K ft-Ibs, rot wt Printed: 2/18/2005 10:11:19AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: Spud Date: 1/12/2005 End: 2/612005 Group: 1/8/2005 2/6/2005 110K, up wt 120K, dn wt 107K, Note: Drilled extra hole to have 30' of gauged hole out of window for Geo-pilot tool Pumped weighted hi vis sweep and circ hole clean while working mills thru window, circ at 315 gpm, 2,600 psi Monitored well-static, pumped dry job, POOH from 4,794' to 213', stood back 4 stds hybrid push pipe LD MWD and milling assembly, upper mill out of gauge 1/32", took gauge and gauged next bit to be RIH and ck ok Pulled wear bushing and flushed out stack after milling window RU to test BOPE Tested BOPE, rams, valves and manifold to 250 psi low and 3,500 psi high, tested annular to 250 psi and 2,800 psi, Note: Jeff Jones with AOGCC witnessed test Pulled test plug and installed wear bushing Slip and cut 80' of drlg line Serviced top drive and changed out XT-39 saver sub MU 63/4" BHA #6 and RIH to 371', MU 6 3/4" bit #6, Geo-pilot rotary steerable with MWD, uploaded MWD and programmed Geo-pilot, then RIH with flex dc's, HWDP and jars to 371' Shallow tested MWD and recorded ECD pressures for Sperry Sun RIH with BHA #6 from 371' to 4,763' RIH from 4,763' thru window at 4,816' with pumps off, no problems, est CÎrc and worked Geo-pilot thru window several times with no problems, washed to btm at 4,875', rot wt 85K, up wt 95K, dn wt 76K, 30-40 rpm's with 3.5K ft-Ibs torque Directionally drilled 6 3/4" hole in "D" sand lateral with Geo-Pilot rotary steerable system from 4,875' to 5,654' MD/3,671' TVD (779'), ART 8.55 hrs, 2-14K wob, 90-110 rpm's, 80 rpm's thru calcite stringers, 85 spm, 300 gpm, off btm pressure 2,450 psi, on btm 2,500 psi, off btm torque 3.5K ft-Ibs, on btm 4K ft-Ibs, rot wt 86K, up wt 96K, dn wt 75K, 9.0 ppg MOBM, ave ECD 10.1 ppg, ave BGG 300 units, max gas 788 units 11.25 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "0" sand lateral with Geo-Pilot rotary steerable system from 5,654' to 6,577' MD/ 3,696' TVD (923'), ART 9.07 hrs, 2-14K wob, 110 rpm's, 80 rpm's thru calcite stringers, 85 spm, 300 gpm, off btm pressure 2,500 psi, on btm 2,550 psi, off btm torque 4.5K ft-Ibs, on btm 5K ft-Ibs, rot wt 85K, up wt 103K, dn wt 69K, 9.0 ppg MOBM, ave ECD 10.4 ppg, ave BGG 300 units, max gas 668 units Trouble shoot Geo-Pilot signal, unable to get tool to respond, tool failed Pumped weighted hi vis sweep at 6,577' and circ out of hole, no increase in cuttings back from sweep, circ at 300 gpm, 2,750 psi, 80 rpm's, 5K ft-Ibs torque Backreamed out of hole from 6,577' to 4,950' then pumped out hole thru window to 4,790', backreamed out at drlg rate 300 gpm, 110 rpm's Circ 2X btms up above window at 4,790' and clean at shakers, circ at 300 gpm, 2,400 psi, 80 rpm's, 4K ft-Ibs torque, rot wt 85K, up wt 95K, dn wt 76K Monitored well-static, pumped dry job POOH from 4,790' to BHA at 371' POOH and stood back HWDP, jars and flex dc's, downloaded MWD, LD MWD and Geo-Pilot MU 6 3/4" BHA #7 and RIH to 368', MU bit #7 with slickbore motor with 1/27/2005 12:15-17:45 5.50 WINDOIhsTWP PROD2 I i 17:45 - 18:45 1.00 WINDOIIIICIRC PROD2 18:45 - 19:00 0.25 WINDOWOTHR I PROD2 19:00 - 20:45 1.75 WINDOWTRIP PROD2 20:45 - 22:30 1.75 WINDOV\IPULD PROD2 22:30 - 23:30 1.00 WINDOWOTHR PROD2 23:30 - 00:00 0.50 WELCTL BOPE PROD2 1/28/2005 00:00 - 04:00 4.00 WELCTL BOPE PROD2 04:00 - 04:30 0.50 DRILL ÞULD PROD2 04:30 - 05:30 1.00 RIGMNT RSRV PROD2 05:30 - 07:30 2.00 RIGMNT RSRV PROD2 07:30 - 10:00 2.50 DRILL PULD PROD2 10:00 - 10:45 0.75 DRILL DEQT PROD2 10:45 - 12:45 2.00 DRILL TRIP PROD2 12:45 - 13:30 0.75 DRILL REAM PROD2 I I 13:30 - 00:00 10.50 DRILL TRIP PROD2 1/29/2005 00:00 - 11 :15 11:15 -12:15 1.00 DRILL DEQT PROD2 12:15 -13:15 1.00 DRILL CIRC PROD2 113:15-15:30 2.25 DRILL TRIP PROD2 I I '15:30 - 16:30 1.00 DRILL CIRC PROD2 16:30 - 16:45 0.25 DRILL OBSV PROD2 16:45 - 18:00 1.25 DRILL TRIP PROD2 18:00 - 20:15 2.25 DRILL PULD PROD2 20:15 - 22:30 2.25 DRILL PULD PROD2 Printed: 2/18/2005 10:11:19AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 1/8/2005 2/6/2005 Spud Date: 1/12/2005 End: 2/612005 Group: 1/29/2005 20:15 - 22:30 2.25 DRILL PULD PROD2 1.5 deg bend and MWD, oriented and uploaded MWD, then RIH with flex dc's, HWDP and jars to 368' .22:30 - 00:00 1.50 DRILL TRIP PROD2 RIH with BHA #7 from 368' to 3,919' 1/30/2005 00:00 - 01 :30 1.50 DRILL TRIP PROD2 Fin RIH from 3,919' to btm at 6,577', no problems RIH thru window and washed 42' to btm 01 :30 - 12:00 10.50 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral with Slickbore motor from 6,577' to 7,186 MD/3,712' TVD (609'), ART 6.71 hrs, AST .92 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 85 spm, 300 gpm, off btm pressure 2,400 psi, on btm 2,500 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 84K, up wt 105K, dn wt 68K, 9.0 ppg MOBM, i ave ECD 10.6 ppg, ave BGG 100 units, max gas 415 units 12:00 - 00:00 12.00 DRILL IDRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral with Slickbore motor I from 7,186 to 8,416' MD/3,713' TVD (1,230'), ART 5.95 hrs, AST 1.82 i hrs, 3-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 85 spm, 300 gpm, off btm pressure 2,475 psi, on btm 2,625 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wt 84K, up wt 112K, dn wt 64K, 9.0 ppg MOBM, ave ECD 10.8 ppg, ave BGG 100 units, max gas 562 units 1/31/2005 00:00 - 09:00 9.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "D" sand lateral with Slickbore motor from 8,416' to 8,903' MD/3,706' TVD (487'), ART 5.77 hrs, AST 1.13 hrs, 3-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 85 spm, 300 gpm, off btm pressure 2,550 psi, on btm 2,750 psi, off btm torque 7K I ft-Ibs, on btm 7K ft-Ibs, rot wt 84K, up wt 114K, dn wt 61 K, 9.0 ppg I MOBM, ave ECD 10.9 ppg, ave BGG 70 units, max gas 160 units 09:00 - 10:30 1.50 DRILL CIRC PROD2 Circ hole while evaluating logs for geology 10:30 - 13:45 3.25 DRILL DRLG PROD2 Drilled 6 3/4" hole from 8,903' to 9,115' MD/ 3,712' TVD (212') ART .9 hrs, AST 1.02 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 300 gpm, off btm pressure 2,650 psi, on btm pressure 2,750 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wt 84K, up wt 116K, dn wt 59K, 9.0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 100 units, unable to slide due to lack of down weight 13:45 - 15:00 1.25 DRILL WIPR PROD2 Backreamed out of hole 9 stds from 9,115' to 8,230' to reposition HWDP and push pipe, no problems, backreamed out at 300 gpm, 2,750 psi, 95 rpm's and 6K ft-Ibs torque 15:00 - 15:45 0.75 DRILL WIPR PROD2 RIH from 8,230' to 9,071' and washed 44' to btm with no problems, rot wt 95K, up wt 124K, dn wt 72K, RIH with 8 stds HWDP with lo-tads and , 1 std of hybrid push pipe 15:45 - 00:00 8.25 DRILL DRLG PROD2 Drilled 6 3/4" hole from 9,115' to 9,676' MD/ 3,715' TVD (561') ART 4.26 hrs, AST 1.18 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 300 gpm, off btm pressure 2,975 psi, on btm pressure 3,175 psi, off btm torque 7.5K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 104K, up wt 133K, dn wt 77K, 9.0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 100 units, max gas 286 units 2/1/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 Drilled 6 3/4" hole from 9,676' to 10476' MD/3,690' TVD (800') ART 6.66 hrs, AST 1.38 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite stringers, 300 gpm, off btm pressure 2,975-3350 psi, on btm pressure 3,175-3450 psi, off btm torque 7.5-9.5K ft-Ibs, on btm 7.5-9.K ft-Ibs, rot wt 104-112K, up wt 133-145K, dn wt 77-82K, 9.0 ppg MOBM, ave ECD 11 ppg, ave BGG 118 units, max gas 358 units 12:00 - 00:00 12.00 DRILL DRLG PROD2 Drilled 6 3/4" hole from 10476' to 11451' MD/3665' TVD (975') ART 4.84 hrs, AST 1.96 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite i stringers, 300 gpm, off btm pressure 3350-3500 psi, on btm pressure 3,450-3650 psi, off btm torque 9.5-11.5K ft-Ibs, on btm 9-11 K ft-Ibs, rot wt 112-109K, up wt 145-160K, dn wt 80-60K, 9.0 ppg MOBM, ave ECD Printed: 2/18/2005 10:11:19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/612005 Group: 2/1/2005 12:00 - 00:00 12.00 DRILL DRLG PROD2 11.1 ppg, ave BGG 118 units, max gas 285 units 2/2/2005 00:00 - 08:00 8.00 DRILL DRLG PROD2 Drilled 6 3/4" hole from 11451' to 12050' MD/3680' TVD (599') ART 3.31 hrs, AST 1.96 hrs, 2-14K wob, 95 rpm's, 80 rpm's thru calcite 'stringers, 300 gpm, off btm pressure 3500-3650 psi, on btm pressure 3650- 3825 psi, off btm torque 11.5-12K ft-Ibs, on btm 11- 11.5K ft-Ibs, rot wt 109-106K, up wt 160-166K, dn wt 65-55K, 9.0 ppg MOBM, ave ECD 11.5 ppg, ave BGG 120 units, max gas 329 units 08:00 - 08:30 0.50 DRILL CIRC PROD2 Circ and recip pipe while geologist confirs wI town. 08:30 - 14:00 5.50 DRILL DRLG PROD2 Drilled 6 3/4" hole from 12050' to 12414' MD/3671' TVD (364') ART 1.59 hrs, AST 2.06 hrs, 2-15K wob, 95 rpm's, 80 rpm's thru calcite ì stringers, 300 gpm, off btm pressure 3725 psi, on btm pressure 3800 psi, off btm torque 11.5-12K ft-Ibs, on btm 11-13K ft-Ibs, rot wt 105K, up wt 167, dn wt 60-55K, 9.0 ppg MOBM, ave ECD 11.7 ppg, ave BGG 95 units, max gas 256 units 14:00 - 14:15 0.25 DRILL CIRC PROD2 Monitor well, static, circ 15 min. 14:15 - 23:30 9.25 DRILL REAM PROD2 Backreamed out from 12,414' to 4949', backreamed out at 95 rpm's and 300 gpm, initial pressure 3,725 psi, final 1900 psi, calc fill on trip out 58 bbls, actual fill 95 bbls(running solids control equip). Did not rotate or pump while pulling fl 4949'-4791'. No problems pulling through window @ 4828'-4816'. PU wt @ window, 98k. 23:30 - 00:00 0.50 DRILL CIRC PROD2 Circ and recip @ 300 gpm, 1800 psi, 100 rpm. Pump hi-vis weighted 2# over (11.0 ppg) sweep to clean hole. 2/3/2005 00:00 - 00:30 0.50 DRILL CIRC PROD2 Circ and recip @ 300 gpm, 1800 psi, 100 rpm. Pump hi-vis weighted 2# over (11.0 ppg) sweep to clean hole. 00:30 - 00:45 . 0.25 DRILL OTHR PROD2 . Orient to high side, slide through window wlo pumps, no problems, monitor well. 00:45 - 05:00 4.25 DRILL 'TRIP PROD2 Trip in hole f/4854' to 12414'. Fill pipe every 20 stands. Picked up 1 jt and 10' pup jt to tag bottom @ 12414'. No problems. 05:00 - 07:00 2.00 DRILL CIRC PROD2 Establish circulation, everything looks good, pump Hi-vis sweep @ 85 spm wI 3800 psi. 07:00 - 08:30 1.50 DRILL CIRC PROD2 Displace well to solids free oil base mud. 85 spm wI 3800 psi. 08:30 - 08:45 0.25 DRILL CIRC PROD2 Slow pump rates, monitor well, OK. 08:45 - 12:00 3.25 DRILL TRIP PROD2 POOH on elevators f/12414' to 6348'. No problems. 12:00 - 14:00 2.00 DRILL TRIP PROD2 POOH on elevators f/6348' to 365'. No problems @ window, or any i other place. 14:00 - 16:15 2.25 DRILL PULD PROD2 UD BHA # 7. UD 5 HWDP, jars, x-o, 3 NMDC's, download MWD/LWD, UD bit, pull MWD probe, UD logging tools and MWD, UD motor. 16:15 - 16:45 0.50 WINDOWPULD CMPL T2 MU Baker whipstock retieving assembly. 1 jt 31/2" HWDP, hook, bumper jars, oil jars, x-o 16:45 - 18:30 1.75 WINDOWTRIP CMPL T2 Trip in hole fl 58' to 4784'. PU wt 124k, So wt 106K. Tagged slot on whipstock @ 4822'. 18:30 - 19:15 0.75 WINDOWOTHR CMPL T2 Wash slot, turn 1/4 turn four times, hooked slot, sheared unloader @ 160k, pick up to 190k. cock jars, PU to 200k, cock jars, PU to 175K, jars fired, pulling assembly free. Hole taking a little fluid. 13 bbls to fill hole. Pull 40', set stand back. 19:15 - 20:00 0.75 WINDOilRC CMPL T2 Circ bottoms up. wI 60 spm & 1000 psi. Hole took 8 bbls while circ. Monitor well. Static. No gas. 20:00 - 22:30 2.50 WINDOWTRIP CMPL T2 Drop 1 3/4" rabbit on wire. POOH wI Whipstock. 22:30 - 00:00 1.50 WINDOWPULD i CMPL T2 UD whipstock retrieving tools BHA, UD whipstock and debris excluder sub, un loader valve, emergency shear disconnect, 75/8" Torquemaster retrievable BTA, double pin blanking sub, unloader valve. 2/4/2005 00:00 - 00:30 0.50 WINDOWPULD CMPL T2 Finish UD whipstock assembly, UD 1 jt 31/2" HWDP, (2) 31/2" dp pups, locator sub and dummy seals. Clean & clear rig floor. Printed: 2/18/2005 10: 11: 19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: Spud Date: 1/12/2005 End: 2/612005 Group: 1/8/2005 2/6/2005 2/4/2005 I 0.25' CMPL TN RURD CMPL T2 0.25 CMPL TN SFTY CMPL T2 3.75 CMPLTN RUNT CMPLT2 00:30 - 00:45 00:45 - 01 :00 01 :00 - 04:45 04:45 - 06:45 2.00 CMPL TN RUNT CMPL T2 06:45 - 07:15 0.50 CMPL TN OTHR CMPL T2 2.75 CMPLTNITRIP CMPLT2 07:15 - 10:00 10:00 -10:45 0.75 CMPL TN OTHR CMPL T2 10:45 - 11 :00 0.25 CMPL TN CIRC CMPL T2 I 11 :00 - 11:45 i 0.75 CMPL TN CIRC CMPL T2 11 :45 - 12:00 0.25 CMPL TN OTHR CMPL T2 12:00 - 14:00 2.00 CMPL TN TRIP CMPL T2 14:00 - 14:30 0.50 CMPL TN PULD CMPL T2 14:30 - 15:30 1.00 DRILL OTHR CMPL T2 15:30 - 22:00 6.50 DRILL PULD CMPL T2 I , 22:00 - 00:00 2.00 DRILL PULD CMPL T2 2/5/2005 00:00 - 01 :00 1.00 DRILL PULD CMPL T2 01 :00 - 03:30 2.50 DRILL PULD CMPL T2 I 03:30 - 04:00 : 04:00 - 05:00 05:00 - 05:30 05:30 - 05:45 0.50 DRILL PULD. CMPL T2 1.00 RIGMNT RSRV I CMPL T2 0.50 CMPL TN RUNT CMPL T2 0.25 CMPL TN SFTY CMPL T2 RU to run 41/2" 12.6#/ft L-80 IBT slotted production liner. PJSM on running 4 1/2" "D" lateral slotted liner. PU & ran 4-112" liner per program to 4839'. Ran 3-1/2" Baker guide I shoe, 3-1/2" bent jt, XO, 4-112" pup jt, Baker packoff bushing, ran 156 Ijts of 41/2" 12.6#, L-80 IBT liner to window. Went through window @ 4816'-4828' with no problems. PU wt 73K. SO wt 68k. Continue running 4-112" liner per program to 7541'. Ran total of 244 jts (7493.66') of 4 1/2" 12.6#, L-80, IBT liner, ran 229 jts (7031.86') of slotted liner and 15 jts (461.80') of blank liner. Ran (243) 41/2" x 61/2" spiralglider centralizers, 1/jt on all of liner, except last blank. Ran a total of (4) easy Well Solutions Constrictor swell packers to be set at 12152', 11981',9031',8851'. M/U Baker Model B1 Flanged Hook Hanger & running tool. RIH 1 std 4" dp wI LoTads. Up wt 82K, Dn wt 63K. RIH with 4 1/2" liner on 4" DP from 7679' to 12383'. Ran liner using total of 51 stands dp (27 stands 4" weatherford dp wI Lo-Tads, 8 stands 4" weatherford HWDP wI Lo-tads, and 15 stands 4" Hybrid (4" HWDP on top then 2 joints 4 3/4" DC), then 1 stand slick 4" weatherford dp. PU wt 143K, SO wt 77K. Hook Baker Model B1 Hook hanger in window, wI top of hook hanger @ 4812'. Hook and recheck several times to verify position (Hooked total of 9 times at the same depth, turning orientation 10 times to verify). With liner hooked and top of hook hanger@ 12383', pump ball @ 4bpm wI 700 psi. With ball on seat, pressure up to 2500 psi to release fl hook hanger. Bleed pressure to zero. PU wt 125k, SO wt 60k. Positive indicator of losing 16K liner weight. Pressure to 3200 psi to shear pump out sub. Circulate bottoms up @ 4813', pump 85 spm(7.2 bpm) & 1600 psi. Blow down top drive, monitor well. OK. POOH wI Weatherford 4" S-135, XT-39 dp used to run liner. Calc fill 40 bbls, actual fill 47 bbls. UD Baker Liner running tools. Clear rig floor. RU to UD 4" Weatherford DP in mouse hole. PJSM. UD 80 stands Weatherford 4", S-135, XT-39 dp fl off drillers side of derrick. Lay down using mouse hole. UD 18 stands Weatherford 4", S-135, XT-39 dp wI Lo-Tads installed after the double (on top of bottom single). Lay down using mouse hole. Note: While laying down dp fl derrick, hole took 5 bbls in 9 1/2 hours (1430 hrs to midnight) Note: All OBM has been centifuged, then weighted back up to 9.0ppg wI S-200, then stored in upright tanks on 1 E pad. UD 9 stands Weatherford 4", S-135, XT-39 dp wI Lo-Tads installed after the double (on top of bottom single). Lay down using mouse hole. UD 8 stands Weatherford 4" S-135, XT-39 HWDP wI Lo-tads installed after the double (on top of bottom single). Lay down using mouse hole. UD 15 stands Hybrid pipe( 1 joint on top of (2) Weatherford 4 3/4" Spiral DC's. Lay down using mouse hole. UD Lotads off rig floor. Clear floor. PJSM on slip and cut drilling line. Slip and cut 91' drilling line. Rig up tools to run 41/2" 12.6 ppf L-80 IBT-M tubing. PJSM on running 41/2" 12.6 ppf L-80 IBT-M tubing, to run in hole and stand back fl ESP completion. Note: Hole took 3.6 bbls in 6 hours. Printed: 2/18/2005 10: 11: 19 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-121 1 E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: Spud Date: 1/12/2005 End: 2/612005 Group: 1/8/2005 2/6/2005 2/5/2005 05:45 - 08:45 3.00 CMPL TN RUNT CMPL T2 08:45 - 10:00 1.25 CMPL TN CIRC CMPL T2 10:00 - 12:15 2.25 CMPL TN TRIP CMPL T2 12:15 - 12:30 0.25 CMPL TN OTHR CMPL T2 12:30 - 14:00 1.50 CMPL TN OTHR CMPL T2 14:00 - 14:30 0.50 CMPL TN SFTY CMPL T2 14:30 - 21 :00 6.50 CMPL TN PULO CMPL T2 21:00 - 21:15 0.25 CMPL TN RUNT CMPL T2 21:15-21:45 0.50 CMPL TN OTHR CMPL T2 21 :45 - 00:00 2.25 CMPL TN RUNT CMPL T2 2/6/2005 00:00 - 01 :30 01:30-02:15 02: 15 - 04:00 04:00 - 05:15 05:15 - 06:00 06:00 - 06:30 I I 06:30 - 07:30 07:30 - 10:30 10:30 - 11 :15 1.50 CMPL TN RUNT CMPL T2 0.75 CMPL TN RUNT CMPL T2 1.75 CMPLTN RUNT CMPLT2 1.25 CMPL TN RUNT CMPL T2 I I 0.75 CMPLTN RUNT CMPLT2 0.50 CMPL TN RUNT CMPL T2 1.00 CMPL TN SEQT CMPL T2 3.00 CMPL TN OTHR CMPL T2 0.75 CMPLTN SOHO CMPLT2 PJSM, PUlMU/RIH 132 joints 41/2" 12.6 ppf L-80 IBM tubing wI special clearance collars. Mule shoe on bottom. Run to 4105'. Circ bottoms up @ 85 SPM (7.2 bpm) wI 700 psi. 9.0 ppg Solids Free Oil Base Mud. RID circ equip. RU double stack tongs. Hole took 1 bbl while circ. POOH, Stand back (44) stands 41/2" 12.6 ppf L-80 IBT-M tubing fl ESP completion. Pull Vetco Gray wear bushing. Clear rig floor. RU fl ESP completion. PJSM on running 4 1/2" ESP completion. PU Centrilift's ESP motor assembly, tandem seal section with screen intake, filled motor with oil and connect ESP cable and checked same, Installed 1/4" control line for pump gauge i RIH with ESP assembly to 136': PU jts # 1 & # 2,41/2", 12.6#, L-80, IBTM SCC tbg and MU well discharge pressure sub Connected 1/4" control line to discharge pressure sub and checked cable continuity. RIH slow with ESP completion assembly from 136' to 752': Ran joints #3-#20,41/2" 12.6ppf L-80 IBTM with special clearance collars, PU Cameo GLM KBG-2 with pups each end, ran joints running cable and installing single channel across collar clamps on every other jt and checking cable conductivity every 1,000' Continue RIH slow with ESP completion assembly from 752' to 1640': Ran joints #21-#49,41/2" 12.6ppf L-80 IBTM with special clearance collars, PU Cameo GLM KBG-2 with pups each end, running cable and installing cannon clamps on every other jt and checking cable conductivity every 1,000'. PU wt 60K, SO wt 56K RIH slow with ESP completion assembly from 1640' to 1982': Ran joints #50-#60,41/2" 12.6ppf L-80 IBTM with special clearance collars. Test conductivity of cable. RIH slow with ESP completion assembly from 1982' to 2912': Ran joints #61- #90,41/2" 12.6ppf L-80 IBTM with special clearance collars. Test conductivity of cable. RIH slow with ESP completion assembly from 2912' to 3848': Ran joints #91- #120,41/2" 12.6ppf L-80 IBTM with special clearance collars. Test conductivity of cable. RIH slow with ESP completion assembly from 3848' to 4254': Ran joints #121- #133,41/2" 12.6ppf L-80 IBTM with special clearance collars. Test conductivity of cable. MU Vetco Gray Hanger (13 1/2" 00, 4.909 MeA top thread, full joint PxP 41/2" 12.6 ppf IBT below hanger) and Landing jt with TWC. PU wt 84K, So wt 72K. Continuity check. OK. Cut ESP Cable. Rig down sheave in derrick fl running ESP cable. Spliced ESP Cable and MU to tbg hanger, attatch band above and below splice. (Total 3 bands on landing joint). Test line. OK. RIH, landed hanger and RILDS, Land string as per detail wI Tail @ 4309'(TVO = 3433',64.7 deg), Pump guage @ 4305'(3432' TVO, 64.77 deg), Motor @ 4271', Seal Section @ 4257'( 3412 TVO, 64.9 deg), screen intake @ 4246'( 3407' TVO, 64.9 deg), discharge pressure sub @ 4171'( 3375' TVO,64.5 deg), GLM #1 @ 3593' MD( 3112' TVO, 54.6 deg), GLM #2 @ 2675' MD( 2403' TVD, 37.2 deg), ran a total of 133 jts (4135.78') of 4 1/2" 12.6#, L-80, IBTM tbg with special clearance Printed: 2/18/2005 10:11:19AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-121 1E-121 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: 1/8/2005 Rig Release: 2/6/2005 Rig Number: Spud Date: 1/12/2005 End: 2/612005 Group: 2/6/2005 10:30-11:15 0.75 CMPLTN SOHO CMPL T2 11:15 -11:30 0.25 CMPL TN SEQT CMPL T2 11 :30 - 13:00 1.50 WELCTL NUND CMPL T2 13:00 -15:15 2.25 WELCTL.! NUND CMPL T2 I 15:15 -17:45 2.50 CMPL TN FRZP CMPL T2 I 17:45 - 19:15 1.50 WELCTL OTHR I CMPL T2 19:15-21:15 2.00 WELCTL NUND . CMPL T2 21:15 - 00:00 2.75 CMPLTN OTHR CMPL T2 collars, PU wt 84K, dn wt 72K, blocks 35K of this wt. ,Test Vetco Gray upper and lower seals to 250 psi then 5000 psi f/1 0 min. NID BOPE. NU Vetco Gray tree, test void 5000 psi f/10 min. Test tree 5000 psi 10 min. Pull TWC. Centrilift test ESP cable after tree nippled up. OK. RU to freeze protect. PJSM. Freeze protect wI Little Red. Pump @ 2.1 bpm @ 825 psi. Use willis choke to hold back presssure w/pumping. Pump total 181.7 bbls diesel. Blow down lines. RU scaffolding. Vetco Gray set BPV. Install accuator valve, remove double annulus valve. Secure well. Cleaning pits, clean pollution pans, clean pan under drawworks. Change saver sub on top drive f/4" XT-39 to 4 1/2" IF. Release Rig fl 1E-121. Printed: 2/18/2005 10: 11: 19 AM . 1E-121 Well Events Summary . Date Summary 01/12/05 RUN GYRO TOOL ON THE RIG. 03/08/05 ATTEMPTED TO PERFORM A FCO. DUE TO PHASE TWO WEATHER CONDITIONS JOB POSTPONED. [FCO] 03/12/05 PERFORMED A MUD SWAP TO TOP OF MOTOR AT 4,242' CTMD. RETURNS 1-1 ALL DAY. FLUSHED SCREEN WITH DIESEL. WELL FREEZE PROTECTED TO 4,242' CTMD. [FCO] 03/13/05 TAGGED PUMP DRIVE SHAFT @ 4271' RKB WITH 2.25" LIB. GAUGED TBG TO 3.79" TO SAME. PULLED DV, SET 2000 PSI SOV @ 3594' RKB. IN PROGRESS. [Tag] 03/14/05 SET 44' 2" ESP PUMP @ 4271' RKB. RUN PACKOFF ASSY (OAL 103", 2.24" ID, 36" TO KOBE KNOCK OUT) TO 4227' RKB. TEST PIO & PUMP 1000 PSI, GOOD. SET 4- 1/2" SLIP STOP @ 4224' RKB. [ESP Work] Halliburton Sperry-Sun Western North Slope ConocoPhillips 1 E-121 . Job No. AKZZ3458622, Surveyed: 24 January, 2005 Survey Report 16 February, 2005 Your Ref: API 500292323800 Surface Coordinates: 5960559.83 N, 549889.88 E (70· 18'10.8860w N, 149· 35' 45. 1920w W) Grid Coordinate System: NAD21 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 98. 10ft above Mean Sea Level . SpE!ï'ï'Y-SUI! CAlL-LING seRVices A Halliburton Company Survey Ref: svy2114 Halliburton Sperry-Sun Survey Report for 1E-121 Your Ref: API 500292323800 Job No. AKZZ3458622, Surveyed: 24 January, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (·/100ft) 0.00 0.000 0.000 -98.70 0.00 0.00 N 0.00 E 5960559.83 N 549889.88 E 0.00 CB-GYRO-SS 112.00 0.500 140.000 13.30 112.00 0.37 S 0.31 E 5960559.46 N 549890.20 E 0.446 -0.20 168.00 0.500 152.000 69.30 168.00 0.78 S 0.59 E 5960559.06 N 549890.47 E 0.187 -0.44 261.00 0.200 285.000 162.30 261.00 1.09 S 0.62 E 5960558.74 N 549890.51 E 0.702 -0.71 352.00 0.700 125.000 253.29 351.99 1.37 S 0.92 E 5960558.46 N 549890.81 E 0.979 -0.83 MWD+IIFR+MS+SAG . 477.87 .2.860 53.410 379.10 477.80 0.06 N 4.07 E 5960559.92 N 549893.95 E 2.162 1.84 570.07 5.690 56.640 471.04 569.74 3.95 N 9.74 E 5960563.84 N 549899.59 E 3.079 7.82 661.75 5.560 55.710 562.28 660.98 8.95 N 17.20 E 5960568.89 N 549907.02 E 0.173 15.58 752.81 8.270 56.640 652.67 751.37 15.03 N 26.32 E 5960575.04 N 549916.10 E 2.979 25.05 837.34 9.060 57.230 736.23 834.93 21.98 N 36.99 E 5960582.05 N 549926.73 E 0.940 35.97 934.55 10.650 57.430 832.00 930.70 30.96 N 51.00 E 5960591.13 N 549940.67 E 1.636 50.18 1026.40 13.110 53.250 921.88 1020.58 41.76 N 66.50 E 5960602.03 N 549956.10 E 2.836 66.69 1128.34 16.610 49.880 1020.40 1119.10 58.07 N 86.91 E 5960618.48 N 549976.41 E 3.535 90.30 1220.52 18.350 48.370 1108.32 1207.02 76.20 N 107.84 E 5960636.75 N 549997.21 E 1.951 115.76 1312.33 23.790 49.900 1193.96 1292.66 97.75 N 132.82 E 5960658.46 N 550022.05 E 5.955 146.08 1405.32 30.830 48.360 1276.53 1375.23 125.70 N 165.02 E 5960686.62 N 550054.06 E 7.608 185.32 1498.29 34.930 46.650 1354.59 1453.29 159.81 N 202.19 E 5960720.98 N 550091.01 E 4.521 232.27 1590.90 34.160 47.540 1430.88 1529.58 195.57 N 240.65 E 5960756.99 N 550129.23 E 0.994 281.27 1684.47 36.020 46.250 1507.44 1606.14 232.33 N 279.91 E 5960794.01 N 550168.24 E 2.140 331.52 1775.58 35.700 47.060 1581.28 1679.98 268.96 N 318.73 E 5960830.90 N 550206.81 E 0.628 381.46 1868.47 36.050 45.610 1656.55 1755.25 306.55 N 358.10 E 5960868.75 N 550245.94 E 0.989 432.50 1962.90 35.840 46.520 1733.00 1831.70 345.01 N 398.02 E 5960907.47 N 550285.60 E 0.608 484.57 . 2055.98 35.750 46.330 1808.50 1907.20 382.54 N 437.46 E 5960945.26 N 550324.79 E 0.154 535.59 2146.87 35.510 45.870 1882.37 1981.07 419.25 N 475.61 E 5960982.23 N 550362.69 E 0.396 585.31 2240.74 35.260 45.900 1958.90 2057.60 457.09 N 514.63 E 5961020.32 N 550401.47 E 0.267 636.43 2332.89 37.630 46.890 2033.02 2131.72 494.83 N 554.28 E 5961058.33 N 550440.86 E 2.650 687.73 2426.75 37.200 48.590 2107.57 2206.27 533.18 N 596.48 E 5961096.96 N 550482.80 E 1.192 740.70 2519.97 36.870 46.800 2181.99 2280.69 570.96 N 638.00 E 5961135.02 N 550524.08 E 1.209 792.86 2612.83 37.410 46.880 2256.02 2354.72 609.31 N 678.90 E 5961173.64 N 550564.72 E 0.584 845.26 2752.54 36.970 47.050 2367.31 2466.01 666.95 N 740.62 E 5961231.68 N 550626.06 E 0.323 924.12 2847.59 35.930 47.480 2443.77 2542.47 705.27 N 782.10 E 5961270.28 N 550667.28 E 1.127 976.74 2941.01 35.010 48.430 2519.85 2618.55 741.58 N 822.35 E 5961306.85 N 550707.29 E 1.148 1027.02 3032.99 35.220 47.900 2595.09 2693.79 776.87 N 861.77 E 5961342.40 N 550746.47 E 0.402 1076.02 3126.78 37.040 50.130 2670.84 2769.54 813.11 N 903.52 E 5961378.92 N 550787.99 E 2.394 1126.90 3219.87 39.450 48.250 2743.95 2842.65 850.78 N 947.12 E 5961416.89 N 550831.33 E 2.875 1179.87 16 February, 2005 - 14:45 Page 20f6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 1E-121 Your Ref: API 500292323800 Job No. AKZZ3458622, Surveyed: 24 January, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 3313.21 40.900 49.110 2815.27 2913.97 890.54 N 992.34 E 5961456.94 N 550876.29 E 1.663 1235.42 3406.73 40.610 48.340 2886.11 2984.81 930.81 N 1038.23 E 5961497.51 N 550921.90 E 0.621 1291.73 3497.37 45.510 47.300 2952.32 3051.02 972.37 N 1084.05 E 5961539.38 N 550967.45 E 5.462 1349.18 3591.02 54.570 46.650 3012.40 3111.10 1021.31 N 1136.46 E 5961588.67 N 551019.53 E 9.689 1416.14 3684.43 59.540 46.260 3063.18 3161.88 1075.31 N 1193.25 E 5961643.04 N 551075.97 E 5.332 1489.57 . 3778.03 62.740 46.210 3108.36 3207.06 1132.00 N 1252.45 E 5961700.12 N 551134.78 E 3.419 1566.47 3871.44 65.850 44.930 3148.87 3247.57 1190.92 N 1312.53 E 5961759.44 N 551194.47 E 3.551 1645.77 3964.71 65.030 44.860 3187.64 3286.34 1251.02 N 1372.41 E 5961819.93 N 551253.95 E 0.882 1726.03 4058.25 64.130 44.310 3227.79 3326.49 1311.18 N 1431.71 E 5961880.49 N 551312.85 E 1.099 1806.11 4151.34 64.380 44.820 3268.22 3366.92 1370.92 N 1490.55 E 5961940.62 N 551371.29 E 0.562 1885.59 4247.55 64.940 45.380 3309.40 3408.10 1432.30 N 1552.14 E 5962002.40 N 551432.48 E 0.785 1967.76 4338.81 64.670 45.610 3348.25 3446.95 1490.18 N 1611.04 E 5962060.68 N 551490.98 E 0.374 2045.60 4432.34 65.410 44.640 3387.72 3486.42 1550.01 N 1671.12 E 5962120.90 N 551550.67 E 1.229 2125.71 4525.89 70.090 45.630 3423.13 3521.83 1611.06 N 1732.48 E 5962182.36 N 551611.62 E 5.098 2207.49 4620.45 74.900 46.590 3451.57 3550.27 1673.56 N 1797.46 E 5962245.29 N 551676.19 E 5.178 2292.14 4714.32 74.850 45.520 3476.06 3574.76 1736.44 N 1862.70 E 5962308.60 N 551741.01 E 1.102 2377.26 4807.48 74.880 43.880 3500.39 3599.09 1800.36 N 1925.96 E 5962372.94 N 551803.84 E 1.700 2462.44 4898.40 73.400 43.510 3525.23 3623.93 1863.60 N 1986.37 E 5962436.57 N 551863.83 E 1.674 2545.76 4993.88 76.340 43.990 3550.15 3648.85 1930.17 N 2050.11 E 5962503.57 N 551927.12 E 3.117 2633.53 5087.74 81.630 43.910 3568.08 3666.78 1996.47 N 2114.02 E 5962570.30 N 551990.60 E 5.637 2721.14 5179.15 81.450 42.910 3581.53 3680.23 2062.15 N 2176.16 E 5962636.39 N 552052.30 E 1.100 2807.42 5225.41 81.240 44.970 3588.49 3687.19 2095.08 N 2207.89 E 5962669.53 N 552083.81 E 4.426 2850.92 . 5285.43 78.870 43.490 3598.85 3697.55 2137.44 N 2249.13 E 5962712.16 N 552124.76 E 4.636 2907.07 5376.73 83.760 48.060 3612.64 3711.34 2200.33 N 2313.78 E 5962775.48 N 552189.00 E 7.291 2991.94 5470.17 89.080 46.860 3618.48 3717.18 2263.36 N 2382.47 E 5962838.96 N 552257.26 E 5.836 3078.70 5563.66 91.030 44.560 3618.39 3717.09 2328.64 N 2449.38 E 5962904.68 N 552323.74 E 3.225 3166.70 5657.16 89.780 40.400 3617.73 3716.43 2397.58 N 2512.51 E 5962974.04 N 552386.41 E 4.646 3256.34 5751.01 87.800 36.050 3619.71 3718.41 2471.27 N 2570.55 E 5963048.11 N 552443.96 E 5.091 3348.01 5844.38 86.140 33.460 3624.64 3723.34 2547.86 N 2623.69 E 5963125.06 N 552496.60 E 3.291 3440.16 5937.84 84.460 28.940 3632.31 3731.01 2627.51 N 2671.94 E 5963205.03 N 552544.31 E 5.144 3532.89 6031.33 87.400 26.960 3638.94 3737.64 2709.88 N 2715.63 E 5963287.68 N 552587.46 E 3.788 3626.08 6124.67 87.880 24.840 3642.78 3741.48 2793.76 N 2756.37 E 5963371.84 N 552627.64 E 2.327 3719.33 6218.08 88.870 20.480 3645.44 3744.14 2879.91 N 2792.33 E 5963458.22 N 552663.03 E 4.785 3812.52 6311.51 90.420 17.380 3646.01 3744.71 2968.27 N 2822.64 E 5963546.78 N 552692.74 E 3.709 3905.22 6405.14 90.780 15.900 3645.03 3743.73 3057.97 N 2849.45 E 5963636.65 N 552718.96 E 1.627 3997.60 16 February, 2005 -14:45 Page 3 of6 Drl/IQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 1E-121 Your Ref: API 500292323800 Job No. AKZZ3458622, Surveyed: 24 January, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 6498.39 91.830 15.070 3642.91 3741.61 3147.81 N 2874.33 E 5963726.66 N 552743.25 E 1.435 4089.26 6596.00 89.160 12.080 3642.07 3740.77 3242.67 N 2897.24 E 5963821.67 N 552765.52 E 4.106 4184.56 6685.24 85.880 10.820 3645.93 3744.63 3330.04 N 2914.94 E 5963909.15 N 552782.64 E 3.937 4270.84 6778.69 85.470 11.060 3652.97 3751.67 3421.53 N 2932.62 E 5964000.76 N 552799.72 E 0.508 4360.83 6873.00 89.500 14.740 3657.11 3755.81 3513.33 N 2953.65 E 5964092.70 N 552820.14 E 5.784 4452.56 . 6966.67 88.240 12.730 3658.96 3757.66 3604.30 N 2975.89 E 5964183.81 N 552841.77 E 2.532 4544.07 7060.37 87.380 13.760 3662.54 3761.24 3695.44 N 2997.34 E 5964275.09 N 552862.61 E 1.431 4635.39 7153.75 87.070 16.380 3667.06 3765.76 3785.50 N 3021.59 E 5964365.31 N 552886.26 E 2.822 4726.96 7247.04 89.370 17.630 3669.96 3768.66 3874.66 N 3048.85 E 5964454.65 N 552912.94 E 2.806 4819.05 7342.76 90.040 19.460 3670.45 3769.15 3965.40 N 3079.30 E 5964545.59 N 552942.78 E 2.036 4913.95 7439.10 91.090 13.930 3669.50 3768.20 4057.64 N 3106.96 E 5964638.01 N 552969.83 E 5.842 5008.98 7534.08 89.840 12.390 3668.73 3767.43 4150.11 N 3128.58 E 5964730.63 N 552990.84 E 2.088 5101.58 7630.54 90.660 12.140 3668.31 3767.01 4244.37 N 3149.07 E 5964825.02 N 553010.70 E 0.889 5195.28 7727.25 89.410 10.930 3668.25 3766.95 4339.12 N 3168.41 E 5964919.90 N 553029.41 E 1.799 5288.92 7824.02 89.850 11.590 3668.88 3767.58 4434.03 N 3187.31 E 5965014.93 N 553047.67 E 0.820 5382.50 7920.60 90.720 11.350 3668.40 3767.10 4528.68 N 3206.51 E 5965109.70 N 553066.25 E 0.934 5475.99 8017.08 90.530 11.780 3667.34 3766.04 4623.19 N 3225.85 E 5965204.34 N 553084.96 E 0.487 5569.42 8103.38 90.590 12.470 3666.50 3765.20 4707.56 N 3243.98 E 5965288.83 N 553102.53 E 0.803 5653.20 8210.61 89.660 13.450 3666.27 3764.97 4812.06 N 3268.03 E 5965393.48 N 553125.88 E 1.260 5757.66 8306.97 90.160 14.660 3666.42 3765.12 4905.53 N 3291.43 E 5965487.11 N 553148.66 E 1.359 5851.93 8403.76 88.860 11.120 3667.25 3765.95 4999.86 N 3313.01 E 5965581.58 N 553169.62 E 3.896 5946.18 8500.47 88.550 10.610 3669.43 3768.13 5094.81 N 3331.24 E 5965676.65 N 553187.21 E 0.617 6039.51 . 8596.91 88.620 9.270 3671.81 3770.51 5189.78 N 3347.88 E 5965771.72 N 553203.23 E 1.391 6132.15 8693.38 87.310 3.980 3675.24 3773.94 5285.50 N 3359.00 E 5965867.52 N 553213.71 E 5.646 6223.07 8789.60 89.240 6.000 3678.14 3776.84 5381.31 N 3367.37 E 5965963.38 N 553221.44 E 2.903 6312.84 8887.96 89.920 11.410 3678.86 3777.56 5478.49 N 3382.25 E 5966060.66 N 553235.67 E 5.543 6406.72 8983.20 90.720 15.100 3678.33 3777.03 5571.18 N 3404.08 E 5966153.49 N 553256.89 E 3.964 6499.59 9079.88 90.280 17.740 3677.48 3776.18 5663.90 N 3431.41 E 5966246.40 N 553283.60 E 2.768 6594.91 9176.52 90.720 18.730 3676.64 3775.34 5755.69 N 3461.64 E 5966338.38 N 553313.23 E 1.121 6690.66 9273.28 88.730 13.010 3677.11 3775.81 5848.71 N 3488.09 E 5966431.58 N 553339.06 E 6.259 6785.87 9371.09 89.550 13.080 3678.57 3777.27 5943.99 N 3510.17 E 5966527.00 N 553360.50 E 0.841 6881.18 9467.04 90.230 10.690 3678.76 3777.46 6037.87 N 3529.93 E 5966621.01 N 553379.63 E 2.590 6974.22 9563.62 90.040 15.260 3678.53 3777.23 6131.96N 3551.60 E 5966715.24 N 553400.69 E 4.736 7068.29 9660.33 89.660 16.260 3678.78 3777.48 6225.04 N 3577.87 E 5966808.49 N 553426.34 E 1.106 7163.46 9754.92 90.100 17.090 3678.98 3777.68 6315.65 N 3605.01 E 5966899.28 N 553452.88 E 0.993 7256.80 16 February, 2005 - 14:45 Page 4 of6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 1E-121 Your Ref: API 500292323800 Job No. AKZZ3458622, Surveyed: 24 January, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) 9851.57 89.170 15.700 3679.60 3778.30 6408.36 N 3632.29 E 5966992.17 N 553479.54 E 1.730 7352.09 9949.91 90.720 14.260 3679.69 3778.39 6503.35 N 3657.71 E 5967087.33 N 553504.32 E 2.151 7448.61 10047.54 91.520 15.470 3677.78 3776.48 6597.70 N 3682.75 E 5967181.84 N 553528.74 E 1.486 7544.38 10137.98 90.830 14.500 3675.93 3774.63 6685.04 N 3706.13 E 5967269.33 N 553551.54 E 1.316 7633.13 10234.81 91.150 14.470 3674.26 3772.96 6778.78 N 3730.35 E 5967363.23 N 553575.13 E 0.332 7728.00 . 10334.99 91.270 13.680 3672.14 3770.84 6875.93 N 3754.70 E 5967460.54 N 553598.84 E 0.797 7826.00 10430.48 91.830 13.890 3669.56 3768.26 6968.63 N 3777.45 E 5967553.39 N 553620.97 E 0.626 7919.29 10523.52 92.700 14.810 3665.88 3764.58 7058.70 N 3800.49 E 5967643.61 N 553643.41 E 1.360 8010.34 10617.55 92.140 14.950 3661.91 3760.61 7149.49 N 3824.61 E 5967734.56 N 553666.93 E 0.614 8102.52 10711.52 91.760 16.030 3658.71 3757.41 7240.00 N 3849.70 E 5967825.23 N 553691.41 E 1.218 8194.86 10805.64 91.210 16.000 3656.27 3754.97 7330.43 N 3875.65 E 5967915.84 N 553716.77 E 0.585 8287.52 10899.31 91.150 16.930 3654.34 3753.04 7420.24 N 3902.20 E 5968005.82 N 553742.72 E 0.995 8379.88 10993.35 89.780 15.050 3653.58 3752.28 7510.63 N 3928.10 E 5968096.38 N 553768.02 E 2.474 8472.48 11082.01 90.720 15.540 3653.19 3751.89 7596.15 N 3951.49 E 5968182.05 N 553790.84 E 1.196 8559.59 11172.80 90.470 14.040 3652.25 3750.95 7683.93 N 3974.66 E 5968269.98 N 553813.43 E 1.675 8648.64 11265.39 89.350 15.630 3652.40 3751.10 7773.43 N 3998.37 E 5968359.64 N 553836.54 E 2.100 8739.48 11354.94 91.160 17.560 3652.00 3750.70 7859.24 N 4023.94 E 5968445.61 N 553861.54 E 2.955 8827.81 11447.13 90.780 16.960 3650.44 3749.14 7947.26 N 4051.29 E 5968533.82 N 553888.31 E 0.770 8918.92 11538.62 91.210 18.200 3648.85 3747.55 8034.46 N 4078.92 E 5968621.20 N 553915.35 E 1.434 9009.41 11629.08 93.310 18.190 3645.28 3743.98 8120.33 N 4107.14E 5968707.25 N 553943.01 E 2.321 9098.96 11719.84 92.130 15.920 3640.97 3739.67 8206.99 N 4133.72 E 5968794.09 N 553969.02 E 2.816 9188.50 11810.26 91.330 14.640 3638.24 3736.94 8294.18 N 4157.54 E 5968881.43 N 553992.25 E 1.669 9277.30 . 11901.01 91.020 15.280 3636.38 3735.08 8381.83 N 4180.96 E 5968969.24 N 554015.09 E 0.783 9366.35 11984.69 92.890 14.660 3633.53 3732.23 8462.62 N 4202.57 E 5969050.17 N 554036.16 E 2.354 9448.44 12078.00 91.320 15.790 3630.10 3728.80 8552.59 N 4227.05 E 5969140.30 N 554060.05 E 2.073 9540.03 12175.06 87.860 15.430 3630.80 3729.50 8646.05 N 4253.17 E 5969233.93 N 554085.54 E 3.584 9635.49 12264.19 87.000 15.630 3634.79 3733.49 8731.84 N 4277.01 E 5969319.88 N 554108.81 E 0.991 9723.04 12354.91 86.640 15.950 3639.82 3738.52 8819.00 N 4301.65 E 5969407.20 N 554132.88 E 0.531 9812.19 12378.93 86.330 15.840 3641.30 3740.00 8842.06 N 4308.22 E 5969430.30 N 554139.29 E 1.369 9835.79 '" 12415.00 86.330 15.840 3643.61 3742.31 8876.69 N 4318.04 E 5969465.00 N 554148.88 E 0.000 9871.22 Projected Survey All data is in Feet (US Survey) unless othelWise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 26.000" (True). 16 February, 2005 - 14:45 Page 50f6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 1E-121 Your Ref: API 500292323800 Job No. AKZZ3458622, Surveyed: 24 January, 2005 ConocoPhillips Western North Slope Based upon Minimum Curvature type calculations, at a Measured Depth of 12415.00ft., The Bottom Hole Displacement is 9871.23ft., in the Direction of 25.940· (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment . .; 12415.00 3742.31 8876.69 N 4318.04 E Projected Survey Survey tool program for 1E-121 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 352.00 0.00 352.00 351.99 12415.00 351.99 CB-GYRO-SS 3742.31 MWD+IIFR+MS+SAG . 16 February, 2005 - 14:45 Page 60f6 DrillQuest 3.03.06.008 . ~~!Æ~E ([ F l~JL~~~] . ~"/ASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 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-121 ConocoPhillips Alaska, Inc. Permit No: 204-246 Surface Location: 4307' FNL, 630 FEL, T11N, RlOE, UM Bottomhole Location: 710' FNL, 1591' FEL, SEC. 10, TIIN, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the commiSSi~n.. t witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 60 er). (3i ,Y DATED thist6day of December, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoc~hillips Alaska - Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com RECEIVED DEC 1 42004 Alaska Oil & Gas Coos. commission Anchorage December 9,2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1E-121 and 1E-12111 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a multilateral horizontal well in the West Sak "6" and "D" sands. The main bore of the well will be designated 1E-121 ("6" sand), and the lateral bore of the well will be designated 1E-12111 ("D" Sand). Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1E-121 is 12/28/2004. If you have any questions or require any further information, please contact Steve Shultz at 263-4620. Sincerely, ~t~- Randy Thomas Greater Kuparuk Area Drilling Team Leader Alaska Oil & Gas Cons, Commissíon ExploratoryU Development Oil ~ Ancho_le Zone D Service D Development Gas D Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-121 6. Proposed Depth: 12. Field/Pool(s): MD: 12426" TVD: 3709' Kuparuk River Field 2341' FNL, 3803' FEL, Sec. 15, T11N, R10E, UM' Total Depth: 710' FNL, 1591' FEL, Sec. 10, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): !i9'D~'t> / b"D. ,[ 10. KB Elevation " 12,· ¡'i)·tiT Surface: x- 549890 y- ~ Zone- 4 (Height above GL): 28 feet Well within Pool: 1E-08, 27.5' @ 550' 16. Deviated wells: 17. Antìcipated Pressure (see 20 MC 25.035) " Kickoff depth: 300 ft. Maximum Hole Angle: 90.80 Max. Downhole Pressure: 1634 psig" I Max. Surface Pressure: 1235 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20" 94# K-55 Welded 120' 28' 28' 120' 120' 260 cf ArcticCrete 10.75" 45.5# L-80 BTC 2622' 28' 28' 2650' 2395' 470 sx AS Lite, 180 sx DeepCrete 7-5/8" 29.7# L-80 BTCM 5057' 28' 28' 5085' 3661' 300 sx DeepCrete 4.5" 12.6# L-80 BTM 7526' 4900' 3619' 12426' 3709' slotted liner (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Cement Volume MD TVD . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill 0 Re-entry D RedrillU 1b. Current Well Class: Stratigraphic Test D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): SUrface~~L~FEL, Sec. 16, T11N, R10E, UM Top of Productive Horizon: 41> rz..·¡Ç'·cf 7. Property Designati~n: ALK 25651 & 25648 8. Land Use Permit: ADL 469 & 466 9. Acres in Property: 2560 Hole 40" 13.5" 9-7/8" 6.75" 19 Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) Casing Structu ral Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Length Size Perforation Depth TVD (ft): Drilling Program 0 Tirnev. Depth PlotU Seabed Report D Drilling Fluid Program [;2] Date: 20. Attachments: Filing Fee 0 Property Plat D BOP Sketch U Diverter Sketch D 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randy Thomas Signature ~ \~,. Ree~IV~~ç DEC 1 4 ¿tfU4 West Sak Pool 13. Approximate Spud Date: 12/28/2004 14. Distance to Nearest Property: 4643' 15. Distance to Nearest Shallow Hazard Analysis D 20 AAC 25.050 requirements 0 Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team Leader Phone ~ S-&-ß ~ Date (t-fcor /"00/ Prepared bv Sharon Allsup-Drake Conditions of approval : Commission Use Only I API Number: Permit Approval 50-02.9- 2.323S -DO Date: Samples required DYes Lg No ydr gen sulfide measures D Yes ~NO '-3"'"'\... ~ \>~\-.~~Y·~ ~ "" ~\,)'" ~ ~~. Permit to Drill Number: 2C> 1- 2. 'ib Mud log required Directional survey required COMMISSIONER BY ORDER OF THE COMMISSION RtGtNAL Isee cover letter for other requirements DYes 00 No 00 Yes D No OOV \<'? ~\~~~ \'==.. \1-\ D", '0,(ð<£ Submit in duplicate · .tion for Permit to Drill, Well 1 E-121 Revision No.O December 9,2004 Permit It - West Sak Well #1 E-121 ("B" Sand) Application for Permit to Drill Document Mo:)ximize W.,II VQlue 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. Drill ing Hazards Information .............. ................ ............ ............ .......... ................... 3 Requirements of 20 AAC 25.005 (c)(4) ................................. ......... .......... .............................................. 3 5. Procedure for Conducting Formation Integrity Tests........................................... 3 Requirements of 20 AAC 25.005 (c)(5).... .............................................. ......................................... ....... 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25. 005(c)(6) .. .... ......................................... ..................... ............................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25. 005(c)(7) .... .................. ................ .......................... ..... ....... ........... ............ 4 8. Drilling Fluid Program ......... ............... .............. ............ ......... ............ .............. ........ 5 Requirements of 20 AAC 25. 005(c)(8)............... ................. ................................. ....... ..... ........... ........... 5 Lateral Mud Program (MI FloPro NT)............................ ................................ ....... ........ ............... ........... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9)......... .......... ........ .................................................... ................... 5 10. Seismic Analysis ............ ........... ............ .............. ............. ........... .......... .................. 5 Requirements of 20 AAC 25.005 (c)(10) .......................... ......... ....... .......................... ....... ......... ............ 5 11. Seabed Condition ..Analysis................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ............. ..................................... ....... ............ .... ....................... 5 12. Evidence of Bondi ng .......... ............... .............. ............. ......... ............ ...................... 5 Requirements of 20 AAC 25.005 (c)(12)................ ...................................................... .... ............ .......... 5 OR~GINAL 1E-121 Producer "B" Lateral Page 1 of7 Printed: December 9, 2004 . A&tion for Permit to Drill, Well1E-121 . ... Revision No.O December 9, 2004 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) .... ...................... ................................. ............ ............... .......... 6 14. Discussion of Mud and Cuttings Disposal and Annular DisposaL..................... 7 Requirements of 20 AAC 25.005 (c)(14)... ......................... ..... ........... .......................... ......... ...... ........... 7 15. Attachments .......... ............... ............... .............. .............. ........ .............. .............. ..... 7 Attachment 1 Directional Plan................................................................................................................ 7 Attachment 2 Drilling Hazards Summary ............................................................................................... 7 Attachment 3 Cementing Data............................................................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 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 the commission under 20 MC 2S.040(b). For a well with multiple well branché'~ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the we,~ by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as lE-121. 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 governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic SUlvey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objectiw: formation and at total depth; Location at Surface ASP Zone 4 NAD 27 Coordinates Northings: 5,959,760 Eastings: 549,890 FNL: 5107', FEL: 637', Sec. 16, TllNjRl0E UM I RKB Elevation I 98.7' AMSL Pad Elevation 70.7' AMSL Location at Top of Productive Interval (West Sak "8" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,962,540 Eastings: 551,979 FNL: 2341', FEL:3803', Sec. 15, TllNjRl0E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 5083' 3661' 3562' Location at Total Depth of I the West Sak "8" Sand ASP Zone 4 NAD 27 Coordinates Northings: 5,969,465 Eastings: 554,130 FNL: 710', FEL: 1591', See 10, TllNjRl0E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 12426' 3709' 3610' and (D) other information required by 20 MC 25.0S0(b); OF~IGINAL 1E-121 Producer "B" Lateral Page 2 of 7 Printed: December 9, 2004 · A.tion for Permit to Drill, We1l1E-121 Revision No.O December 9, 2004 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a P,~rmit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed well bore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records; and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items; except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 MC 25.036; or 20 MC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete weIl1E-121. Due to the reduced formation pressures seen at West Sak, CPAI would like to utilize a 5,000 psi BOP system but operate the stack under the 3000 psi rating giving CPAI the opportunity to utilize one ram cavity for the 7 5/8" casi'!9 rams, thereby reducing the times the rams would have to be openedãñ'ëiì-etested. "' J 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 ha2"éJrds; including (A) the maximum downho¡'~ pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methéme gradient,· The expected reservoir pressures in the West Sak sands in the 1E-121 area average 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1235 psi, calculated thusly: "' MPSP =(3632 ft)(0.45 - 0.11 psi/ft) =1235 psi . (B) data on potential gas zon<~s; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormall)' geo-pressured strata, lost circulation zones; and zones that have a propensity for diñ"erential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the (¡ ¡lIowing items; except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests. as required under 20 MC 25. 030(f); o RIG I r~ A L 1E-121 Producer "B" Lateral Page 3 of 7 Printed: December 9, 2004 · A.tion for Permit to Drill, Well 1 E-121 Revision No.O December 9, 2004 The parent wellbore,lE-121, will be completed with 7 5/8" intermediate casing landed in the West Sak B- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program so A chment 3, APD for lE-121: Ceme!}!..---L Summary --......-.- Hole ~~ Top Btm CsgfTbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lblft) Grade Connection (ft) (ft) (ft) Cement Program 20 40" 94# K55 Welded 120 28 / 28 120 / 120 Cemented to surface with 260d ArcticCRETE 10 314" 13 1/2" 45.5# L-80 Buttress 2622' 28 / 28 2650 / 2395 Cemented to Surface with 470 sx ASLite Lead, 180 sx DeepCRETE Tail 7 5/8" 9 7/8" 27.9# L-80 BTM 5057' 28 / 28 5085/ 3661 Cement Top planned @ 2,700' MD / 2435' TVD. Cemented w/ 300 sx DeepCRETE 41/2" 6314" 12.6# L-80 BTM 7476' 4650 / 3633 12426 / Slotted- no slotted "B" Lateral 3709 cement lE-121 ~ -- 4 V2" 6~ 12.6# L-80 BTM 7719' 4900/36Th--- 12419/ 510 slotted "D" Lateral 3647 cement lE-121 L1 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description ofthe diverter system as requir.~d by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); A 21-1/4",2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of lE-121. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 1E-121 Producer "B" Lateral Page 4 of 7 Printed: December 9, 2004 FçlGINAL · Aetion for Permit to Drill, Well 1 E-121 Revision No.O December 9, 2004 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 items, 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 mud having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Properties Surface Intermediate Production Density (ppg) 8.9-9.2 9.0-9.1 9.0 -' Funnel Viscosity 150-250 45-60 NA (seconds) Yield Point 50-70 26-35 18-28 (cP) Plastic Viscosity 15-20 12-18 15-25 Chlorides (mg/l) pH API filtrate (cc / 30 min) **HTHP filtrate (cc /30 min) MBT (Ib / gal) NA <20 NA Electrical Stability NA NA 650-900 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test welt a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f}; <500 8.5-9.0 5-7 <500 9.0-9.5 4-6 NA NA <4 <10 <10 <10 Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test welt 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. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vesset an analysis of seabed conditions as required by 20 MC 25.061 (b); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: IGINAL 1E-121 Producer "B" Lateral Page 5 of 7 Printed: December 9, 2004 · Aetion for Permit to Drill, Well 1 E-121 Revision No.O December 9, 2004 (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items; except for an item already on file with the commission and identified in the application: The proposed drilling program for 1E-121 is listed below. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 120' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 13 1/2" hole to casing point at +/- 2650' MD /2395' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 103/4",45.5#, L-80, BTC casing to surface. Displace cement with mud and, pressure test casing to 3000 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 3500 psi (annular preventer to 1500 psi) Notify AOGCC 24 hrs before test. / 6. PU 9 7/8" bit and drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 7 5/8" casing point at 5085' MD /3661' TVD. 9. Run 75/8",29.7# L-80, BTCM Mod casing to surface. Pump cement and displace with mud and pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead 75/8" packoff and test to 5000 psi. 11. Flush 103/4" x 7 5/8" annulus with water, followed by diesel. .- 12. PU 6 3/4" Bit and drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform leak <'7 off test, recording results. ~ "'~ 14. Directionally drill 6 3/4" hole to TD at +/- 12426' MD / 3709' TVD as per directional plan. ./ ~«-~ 15. POOH, back reaming out of lateral. POOH. ~ 16. PU and run 4 1/2" slotted liner. ~. 17. Land liner, set liner hanger POOH. -, + Note: Remaining operations are covered under the lE-121L1 Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of 4776' MD /3587' TVD, the top of the "D" sand. 19. Mill 6 3/4" window. POOH. 20. Pick up drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of "D" sand lateral at 12,419' MD /3647' TVD, as per directional plan. 22. POOH, back reaming out of lateral. POOH. OF<fGINAL 1E-121 Producer "8" Lateral Page 6 of 7 Printed: December 9, 2004 · Aetion for Permit to Drill, Well 1 E-121 Revision No.O December 9, 2004 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4 1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool, POOH 27. POOH and lay down drill pipe 28. RU and run 4 V2" tubing completion with ESP artificial lift 29. Nipple down BOPE, nipple up tree and test 30. Freeze protect well with diesel by pumping into 4 1/2" x 7 5/8" annulus, taking returns from tubing (diesel all the way around). Install BPV 31. RDMO Doyon 141 32. Place well on production. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25. 080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling them to the Prudhoe Bay ,/ Grind and Inject Facility or to 1R pad in accordance with regulations from the State of Alaska. 14. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cementing Data Attachment 4 Well Schematic ()f<IGINAL 1E-121 Producer "B" Lateral Page 7 of 7 Printed: December 9, 2004 · . lE-121 Drillina Hazards Summary 13 1/2" Open Hole /10 3/4" Casina Interval Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Hole swabbing on trips Risk Level Low Low / Moderate Moderate Mitigation Strategy Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Dri Itreat. Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Trip speeds, Proper hole filling (use of trip sheets), pumping out 9 7/8" Open Hole / 7 5/8" Casina Interval Hazard Running Sands and Gravels Stuck Pipe Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Risk Level Moderate Low Low / Low Moderate Mitigation Strategy Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, Decreased mud weight BOP training and drills, increased mud weight. Reduced pump rates, mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), pumping out 63/4" Open Hole / 4 1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Lost Circulation Hole Swabbing on Trips Risk Level Low / Low Moderate Low Mitigation Strategy Stripping drills, Shut-in drills, Increased mud weight. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weight Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out 1E-121 Drilling Hazards Summary prepared by Steve Shultz 9/1/2004 4:27 PM ORIGiNAL Producer 1E-121 KOP: 300' Build at 3-5 degrees/100' . Top of Ugnu ./ 3243MD 2921~.' Top of Cement 2700" MD Slimhole Design 131/2" Hole (8.8 ppg Spud Mud) 10 3/4" Casing . Tangent Angle: 65 degrees Hydraulics: Surface: 700-900 gpm Intermediate: 600-700 gpm Laterals: 250-300 gpm Figure on a 50 YP for surface Figure on a 35 YP for intermediate Figure on a 28 YP for laterals liD" Sand (9.0 ppg Oil Base Mud) Window @ 4776'MD 6 3/4" Hole 3587'TVD 41/2" Line 12419' MD 3647' TVD 9 7/8" Hole (9.0 ppg LSND) 7 5/8" Casing 5085' MD 3661' TVD It,,,,,, ç> ~ c-M\-\-" ~ "B" Sand (9.0 ppg Oil Base Mud) 6 3/4" Hole 4 1/2" Liner ~ ,-.J « :z - (!) - CJ::: o ./ 12,426' MD 3709' 'TVD . 1 E-121 . Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 11/30/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 108' MD < Base of Permafrost at 1,558' MD (1,501' TVD) < Top of Tail at 1,850' MD < 103/4",45.5# casing in 131/2" OH TO at 2,650' MD (2,395' TVD) Mark of Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. ScblllbøPl8P Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 1,850' MD. Lead Slurry Minimum pump time: 200 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 3 0.6381 fi 1ft x (108') x 1.00 (no excess) = 3 0.3637 fi 1ft x (1558' - 108') x 3.50 (250% excess) = 0.3637 fi31ft x (1850' - 1558') x 1.35 (35% excess) = 68.9 fi3 + 1845.8 fi3 + 143.4 fi3 = 2058.1 fi3 14.45 fi3/sk = Round up tõ47õ sks 68.9 fi3 1845.8 fi3 143.4 fi3 2058.1 fi3 462.5 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 150 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.3637 fi3/ft x (2650' - 1850') x 1.35 (35% excess) = 0.5400 fi3/ft x 80' JShoe Joint) = 392.8 fi3 + 43.2 fi = 436 fi31 2.52 fi3/sk = Round up to '180 sks 392.8 ft3 43.2 fi3 436 fi3 173 sks BHST = 48°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume (bbl) 10.0 0.0 40.0 50.0 0.0 380.6 77.7 0.0 20.0 0.0 218.2 9.0 CW100 Pause CW100 MUDPUSH II Pause ASL DeepCRETE Pause Water Pause Mud Mud 5.0 0.0 5.0 6.0 0.0 7.0 5.0 0.0 5.0 0.0 7.0 3.0 MUD REMOVAL Stage Time (min) 2.0 10.0 8.0 8.3 5.0 54.4 15.5 5.0 4.0 5.0 31.2 3.0 Recommended Mud Properties: 9.1 ppg, Pv < 30, Ty < 40. Cumulative Time (min) 2.0 12.0 20.0 28.3 33.3 87.7 103.2 108.2 112.2 117.2 148.4 151.4 Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 17-21, Ty ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ¡ ~... Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 11/30/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 103/4",45.5# casing at 2,650' MD . . 1E-121 Scblulb8Pg8J1 Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 543' MD above Ugnu C - (2400' MD annular length). Tail Slurry Minimum thickening time: 160 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 3 0.2148 ft fft x 2400' x 1.25 (25% excess) = 0.2578 ft3fft x 80' (Shoe Joint) = 644.4 ft3 + 20.6 ft3 = 665.0 ft3f 2.26 ft3fsk = Round up to 300 sks 644.4 ft3 20.6 ft3 665.0 ft3 294.2sks BHST = 81°F, Estimated BHCT = 70°F. (BHST calculated using a gradient of 2.6°Ff100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Time Cumulative Stage Rate Volume . Time (bpm) (bbl) (mm) ( . ) mm CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 30.0 6.0 18.0 Drop bottom plug 0.0 0.0 5.0 23.0 MUDPUSH 1/ 6.0 40.0 6.7 29.7 DeepCRETE 6.0 118.4 19.7 49.4 < Top of Tail at Drop top plug 0.0 0.0 5.0 54.4 2,700' MD Mud 7.0 221.5 31.6 86.0 Slow & bump plug 3.0 9.0 3.0 89.0 < 7 5/8", 29.7# casing in 97/8" OH TD at 5,100' MD (3,663' TVD) MUD REMOVAL Recommended Mud Properties: 9.0 ppg, Pv < 15, Ty < 15. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 20-24, Ty = 25-28 Centralizers: Recommend 1 per joint from shoe track to K-13 @ 4200' ORIGINAL ~ ;; 5250 o 1.0 '<- '-' Kuparuk Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method; Elliptical Conic Error Surface; Rules Based Warning Method: Trav. Cylinder North 9750 -T . .-, ¡ -~! " ¡ I, ¡ I ,: ~ , 1 : . . ' ' , . . - i - ! - - i , - - , : ¡ - - ¡ - - -' - - , - f"j , , : : . 1E-121 WS 8 Lat t 6 ¡ . ¡ : ¡ 1E-121 WS 8 Lat Pì - . - - - : . I .' . - I· . , ! = , i 1E-121 WS 8 Laì Pì4 . . - , - - ! ¡U i . ' ' I - iE-121 WS 8 Lat Pt - - , ' - . - ¡ : 1E-121 WS BLat n '" ", - . · I, ,I ,i+;; . I - - I 121 WS 8 Lat I , I' . jE-121 WS BLat nw, . .. : - - ~ - - - . . - ¡ I , , ¡ I ' , , I, I ¡ , , ( ! ! ! ! i Î I f , , I ! ! 1 ! ! i ì , I ìI ¡ I I , , , 9000 8250 7500 6750 6000 3000 2250 1500 750 o -750 -3000 -2250 -1500 -750 750 1500 2250 4500 6000 6750 3000 3750 5250 West(-)Æast(+) (1500 ftlìn) SP=B -i ...sun A HALLI-BlIRl'Q.!\'. (J.l\WA!\~ Engineering Error System: Calculation Method: Scan Method: Error Surfaca: W<:¡rning Method: Kuparuk Minimum Curvature ISCWSA Trav. Cylind¡;w North Elliptical Conic Rules Based . . Halliburton Company Anticollision Report '." Co.ordinat~~.E) Referen.ce: Vertical (TVD) Reference: if Company: Field: ." Reference Site: Reference Well: Réference Wellpath: 'ConocoÞhillips Alaska Inc. Kuparuk River Unit Kuparuk 1 E Pad Plan lE-121 Plan: tE-121 Date: 12/3/2004 GLOBAL SCAN APPLIED: All weDpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 100.000 ft Depth Range: 28.000 to 12426.329 ft Maximum Radius: 1439.833 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 11/9/2004 Validated: No Planned From To Survey ft ft 28.000 800.000 800.000 12426.329 Version: 3 Toolcode Tool Name Planned: Plan: 1E-121 BLat (wp06) V12 Planned: Plan: 1E-121 Blat (wp06) V12 CB-GYRO-SS MWD Camera based gyro single shot - Used in Preference MWD - Standard - Used in Preference Casing Points MD TVD Diam~ter Hille S~" ft ft 1n in 2650.874 2395.700 10.750 13.500 10 3/4" 4900.000 3618.689 7.625 9.625 75/8" 12426.329 3708.700 4.500 6.750 41/2 Summary Offset Wellpath - > Refere.nce Offset . . Ctr-Ctr«No-Go ~IIWable Site WeD WeUpath MD MD DistanceA~ea Deviation ft ft ft ft ft Kuparuk 1 B Pad 1 B-07 1 B-07 V1 10429.081 5800.000 1102.581 324.311 778.269 Pass: Major Risk Kuparuk 1 B Pad 1 B-08 1 B-08 V1 11615.953 5500.000 1203.990345.043 858.947 Pass: Major Risk Kuparuk 1 B Pad 1 B-08A 1 B-08A V1 11616.916 5500.000 1204.236344.941 859.296 Pass: Major Risk Kuparuk 1 B Pad 1B-101 1B-101 V1 12376.026 6100.000 456.421 358.915 97.506 Pass: Major Risk Kuparuk 1 B Pad 1 B-1 01 1B-101L1 V1 12376.026 6100.000 456.421 358.915 97.506 Pass: Major Risk Kuparuk 1 B Pad 1B-102 1B-102V1 Out of range Kuparuk 1 E Pad 1 E-05 1 E-05 V1 1049.836 1100.000 299.218 19.181 280.037 Pass: Major Risk Kuparuk 1 E Pad 1 E-06 1 E-06 V1 688.543 700.000 197.614 12.279 185.335 Pass: Major Risk Kuparuk 1 E Pad 1 E-07 1 E-07 V1 1782.194 1800.000 71.235 43.112 28.123 Pass: Major Risk Kuparuk 1 E Pad 1 E-08 1 E-08 V5 894.353 900.000 27.468 15.461 12.007 Pass: Major Risk Kuparuk 1 E Pad 1 E-09 1E-09V1 690.275 700.000 262.238 11.620 250.618 Pass: Major Risk Kuparuk 1 E Pad 1E-10 1E-10 V1 687.433 700.000 191.076 13.128 177.948 Pass: Major Risk Kuparuk 1 E Pad 1 E-11 1E-11V1 592.979 600.000 186.629 11.344 175.286 Pass: Major Risk Kuparuk 1 E Pad 1 E-12 1E-12V1 592.992 600.000 246.028 1 0.438 235.590 Pass: Major Risk Kuparuk 1 E Pad 1E-123 1E-123 V2 199.996 200.000 40.403 3.752 36.652 Pass: Major Risk Kuparuk 1 E Pad 1E-123 1E-123L 1 V2 199.996 200.000 40.403 3.752 36.652 Pass: Major Risk Kuparuk 1 E Pad 1E-123 1E-123PB1 V1 199.996 200.000 40.403 3.752 36.652 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1E-126V1 399.625 400.000 122.484 7.301 115.183 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1E-126L 1 V1 399.625 400.000 122.484 7.301 115.183 Pass: Major Risk Kuparuk 1 E Pad 1 E-126 1 E-126L2 V1 399.625 400.000 122.484 7.457 115.027 Pass: Major Risk Kuparuk 1 E Pad 1E-18 1E-18V1 3341.173 3600.000 364.956 59.204 305.752 Pass: Major Risk Kuparuk 1 E Pad 1 E-36 1 E-36 V3 286.191 300.000 187.990 4.991 182.998 Pass: Major Risk Kuparuk 1 E Pad Plan 1E-121 Plan: 1E-121 L 1 V3 Pia 28.000 28.000 0.000 0.975 -0.975 FAIL: Minor 1/10 Kuparuk 1 E Pad Plan: 1E-102 1 E-1 02 B Lateral V8 PI 2338.807 2400.000 331.115 52.974 278.141 Pass: Major Risk Kuparuk 1 E Pad Plan: 1E-102 1 E-1 02 D lateral V3 PI 2338.807 2400.000 331.115 52.823 278.292 Pass: Major Risk Site: Kuparuk 1 B Pad Well: 1 B-07 Rule Assigned: Major Risk WeDpath: 1B-07 V1 Inter-Site Error: 0.000 ft ~í:ferenCei MD' tv]) ft ft 10646.156 3734.655 10619.459 3735.044 10590.786 3735.462 10558.883 3735.927 10526.877 3736.394 Offset Semi-Major Axis Ctr-Ctr No"Go AUowab~ MD TVD Ref Offset TFO+AZI TFO-HS CasingIHS>istance Area Deviatiøn ft ft ft ft deg deg inft ft ft 5100.000 3956.252110.412 16.560275.531 260.612 1387.394373.797 1013.597 5200.000 4020.196 110.027 16.860272.314 257.395 1328.390371.372 957.018 5300.000 4083.820 109.614 17.274268.832 253.913 1274.301 367.976 906.325 5400.000 4147.091109.154 17.715265.091 250.172 1226.130363.161 862.969 5500.000 4210.024108.693 18.152261.072 246.153 1183.231356.712 826.519 Pass Pass Pass Pass Pass 10495.141 3736.857 5600.000 4273.800108.236 10462.624 3737.331 5700.000 4338.911 107.768 10429.081 3737.820 5800.000 4404.517 107.285 18.452256.751 241.832 18.702252.167 237.248 19.046247.402 232.483 1147.529348.005 799.524 1120.785337.061 783.725 1102.581 324.311 778.269 Pass Pass Pass ORIGINAL . ConocriP'hillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-121 Plan: 1E-121 Plan: 1E-121 (wp06) Standard Planning Report 02 December, 2004 . SpElr'r'y-sun DRII-L.I.NG SERVICE. A HALLlftUR'JQN COW-ANY ORIGINAL o o I{) .- ~ i " - ..--------------J ~.. ·y-sun P-FHJ-:LfNG S¡¡e"VH::~ West(-)/East(+) (1500 Win) 1500 2250 3000 I ! ! " ! I 9000 8250 WELL OETAILS: I"¡an 1E-121 (wpOO) 6750 Ground Level: 10.7' +NJ-S +EJMW Northing Eastìng latittude longitude 0.000 0.000 5960559.830 549889.880 70"18'10.886N 149"35'45.192W Slot 1E-12' 6000 = I Begin Build @ 5"110Oft (4478' MD & REFERENCE INFORMATION 5250- Co--ordinate (NJE) Reference: W-eU Pian 1E~il1(wp06J , Twe !\16ftI'! Vertical (TIIO) Reference: 1E-121 @ 98.7000 (1E-212) Section (VS) Reference: Slot - (o.oOON, O.OOOE) Mea.ured Oepth Reference (RKS): 1E-121 @98.7_(1E-212) Calculatîon Method: MinÎmum Curvature 4500 3750 3000 2250 I ~~tl,",&L(""IMO&'Msruol ~ ~::: /~ ___~~r I i ?~ "_œe"""'O"OO'T"M"T~I' ~ I Increase i"ild to 4"110, (933' MD & 932' TVD) I IBegin Build @ 3"1100 It (600'MD, 600' TVD) I ¡ ¡ j ¡ I I ¡ ¡ ! ¡ 4500 I Begin Build & RH turn @ 5"110Oft 1500 750 0- ! I I I I I f I I j ! I I I I I I ! I ! I I ¡ ! I I I ¡ I ! I I ¡ ! ¡ f I I ! I ! ! I I I I I I ! I I I ! I ! I I I I I I ! I -4500 -3750 -3000 -2250 -1500 -750 o 750 1500 2250 3000 3750 5250 6000 6750 7500 8250 West( - )/East( +) ( 1500 Win) ,_ !:<At~!II"Im)J>' '::I>MI''''~">.' 9000 8250 7500 ";-'-6000 (f) o ~5250 c: ~ Z o -- -4500 50 1: ~ 01 o 3750 0 ë!' 2: 1500 750 o -1250 -625 -625 I ¡ Iii I I I ,I i II l..v - -", -, 0 -", ' - ' - -- 625 - - - I - 1250 ~¿ -7 ~¿r- ~ 1875 -L:::::/ c: ~ -- 0 - " \0 '" -- J:: êí ( ) o ro () '55 3125 > ( ) ::> ~ /' - ~_/ gf¡~:- Al -~~,- ,.;;;;~-' 3750-4:: -", -- - 4375 5625 - -1250 -625 o 625 1250 ! ~", p,iJ^,L ! 1875 I ! ! ! " -- ~ :--- --- :-- ~ ---- --- ¡~ ---- ----- - - -" , ' . -, ¡, ~.- ;:::: :~; r:~ , /' o 625 1250 1875 ----------l Vertìæl Section at 26.00° (1250 ftlin) 3125 3750 4375 5000 5625 6250 6875 ,J i I I i II I r ! I J I I I i I I"M'~ Build ¡g 3'/100 ft 600' TH"" I ,; Build to 4'/100ft (933' MD & 932' n",d 'r:' ¡ ¡, :m- " .1 i i i I Iii i i I I I Ii .-- --= l'nNP~oP BUild to 5'/100ft (1191' MD & 1180' i I i III I I ",' ¡Begin Sail @ 35' Ine & 48' Azi (1491' MD & 1446' .l-.-+---tIT ---- r -11 T Tir I' I i I I I I I Ii, -, """ ,;u¡ I~Qo."" I I ,.L--+---'r I I I I ;n~~'~t:r~~l' ¡ I I I I I I- I Þr=¡!!JLI I I ¡ I I I I I L _ir:~~itEegin Build & RH turn 5°/100ft (3150' MD & 2805' TVO) ~ ¡', ---- ,._", ,- -, "IT ,c;;¡-J8f{fttr'¡ , fmT-tffffHJJ '";7 ,"", ,', '''''§I'&J,titiI1.,IVDJ, == I ,1'111=::: ::_J litJ 11=4=fttf'== 'T 3750 ! i in" " i """ -- , "" V il 4375 2500 '" -- ~;; +~=-F~:- , - - ---- - "" H11fr 7 - ",' V - '" __ I' "" 75' & 454' Az, (4676' MD & 3561¡iw!rTITVD)! ' ( i = ' 'lJ,~r I -,', , -111 ' "" -"", " "f - - ,,'" i BeQin Buiid to Land in B-Sand @4'/10OO(4954' MD &3633' TVD) " ,I j j ¡ ,-- i_ ~ -- ~~:~ .-- 1- --4,,--1 I Iii ---- - ---- ---- ~ L-- -:l- ---- :-;- I \; , , , . 1\ \ i ~\I I in B-Sand 5250' MD & 3679' ,VC:¡ I ", IT I I j i Ii r i I i - ! : ¡,I ! ¡ f I ,illl-I! , ~- 2500 3125 3750 4375 5000 7500 8125 8750 ¡ 1 j i . i , ; : I ' ---- I i , rID ,--"sony - , ." / I '¡4f$1 JtT;'TÞ'_a'IOB , iJ .i"" "'" j"" ""'" I ,n4L r 159" FEL ,oeu ,u "r ¡ ,ne (12426' "'u,, ," ur II!! [i!! ,II " :::: ¡ ¡ ,¡:::: i ì " . , IBHl ¡ I ' ¡ , I' 5625 6250 6875 7500 8125 9375 9375 " U;'\LU!!l'ttro!iCO)'<tI'ANY 10000 , 1 ! -625 0 - i,n . -1875 :;I c: '" < '" ;::¡. 5' £I'- C1 '" ." 5' ~-2500 - , ' n _" - 10000 625 1250 -- - '" '" o ë1' 2: 5625 m-os Conoc;Phillips Alaska . . Halliburton Company Planning Report -, .-I .. IV-sun QFUL.L.ING SIIFtVICeS A H,.\l.Ll;~U~ro" çOMPAl'lV EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-121 Plan: 1 E-121 1E-121 (wp06) Map System: Goo Datum: Map Zone: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor O.OOOft Northing: Easting: Slot Radius: 5,959,760.24°ft 549,889.510ft 0" Latitude: Longitude: Grid Convergence: 70' 18' 03.021" N 149' 35' 45.358" W 0.380 ' Site Position: From: Position Uncertainty: Map Plan 1 E-121 Position Uncertainty 0.000 ft 0.000 ft 0.000 ft Northing: Easting: Wellhead Elevation: 5,960,559.830 ft ~ 549,889.880 ft ft Latitude: Longitude: Ground Level: 70' 18' 10.886" N 149' 35' 45.192" W 70.700 ft Well Position +N/-S +EI-W .M'" Plan: 1E-121 bggm2004 11/9/2004 24.537 80.743 57.577 Audit Notes: Version: 10 Phase: PLAN Tie On Depth: 28.000 28.000 0.000 0.000 26.000 1212/2004 7:27:58PM Page 2 of 8 COMPASS 2003.11 Build 48 ORIGINAL . . Conoc~hillips Alaska Halliburton Company Planning Report ~I .-1 .. ·y-sun DFtIL.L.INC!I SBFtVIC:.S A RAl-LlBURW.s COldPANY EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-121 Plan: 1 E-121 1E-121 (wp06) 28.000 0.000 0.000 28.000 0.000 0.000 0.00 0.00 0.00 0.000 600.000 0.000 0.000 600.000 0.000 0.000 0.00 0.00 0.00 0.000 933.333 10.000 60.000 931.644 14.508 25.128 3.00 3.00 0.00 60.000 1,190.670 20.000 50.000 1,179.934 54.073 78.332 4.00 3.89 -3.89 340.587 1,491.177 35.000 48.041 1,445.731 145.250 182.383 5.00 4.99 -0.65 355.662 3,150.000 35.000 48.041 2,804.560 781.396 889.912 0.00 0.00 0.00 0.000 3,752.405 65.056 45.378 3,187.169 1,096.022 1,220.415 5.00 4.99 -0.44 -4.816 4,477.526 65.056 45.378 3,492.974 1,557.854 1,688.382 0.00 0.00 0.00 0.000 4,676.404 75.000 45.380 3,560.818 1,688.983 1,821.258 5.00 5.00 0.00 0.011 4,776.404 75.000 45.380 3,586.700 1,756.830 1,890.010 0.00 0.00 0.00 0.000 1E-121 Blat D Top 4,953.774 75.000 45.380 3,632.607 1,877.170 2,011.957 0.00 0.00 0.00 0.000 5,249.849 86.843 45.381 3,679.241 2,082.161 2,219.689 4.00 4.00 0.00 0.004 1 E-121 BLat Pt1 5,494.224 86.843 45.381 3,692.700 2,253.547 2,393.369 0.00 0.00 0.00 0.000 1 E-121 BLat Pt1 5,972.685 88.714 26.319 3,711.418 2,639.298 2,672.028 4.00 0.39 -3.98 -84.815 6,118.906 88.714 26.319 3,714.700 2,770.328 2,736.841 0.00 0.00 0.00 0.000 1E-121 BLatPt2 6,418.960 88.831 14.314 3,721.151 3,051.136 2,840.807 4.00 0.04 -4.00 -89.571 7,083.239 88.831 14.314 3,734.700 3,694.658 3,005.010 0.00 0.00 0.00 0.000 1 E-121 BLat?t3 7,118.538 89.329 13.379 3,735.267 3,728.926 3,013.457 3.00 1.41 -2.65 -62.002 8,264.775 89.329 13.379 3,748.700 4,843.978 3,278.674 0.00 0.00 0.00 0.000 1 E-121 BLat?t4 8,288.629 90.044 13.361 3,748.831 4,867.184 3,284.190 3.00 3.00 -0.08 -1.495 9,765.260 90.044 13.361 3,747.700 6,303.849 3,625.409 0.00 0.00 0.00 0.000 1 E-121 BLat Pt5 9,793.538 90.891 13.409 3,747.469 6,331.358 3,631.955 3.00 3.00 0.17 3.273 10,164.620 90.891 13.409 3,741.700 6,692.281 3,717.999 0.00 0.00 0.00 0.000 1 E-121 BLat Pt6 10,214.980 90.835 14.919 3,740.941 6,741.103 3,730.320 3.00 -0.11 3.00 92.091 12,426.327 90.835 14.919 3,708.700 8,877.680 4,299.579 0.00 0.00 0.00 0.000 1 E-121 BLat Toe 12/2/2004 7:27:58PM Page 3 of 8 COMPASS 2003.11 Build 48 ORIGfN,AL Conoc~hillips Alaska . Halliburton Company Planning Report . ""DI'""tI"""'y-sun ","'IL.L.IN... ......VlI-a:. A I\ALLI.Il{JRJ'O~ COl\W,.\N¥ 28.000 0.000 0.000 28.000 0.000 0.000 0.000 SHL: 4307' FNL & 630' FELSe.et 16-T11N-R10E 110.000 0.000 0.000 110.000 0.000 0.000 0.000 199.999 0.000 0.000 400.000 0.000 0.000 600.000 0.000 0.000 Begin Build @ 3°/100 ft (600'MD, 600' TVD) 800.000 6.000 60.000 933.333 10.000 60.000 Inerease Build to 4°/100ft (933' MD & 932' TVD) 1,000.000 12.546 55.918 997.020 1,190.670 20.000 50.000 1,179.934 Inerease Build to SO/100ft (1191' MD & 1180' TVD) 1,200.000 20.465 49.899 1,188.688 1,400.000 30.446 48.446 1,369.045 1,491.177 35.000 48.041 1,445.731 Begin Sail @ 35°lne & 48° Azi (1491' MD & 1446' TVD) 1,558.281 35.000 48.041 1,500.700 Pennafrost 1,600.000 1,800.000 1,808.540 13 2,000.000 2,173.551 K15 2,200.000 35.000 48.041 2,026.365 417.078 484.713 587.352 2,400.000 35.000 48.041 2,190.196 493.776 570.018 693.683 2,600.000 35.000 48.041 2,354.026 570.475 655.323 800.014 2,650.877 35.000 48.041 2,395.702 589.986 677.024 827.063 103/4" Casing 3717' FNL & 5231' FEL: Seet15-T11N-R10E (2651' MD & 2396' TVD) ~ 10 3/4" 2,800.000 35.000 48.041 2,517.857 647.173 740.628 906.346 3,000.000 35.000 48.041 2,681.687 723.872 825.933 1,012.677 3,150.000 35.000 48.041 2,804.560 781.396 889.912 1,092.426 Begin Build & RH turn @ 5°/10Oft (3150' MD & 2805' TVD) 3,200.000 37.491 47.696 2,844.881 3,243.258 39.648 47.428 2,878.700 Ugnu C 3,400.000 47.465 46.628 2,992.202 3,600.000 57.447 45.857 3,113.922 3,752.405 65.056 45.378 3,187.169 Sail @65° Ine & 45° Azi (3762' MD & 3187' TVD) 3,800.000 65.056 45.378 3,207.241 3,801.088 65.056 45.378 3,207.700 Ugnu B 3,914.905 Ugnu A 4,000.000 4,200.000 4,325.119 K13 12/2/2004 7:27:58PM 35.000 35.000 48.041 48.041 35.000 48.041 35.000 35.000 48.041 48.041 65.056 45.378 65.056 65.056 45.378 45.378 65.056 45.378 199.999 400.000 600.000 799.635 931.644 1,534.874 1,698.705 1,705.700 1,862.535 2,004.700 3,255.700 3,291.587 3,375.933 3,428.700 0.000 0.000 0.000 5.231 14.508 21.461 54.073 56.149 112.426 145.250 170.984 186.983 263.681 266.956 340.379 406.935 801.228 819.427 893.030 1,002.616 1,096.022 1,126.335 1,127.028 1,199.518 1,253.716 1,381.097 1,460.786 0.000 0.000 0.000 9.061 25.128 36.140 78.332 80.802 145.631 182.383 211.004 228.798 314.103 317.746 399.408 473.432 911.832 931.734 1,010.662 1,125.003 1,220.415 1,251.131 1,251.833 1,325.286 1,380.204 1,509.277 1,590.024 Page 4 of 8 0.000 0.000 0.000 8.674 24.055 35.131 82.939 85.888 164.888 210.501 246.177 268.357 374.689 379.229 481.020 573.290 1,119.860 1,144.941 1,245.695 1,394.314 1,520.092 1,560.803 1,561.733 1,659.087 1,731.874 1,902.945 2,009.966 ORIGINAL 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 3.00 0.00 3.00 3.00 0.00 4.00 3.82 -6.12 4.00 3.91 -3.10 5.00 4.98 -1.08 5.00 4.99 -0.73 5.00 4.99 -0.44 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5.00 4.98 -0.69 5.00 4.99 -0.62 5.00 4.99 -0.51 5.00 4.99 -0.39 5.00 4.99 -0.31 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 COMPASS 2003. 11 Build 48 . . Conoc;p.,illips Alaska Halliburton Company Planning Report ~I.~I -I -Y-!!5LI1 O....L.L.INu .."VI~.. ^ HA.LLIBUR'fG'i çm.IfA!"lY 4,400.000 65.056 45.378 3,460.279 1 ,508.478 1 ,638.350 2,074.016 0.00 0.00 0.00 4,477.526 65.056 45.378 3,492.974 1 ,557.854 1 ,688.382 2,140.328 0.00 0.00 0.00 Begin Build @ 6·/10Oft (447S' MD & 3493' TVD) 4,600.000 71.179 45.379 3,538.598 1,637.646 1,769.236 2,247.489 5.00 5.00 0.00 4,676.404 75.000 45.380 3,560.818 1,688.983 1,821.258 2,316.435 5.00 5.00 0.00 Sail @ 76· & 46.4· Azi (4676' MD & 3661' TVD) 4,776.404 75.000 45.380 3,586.700 1,756.830 1,890.010 2,407.554 0.00 0.00 0.00 D -1E-121 Blat D Top 4,800.000 75.000 45.380 3,592.807 1,772.839 1,906.233 2,429.055 0.00 0.00 0.00 4,950.271 75.000 45.380 3,631.700 1,874.793 2,009.549 2,565.981 0.00 0.00 0.00 C 4,953.774 75.000 45.380 3,632.607 1,877.170 2,011.957 2,569.173 0.00 0.00 0.00 Begin Build to Land in B-Sand @4·/100ft (4954' MD &3633' TVD) 5,000.000 76.848 45.380 3,643.848 1,908.663 2,043.871 2.611.469 4.00 4.00 0.00 5,084.877 80.244 45.380 3,660.700 1,967.084 2,103.073 2,689.930 4.00 4.00 0.00 / 7518 Casing - 2340' FNL&3S02' FE!.: Sect 16-T11N-R10E (6086' MD & 3661' TVD) .-8 - 7 5IS" 5,200.000 84.848 45.381 3,675.630 2,047.241 2,184.302 2,797.583 4.00 4.00 0.00 5,249.849 86.843 45.381 3,679.241 2,082.161 2,219.689 2,844.482 4.00 4.00 0.00 Begin Geo-Steering in B-Sand (6250' MD & 3679' TVD) -1E-121 BLat Pt1 5,400.000 86.843 45.381 3,687.510 2,187.466 2,326.403 2,985.909 0.00 0.00 0.00 5,494.224 86.843 45.381 3,692.700 2,253.547 2,393.369 3,074.658 0.00 0.00 0.00 5,600.000 87.234 41.163 3,698.168 2,330.444 2,465.760 3,175.507 4.00 0.37 -3.99 5,800.000 88.011 33.194 3,706.478 2,489.533 2,586.412 3,371.385 4.00 0.39 -3.98 5,972.685 88.714 26.319 3,711.418 2,639.298 2,672.028 3,543.525 4.00 0.41 -3.98 6,000.000 88.714 26.319 3,712.031 2,663.775 2,684.136 3,570.832 0.00 0.00 0.00 6,118.906 88.714 26.319 3,714.700 2,770.328 2,736.841 3,689.706 0.00 0.00 0.00 1 E-121 BLat Pt2 6,200.000 88.740 23.075 3,716.502 2,843.977 2,770.710 3,770.749 4.00 0.03 -4.00 6,400.000 88.822 15.074 3,720.763 3,032.800 2,835.998 3,969.083 4.00 0.04 -4.00 6,418.960 88.831 14.314 3,721.151 3,051.136 2,840.807 3,987.671 4.01 0.05 -4.01 6,600.000 88.831 14.314 3.724.843 3,226.519 2,885.558 4,164.922 0.00 0.00 0.00 6,800.000 88.831 14.314 3,728.923 3,420.270 2,934.996 4,360.736 0.00 0.00 0.00 7,000.000 88.831 14.314 3,733.002 3,614.020 2,984.434 4,556.550 0.00 0.00 0.00 7,083.239 88.831 14.314 3,734.700 3,694.658 3,005.010 4,638.046 0.00 0.00 1E-121 BLat Pt3 7,118.538 89.329 13.379 3,735.267 3,728.926 3,013.457 4,672.549 3.00 1.41 -2.65 7,200.000 89.329 13.379 3,736.222 3,808.172 3,032.306 4,752.038 0.00 0.00 0.00 7,400.000 89.329 13.379 3,738.565 4,002.730 3,078.582 4,947.192 0.00 0.00 0.00 7,600.000 89.329 13.379 3,740.909 4,197.289 3,124.858 5,142.346 0.00 0.00 0.00 7,800.000 89.329 13.379 3,743.253 4,391.848 3,171.134 5,337.500 0.00 0.00 0.00 8,000.000 89.329 13.379 3,745.597 4,586.406 3,217.410 5,532.654 0.00 0.00 0.00 8,200.000 89.329 13.379 3,747.941 4,780.965 3,263.686 5,727.808 0.00 0.00 0.00 8,264.775 89.329 13.379 3,748.700 4,843.978 3,278.674 5,791.014 0.00 0.00 0.00 1E-121 Blat Pt4 8,288.629 90.044 13.361 3,748.831 4,867.184 3,284.190 5,814.290 3.00 3.00 -0.08 8,400.000 90.044 13.361 3,748.745 4,975.541 3,309.925 5,922.962 0.00 0.00 0.00 8,600.000 90.044 13.361 3,748.592 5,170.128 3,356.141 6,118.116 0.00 0.00 0.00 8,800.000 90.044 13.361 3,748.439 5,364.715 3,402.357 6,313.269 0.00 0.00 0.00 9,000.000 90.044 13.361 3,748.286 5,559.302 3,448.573 6,508.422 0.00 0.00 0.00 9,200.000 90.044 13.361 3,748.133 5,753.889 3,494.789 6,703.575 0.00 0.00 0.00 9,400.000 90.044 13.361 3,747.980 5,948.476 3,541.005 6,898.729 0.00 0.00 0.00 9,600.000 90.044 13.361 3,747.827 6,143.062 3,587.221 7,093.882 0.00 0.00 0.00 12/2/2004 7:27:58PM Page 5 of 8 COMPASS 2003.11 Build 48 OR! G , ~J l\ t.~_ . Conoc~illips Alaska Halliburton Company Planning Report . spIII'"T"y-sun a"dL.L.IN'IO .."'VI,-.. A JLU.LIB.\JR,TO~ COl\WANY 9,765.260 90.044 13.361 3,747.700 6,303.849 3,625.409 7,255.137 0.00 0.00 0.00 1E·121 BLat pt5 9,793.538 90.891 13.409 3,747.469 6,331.358 3,631.955 7,282.731 3.00 3.00 0.17 9,800.000 90.891 13.409 3,747.369 6,337.643 3,633.453 7,289.037 0.00 0.00 0.00 10,000.000 90.891 13.409 3,744.259 6,532.168 3,679.828 7,484.204 0.00 0.00 0.00 10,164.620 90.891 13.409 3,741.700 6,692.281 3,717.999 7,644.846 0.00 0.00 0.00 1E·121 BLat pt6 10,200.000 90.852 14.469 3,741.162 6,726.614 3,726.521 7,679.440 3.00 -0.11 2.99 10,214.980 90.835 14.919 3,740.941 6,741.103 3,730.320 7,694.128 3.01 -0.11 3.01 10,400.000 90.835 14.919 3,738.244 6,919.867 3,777.949 7,875.679 0.00 0.00 0.00 10,600.000 90.835 14.919 3,735.328 7,113.104 3,829.435 8,071.930 0.00 0.00 0.00 10,800.000 90.835 14.919 3,732.412 7,306.342 3,880.920 8,268.180 0.00 0.00 0.00 11,000.000 90.835 14.919 3,729.496 7,499.580 3,932.405 8,464.430 0.00 0.00 0.00 11,200.000 90.835 14.919 3,726.580 7,692.817 3,983.890 8,660.681 0.00 0.00 0.00 11,400.000 90.835 14.919 3,723.664 7,886.055 4,035.376 8,856.931 0.00 0.00 0.00 11,600.000 90.835 14.919 3,720.748 8,079.292 4,086.861 9,053.182 0.00 0.00 0.00 11,800.000 90.835 14.919 3,717.832 8,272.530 4,138.346 9,249.432 0.00 0.00 0.00 12,000.000 90.835 14.919 3,714.916 8,465.768 4,189.831 9,445.683 0.00 0.00 0.00 12,200.000 90.835 14.919 3,712.000 8,659.005 4,241.317 9,641.933 0.00 0.00 0.00 12,400.000 90.835 14.919 3,709.084 8,852.243 4,292.802 9,838.184 0.00 0.00 0.00 12,426.327 90.835 14.919 3,708.700 8,877.680 4,299.579 9,864.017 0.00 0.00 0.00 BHL: 710' FNL & 1591'FEL: sect 10-T11N·R10E (12426' MD & 3709'TVJ:)) ·41/2 ·.1E·121 Blat Toe 12/2/2004 7:27:58PM Page 6 of 8 COMPASS 2003.11 Build 48 ORIGINAL Conoc~hillips Alaska . . -n.-mY-BLn D"'IL.L.INut .."'VII.... A J\ALLUUJRTO~ CQM.PANV Halliburton Company Planning Report EDM 2003.11 Single User Db onocoPhillips Alaska Inc. uparuk River Unit uparuk 1 E Pad Ian 1 E-121 Ian: 1 E-121 1E-121 (wp06) 1 E-121 Blat D Top 0.00 0.00 3,586.700 1,756.830 1,890.010 5,962.329.000 551,768.000 70' 18' 28.162" N 149' 34' 50.072" W - plan hits target - Point 1E-121 BLat Pt3 0.00 0.00 3,734.700 3,694.658 3,005.010 5,964,274.000 552,870.000 70' 18' 47.217" N 149' 34' 17.531" W - plan hits target - Point 1E-121 BLat Pt1 0.00 0.00 3,692.700 2,253.547 2,393.369 5,962,829.000 552,268.000 70' 18' 33.046" N 149' 34' 35.387" W - plan hits target - Point 1E-121 BLat Pt5 0.00 0.00 3,747.700 6,303.849 3,625.409 5,966,887.000 553,473.000 70' 19' 12.875" N 149' 33' 59.396" W - plan hits target - Paint 1 E-121 BLat Pt6 0.00 0.00 3,741.700 6,692.281 3,717.999 5,967,276.000 553,563.000 70' 19' 16.695" N 149' 33' 56.689" W - plan hits target - Point 1 E-121 BLat Toe 0.00 0.00 3,708.700 8,877.680 4,299.579 5,969,465.000 554,130.000 70' 19' 38.185" N 149' 33' 39.680" W - plan - Point 1E-121 BLat Pt4 0.00 0.00 3,748.700 4,843.978 3,278.674 5,965,425.000 553,136.000 70' 18' 58.519" N 149' 34' 09.533" W - plan hits target - Point 1E-121 BLat Pt2 0.00 0.00 3,714.700 2,770.328 2,736.841 5,963,348.000 552,608.000 70' 18' 38.127" N 149' 34' 25.364" W - plan hits target - Point 110.000 110.000 20" 20 40 2,650.874 2,395.700 103/4" 10-3/4 13-1/2 5,084.877 3,660.700 7 5/8" 7-5/8 9-7/8 12,426.326 3,708.700 4 1/2 4-1/2 6-3/4 1 ,558.281 1 ,808.540 2,173.551 3,243.258 3,801.088 3,914.905 4,325.119 4,776.404 4,950.271 5,084.877 121212004 7:27:58PM 1,500.700 Permafrost 1,705.700 T3 2,004.700 K15 2,878.700 Ugnu C 3,207.700 Ugnu B 3,255.700 Ugnu A 3,428.700 K13 3,586.700 D 3,631.700 C 3,660.700 B 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 o RPr~1N A L 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 COMPASS 2003. 11 Build 48 Conoc~Phillips Alaska . . Halliburton Company Planning Report ~y-sun DFULLINCI .IIAVIC:II. A JW.l,IBURTO's COMJ:>A,N\' EDM 2003.11 User Db ConocoPhillips Alaska Inc. Kuparuk River Unit uparuk 1 E Pad Ian 1E-121 Plan: 1 E-121 1 E-121 (wp06) 28.000 600.000 933.330 1,190.670 1 ,491.177 2,650.877 3,150.000 3,752.405 4,477.526 4,676.404 4,953.774 5,084.877 5,249.849 12,426.326 12/2/2004 7:27:58PM 28.000 600.000 931.640 1,179.934 1,445.731 2,395.702 2,804.560 3,187.169 3,492.974 3,560.818 3,632.607 3,660.700 3,679.241 3,708.700 0.000 0.000 14.507 54.073 145.250 589.986 781.396 1,096.021 1,557.854 1,688.983 1,877.170 1,967.084 2,082.161 8,877.679 0.000 0.000 25.127 78.332 182.383 677.024 889.912 1,220.415 1,688.382 1,821.257 2,011.957 2,103.073 2,219.689 4,299.579 SHL: 4307' FNL & 630' FEL Sect 16-T11N-R10E Begin Build @3°/100ft(600'MD, 600' TVD) Increase Build to 4°/100ft (933' MD & 932' TVD) Increase Build to 5°/100ft (1191' MD & 1180' TVD) Begin Sail @ 35° Inc & 48° Azi (1491' MD & 1446' TVD) 103/4" Casing 3717' FNL & 5231' FEL: Sect15-T11N-R10E (2651' MD & 239€ Begin Build & RH tum @ 5°/100ft (3150' MD & 2805' TVD) Sail @ 65° Inc & 45° Azi (3752' MD & 3187' TVD) Begin Build @ 5°/100ft (4478' MD & 3493' TVD) Sail @ 75° & 45.4° Azi (4676' MD & 3561' TVD) Begin Build to Land in B-Sand @ 4°/100ft (4954' MD &3633' TVD) 75/8 Casing - 2340' FNL & 3802' FEL: Sect 15- T11N-R10E (5085' MD & 3661 Begin Gee-Steering in B-Sand ( 5250' MD & 3679' TVD) BHL: 710' FNL & 1591' FEL: Sect 10-T11N-R10E (12426' MD & 3709' TVD) COMPASS 2003. 11 Build 48 ORiGÎNAl WELL DETAJLS ~am<: ¡-Ni,S ,Ei·W N"rthing E¡¡~1¡ng Lßtit! dc L(}j\gitudl: Slo¡ 'Ian IF-Ill 7<)<),M8 5.680 5960559.&3 549889.88 71Y'1&'1O.8&6N !49-'J5'45.J92W NiA -112 100 ANn-eOLLISION SETTINGS iE· 121 BLat (\-vp06) Prom Colour 28 100 950 33 ToMD rOO 200 450 700 950 1450 1950 2450 2950 3450 4950 6450 7950 9450 10950 12426 COMPANY DETAILS SURVEY PROGIMM D"plhFm fkpthTo '''' Rcf.lMul!1 10.0 20.0 15.0 5.0 5.0 100 -0 ¡;; . 15.0 b "" '20.0 25.0 "'""26.2 ]8{fUL LEGE'ND TraveHing Cylinder Azimuth (TFO+AZl) [deg] VB Cenlre 10 Centre Separation [50ft/in] TraveHing Cylinder Azimuth (TFO+AZl) [deg] vs Cenlre to Centre Separation [15ft/in] SECTION DETA!1"S Soc. MD In..: 'E;·W DL;..'ß fhwe 0,00 O,(Xj 300 ,1.{)0 5.0() 0.00 5J)(j O})() '.00 0.00 0.00 4,00 0.00 4JXì 0.00 4.0Ü 0.00 lO() O.O!) 3J)() OJ)() ).Ü() 0.00 3JJO OJX> V$tx 3 4 , " 7 , 9 [I) II J2 J3 14 15 16 17 '" 19 20 21 22 23 24 25 U~~¡2! WS [Hop IE,121 WSBL1J.tl'¡ I JE-IZI WS- JH.J.I¡-JIi 2 IE-121 W8BLatf'U lE·12IWSBL;üP¡4 !E·J2!WSBL¡¡.t1>¡5 JE-IZI WSBL(\IPt6 !E-tnWsBLatToc -- --- -- ---- --:J \\UlJ'AIHÜETA!LS ,1¡r.:W ~:~"VD Colour loMU 100 200 450 700 950 140-- 130--= 120--= 110--= ¡::: 0 100--= .~ a 0- 90-= <1) ifJ <1) 80--= .... .... ¡::: <1) u 70-=: 0 .... <1) .... 60- .... ¡::: <1) u 50-=: 40-=: 30-=: 20--= 10--= Plan: IE-121 (wp06)(Plan 1E-1211P1an 1E-121) 220-- 210--= 200--= 190--= 180--= 170--~ 160- -20---=· - 3 0--= -40-=: - 5 0--= IIIII i j J III I! III III f ¡ II -400 -300 -200 -100 0 11111111111111111111111'1: II' i 11111'11111'111111'111111111 i 1111111'11111 II! I 11111 I! I 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 Measured Depth [ft] N ~ KRU 1 E-121 Proposed i-Oil 2042460 SFD 12/15/2004 ~ ¡: o ~ . ~ o MEMO ':0 :ì UNIV/:RSAl r'A:O(::ZC C $ /éJo. Oð AUiSt;1t . PAVTO T. H E -G1J~1fT£ of' I 1/ /J ~ 1,.... _ OOLlAR$ ITI , ORDER OF ~(th,> t:-,f" lfi ,¡ --~ - ~ - Bank USA, N.Þ.. Up To ~) CHASE ::.:..=.-.'". "lL· ~. ÍÀ ~ · '7/; ---- ... m ____.O.m._ ~--~-----,~- ----- ,. ¡'08 2 .¡'OO.I.I. I: 2¡'81.7 ¡'110 711 271; . SHARON K. ALLSUP·DRAKE CONOCOPHILLlPS ATO 1530 700 G ST. ANCHORAGE AK 99501 1082 DATE /3 f)e.a.....~ 2Ø()4- ~ 62-14/311 e . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /¿J2¿t / E,-!¿ ( PTD# zo V-2-i.f~ ,/ Development Service CHECK WHAT APPLIÉS ADD-ONS (OPTIONS) MULTI LATERAL (1f API Dum ber last two. (2) digits are between 60-69) Exploration Stratigraphic ~'CL DE fl. Tbe permit is for a new wellbore segment of e:xisting well" . Permit No, .' API No. Production. sbould continue to be reponed as a function 'of tbe original API Dumber. stated above. . HOLE In accordance with 20 AAC 25.00S(f), an records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb Dame (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for we)) (Dame on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25..0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing eueption. {Company Name) assumes tbe liability of any protest to tbe spacinge:lception tbat may occur. AU dry ditcb sample sets submitted to tbe Commission must be in no greater 1ban 30' sample intervals from below tbe permafrost or from where samples are first caught aDd ] 0' sample inter:vals tbrough target zones. Administration Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 PTD#: 2042460 Company CONOCOPHILLlPS ALASKA INC Initial ClassfType 1 P~rmitfee Qttaçhed. . . . . . . . y~s 2 LeQs~.number.apRrORriate.... ........ Y~s. .... ..Surtaçeloca.tiooinAP1-025651.tOP.Rrodiot~rval&.TQinAP1-0256~6 ...... 3 .U.nique weltn.am~.aod Ollmb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 Well JQcat~d in.a. d.efinedppol. . . . . . . . . . . . . . . . . . . . . Yes. . . . . KRU West Sal< Oil Pool, goyeroed bY.C.ooseNation Order No, 4Q6B. . . 5 WellJQcat~d proper .distance. from driJling unitb.oundary. . y~s . . No tnterweJI spacing restriçtjo.ns,mOJe than SQO' from exte.maJ bQundaJ)'. . 6 WellJQcat~d proper .distance from other welJs . . . . . . . . Yes. . . . . . . . 7 .S.u{fiçientaçreQg.e.ayQilable indrillillg unjt . . . . . . . y~s . . . . . . . . . . . . . 8 Jf.d~viated, js. weJlbore plaUncJuded . . . . . . . . . Yes. . . . . . . . . . . . . . . 90.perator only Qff'eçted party. . . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . 10 .O.perator bas.appropriate.bond inJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 P~rmitcaobeisslledlNjtbQutconserva.tiooorder. Y~s............. ....'. ....'. ....'. ...... Appr Date 12 P~rmitC<ln be isslled INjtbout ac:tministratÍlle.approvaL . . . . . . . . . Yes. . . . . . . . SFD 12/15/2004 13 Can permit be approved before 15-daywait Yes 14 WellJQcat~d within Qrea alldstrata .authorized by.lojectioll Ord~r # (putlO# incomm.eots).(For. .NA . . . . . . . . . . . . 15 AJI weIJs.witntn.114.mile.area.of reyiew jd~otifjed (For sefVj~well OOly). . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pre-producec:t injector; .durationof pre-.productipo I~ss tnQn:3 montbs. (For.service well onJy) . . NA . . . . . . . . . . . . . 17 AÇMP.F:iodingofCon.sistency.h.as beenJssuedfprJhis projeçt . . . . . . . . . . . . . .NA . . . . . . . . 18C.ooductor striog.prov[ded . . . . . . . . . . . . . . . y~s . . . . . . . . . . . . . . . . . . . . . 19Surfa~.casingpJotectsallknownUSQWs. ............. ..NA ... .8Ilaq.uifersex~mpt~d,AOCFR147.102(b).(:3). 20CMTv.oladequ.ateJo çirculate.oncpnd.uctpr& SUJf.csg . y~s . . . . . . 21CMT v.ol adequateJo tie-tnJQng .string to.surf çsg. . . . . . . . . . . . .No. . . . .811 hydroçarbon.zOlles.pJanoedto be çover~d. 22 .CMTwill coyeraJll<nown.productiye bQri¡¡:on.s . . . . . . . . . . . . . . .No. . Slotte.dJioer.completioo plaooed.. . 23 .C.asiog desigos ac:tequa.te for C,T, B.&permafr.ost . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . 24 .ÄdequateJQnkage.or re.seIYe pit y~s . . Rig jSßquippedwith steelpits.. No rese.rvepit.planlled, M wasteto apPJoved aon.ulus pr ClassJlweJI.. 25 Jfa.re-drilt hasa. 10,403 for abandooment be~o aRProved . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . .26 .Ädequatewellbore separatjo.npro.ppsed. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . y~s . . . . . . . I?rOJSil]1ity analysis pertormed, Jrayeling cylioder ploUllcJu.ded.. ~roximity.d.oes oo.t aPRearJo be ao issu~. . . . . . 27 Jfdjvecter required, does jt meet reguJations. . . . . . . . Yes. . . . . . . . . . . . . . Appr Date 28 .DJiUillg flujd. program schematic.&. equip Jistadequate. . . . . . . . . . Y~s. . . . Maximum expectformation.pre.ssuJe 8.6 EMW.MWpJanlled.9, 1 RP9Jn 9-7/8'~ hole. and 9.0.ppg tnWS. TEM 1~/.15/2004 29 .BOPEs,.do.they meetreguJation . . . . . . . . y~s . . . . . . ~.m ~. if'I'J \ 3301 BOPE.press ratiog ap.propriate; .testto(pu.t psig in.comments). . . . . . . . . Yes.. .... M8S~ çalculate.dat 1235 'psi. 35QO.pstest planned.. BOF' stack will conform to.3K"rules" withJ'RIBRl8n.. /IJYChoke.manjfold compJies w/APtRF'-53 (May 84). Y~s . . .lPR c;ayitY.will be. equipped with çasjn-9.rams.. . . . . . . . . . 32 Work will pccur withoutoperationsbutdown y~s . . . . . . . . . . . . . 33 Js preseoce of H2S gas. prob.able . . . . . . .No . . . . . tf2S basnpt been reported in WS.. . . . . . . . 34 Mecba.nlcalcPlldJtionof wells withio 80R yerified (for. s.ervice IN~IJ only). . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . Well Name: KUPARUK RIV UNIT 1E-121 DEV I PEND GeoArea 890 Unit J 1160 Program DEV On/Off Shore On Well bore seg Annular Disposal ~ o - - - - - - . Engineering - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - e Appr SFD 35 36 Date 37 12/15/2004 38 39 P~rmit c.an be issued INfo hydrogen sulfide meas.ures . .D.atapresented On RotentialoveJRress!Jr~zones. S~tsm[c.analysis. of sbaJlow gas.zolles . .S~abed .cooditioll survey (if off-sh.ore) . . . . . . . . . . CQntact namelpnooeJor.weekly prpgressreports [exploratpry .only). - - - - - - - - - - - - - . .Y~$. . Y~$ . NA NA. . NA - - - - - - - - - - - - Geology . Expected r~$ervojr .pressUJe is .8.6ppg EMW; will be drilled with 9.0 ppg mud.. . . . l:iydrates.and sbaJlow gas are not exp~cted.. . . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - ~ - - - - - - - - - - - - - - - - - Geologic Commissioner: Date: Engineering Commissioner: Date Public Commissioner Date 1J7J' / ¿¡ / 6/1-. . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . Sperry-Sun Drilling Services LIS Scan Utility . ~of-tÀc/Ç $Revision: 3 $ LisLib $Revision: 4 $ Mon Feb 28 15:49:08 2005 If I )fJ:L~ Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments.... ....... ..... .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1E-121 500292323800 ConocoPhillips, Alaska, Inc Sperry-Sun Drilling Services 28-FEB-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003458622 E. QUAM D. GLADDEN MWD RUN 3 MW0003458622 E. QUAM D. GLADDEN MWD RUN 4 MW0003458622 E. QUAM D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 16 11 10 973 630 98.70 70.70 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 9.875 6.750 CASING SIZE (IN) 10.750 7.625 DRILLERS DEPTH (FT) 2662.0 5267.0 # . . REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). RUNS 2 & 4 ALSO INCLUDED GEO- PILOT ROTARY STEERABLE BHA (GP). RUNS 2 & 3 ALSO INCLUDED ACOUSTIC CALIPER (ACAL). RUN 4 ALSO INCLUDED AT-BIT INCLINATION (ABI) . 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 - 4 REPRESENT WELL lE-121 WITH API#:50-029-23238-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12415'MD/3742'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name. ........... .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE CALA FET RPD RPM RPS 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2620.0 2627.5 2627.5 2627.5 2627.5 STOP DEPTH 5185.0 12364.0 12364.0 12364.0 12364.0 RPX GR ROP $ . 2627.5 2636.5 2670.0 12364.0 12357.0 12415.0 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 2 3 4 MERGE TOP 2620.0 3460.0 5270.0 MERGE BASE 3460.0 5270.0 12415.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type...... ....... .....0 Data Specification Block Type. ....0 Logging Direction............... ..Down Optical log depth units........ ...Feet Data Reference Point............ ..Undefined Frame Spacing.... ................ .60 .1IN Max frames per record. ....... .....Undefined Absent value............ ..........-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 CALA MWD INCH 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2620 12415 7517.5 19591 2620 12415 ROP MWD FT/H 0.15 652.56 175.172 19480 2670 12415 GR MWD API 25.63 134.54 67.5869 19442 2636.5 12357 RPX MWD OHMM 1. 33 2000 70.3604 19474 2627.5 12364 RPS MWD OHMM 1.29 2000 52.9517 19474 2627.5 12364 RPM MWD OHMM 1. 31 2000 73.3269 19474 2627.5 12364 RPD MWD OHMM 0.97 2000 82.6135 19474 2627.5 12364 FET MWD HOUR 0.17 77.36 1. 39785 19474 2627.5 12364 CALA MWD INCH 8.92 12.54 10.2622 5106 2620 5185 First Reading For Entire File......... .2620 Last Reading For Entire File.......... .12415 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/28 . Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name. ......... ...STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/02/28 Maximum Physical Record. .65535 File Type............ ... .LO Previous File Name. ..... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE CALA FET RPD RPM RPS RPX GR ROP $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 2620.0 2627.5 2627.5 2627.5 2627.5 2627.5 2636.5 2670.0 # 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: # STOP DEPTH 3389.0 3417.5 3417.5 3417.5 3417.5 3417.5 3425.0 3460.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 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): 16-JAN-05 Insite 66.37 Memory 3460.0 2669.0 3460.0 35.0 40.9 TOOL NUMBER 061497 134760 9.875 2662.0 Water Based 9.00 50.0 8.5 300 9.0 . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: . 4.500 3.750 4.000 6.000 66.0 80.5 66.0 66.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction......... .... ....Down Optical log depth units. ........ ..Feet Data Reference Point.... ..........Undefined Frame Spacing................ '.. ..60 .1IN Max frames per record........... ..Undefined Absent value.............. ...... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 CALA MWD020 INCH 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2620 3460 3040 1681 2620 3460 ROP MWD020 FT/H 28.14 301.74 188.813 1581 2670 3460 GR MWD020 API 26.7 112.3 61.5869 1578 2636.5 3425 RPX MWD020 OHMM 1. 33 1598.15 14.1594 1581 2627.5 3417.5 RPS MWD020 OHMM 1.29 2000 20.8786 1581 2627.5 3417.5 RPM MWD020 OHMM 1. 31 1850.01 15.6581 1581 2627.5 3417.5 RPD MWD020 OHMM 0.97 2000 73.5524 1581 2627.5 3417.5 FET MWD020 HOUR 0.17 47.04 2.97202 1581 2627.5 3417.5 CALA MWD020 INCH 9.44 12.54 10.2264 1539 2620 3389 First Reading For Entire File...... ....2620 Last Reading For Entire File.......... .3460 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation...... .05/02/28 Maximum Physical Record. .65535 File Type... ............ .LO Next File Name.......... .STSLIB.003 . Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation. ..... .05/02/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE CALA RPX RPS RPM RPD FET GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 3389.5 3418.0 3418.0 3418.0 3418.0 3418.0 3425.5 3460.5 STOP DEPTH 5185.0 5216.0 5216.0 5216.0 5216.0 5216.0 5223.5 5270.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 17-JAN-05 Insite 66.37 Memory 5270.0 3460.0 5270.0 45.5 81.5 TOOL NUMBER 061497 134760 9.875 2662.0 Water Based 9.10 80.0 8.5 350 5.6 5.000 3.640 8.000 70.0 98.6 70.0 . MUD CAKE AT MT: 4.000 . # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.,..... ...........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing.................. ...60 .1IN Max frames per record.. ...........Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 CALA MWD030 INCH 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3389.5 5270 4329.75 3762 3389.5 5270 ROP MWD030 FT/H 1.35 652.56 181.281 3620 3460.5 5270 GR MWD030 API 30.67 119.87 78.467 3597 3425.5 5223.5 RPX MWD030 OHMM 5.84 87.38 14.2516 3597 3418 5216 RPS MWD030 OHMM 6.29 103.77 15.4887 3597 3418 5216 RPM MWD030 OHMM 6.72 101. 12 15.909 3597 3418 5216 RPD MWD030 OHMM 7.98 120.94 17.9465 3597 3418 5216 FET MWD030 HOUR 0.24 12.28 0.910801 3597 3418 5216 CALA MWD030 INCH 8.92 11.8 10.2776 3567 3389.5 5185 First Reading For Entire File......... .3389.5 Last Reading For Entire File.......... .5270 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/02/28 Maximum Physical Record. .65535 File Type...... ......... .LO Next File Name. ........ ..STSLIB.004 Physical EOF . File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .05/02/28 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 . header data for each bit run in separate files. 4 .5000 START DEPTH 5216.5 5216.5 5216.5 5216.5 5216.5 5224.0 5270.5 STOP DEPTH 12364.0 12364.0 12364.0 12364.0 12364.0 12357.0 12415.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 23-JAN-05 Insite 66.37 Memory 12415.0 5270.0 12415.0 78.9 92.7 TOOL NUMBER 135134 73764 6.750 5267.0 Oil Based 9.00 92.0 .0 42000 2.4 .000 .000 .000 .000 .0 116.6 .0 .0 . HOLE CORRECTION (IN): . # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type.....O Logging Direction..... ........... . Down Optical log depth units.......... .Feet Data Reference Point. ............ .Undefined Frame Spacing..... ............... .60 .1IN Max frames per record............ .Undefined Absent value...... ............... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5216.5 12415 8815.75 14398 5216.5 12415 ROP MWD040 FT/H 0 492.45 171.98 14290 5270.5 12415 GR MWD040 API 25.63 134.54 65.5074 14267 5224 12357 RPX MWD040 OHMM 4.32 2000 90.6932 14296 5216.5 12364 RPS MWD040 OHMM 4.63 2000 65.9247 14296 5216.5 12364 RPM MWD040 OHMM 4.92 2000 94.1513 14296 5216.5 12364 RPD MWD040 OHMM 2.27 2000 99.8864 14296 5216.5 12364 FET MWD040 HOUR 0.22 77.36 1. 3463 14296 5216.5 12364 First Reading For Entire File......... .5216.5 Last Reading For Entire File.......... .12415 File Trailer Service name. ......... ...STSLIB.004 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.... ...05/02/28 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .05/02/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name. . . . . . . . . . .UNKNOWN · Comments..... ........... .STS LIS Writing Library. SCient~ Technical Services Reel Trailer Service name...... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/02/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........... .... . UNKNOWN Continuation Number..... .01 Next Reel Name........ ...UNKNOWN Comments............ .... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
