The URL can be used to link to this page

Home My WebLink About198-2561. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Conductor ext ConocoPhillips Alaska, Inc. Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9727 feet feet true vertical 5765 feet 9172' feet Effective Depth measured 9194' feet 8677 and 8695 feet true vertical 5465' feet 5171 and 5180 feet Perforation depth Measured depth 9210 to 9240 feet True Vertical depth 5474 to 5491 feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 8800' 5239' Packers and SSSV (type, measured and true vertical depth) Baker Seal Assy Baker S Hyd Packer 8677'-8695' 5170'-5180' SSSV N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name:Roger Mouser / Brennen Green Contact Email: Authorized Title: Contact Phone: 322-387 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. (907) 659-7056 n1927@conocophillips.com Well Integrity Field Supervisor measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 115' 2905' Conductor Surface Production Casing 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-256 5010320284-0000 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0380051 KUPARUK RIVER / TARN OIL KUPARUK RIVER U TARN 2L-307 P.O. Box 100360, Anchorage, AK 99510 measuredPlugs Junk measured Length 81' 2870' Size 16" 7.625" 9646' TVD 115' 2307' 5755'5.5" Burst Collapse 9709' Form 10-404 Revised 10/2021 Submit Within 30 days of Operations Date Event Summary Executive Summary Welded Conductor Extension 09/26/22 (MISC) T/I/O = 230/784/335. 8.5" tree rise (offset) 10/25/22 NES welders, welded a 16" diameter x 10" long x 0.500" wall Conductor extension to the existing Conductor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y Meredith Guhl at 9:46 am, Jul 05, 2022 'LJLWDOO\VLJQHGE\%UHQQHQ*UHHQ '1& 862 &RQRFR3KLOOLSV&1 %UHQQHQ*UHHQ ( Q#FRQRFRSKLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ\RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ %UHQQHQ*UHHQ ; '/% ; '65 3KRWR GRFXPHQW DOO VWHSV 97/ GWV -/& Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.07.18 09:05:21 -08'00' 5%'06 -6% 32%2; $1&+25$*($/$6.$ -XO\ &RPPLVVLRQHU-HVVLH&KPLHORZVNL $ODVND2LO *DV&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$. 'HDU&RPPLVVLRQHU&KPLHORZVNL 3OHDVHILQGWKHHQFORVHGDSSOLFDWLRQIRU6XQGU\$SSURYDOIURP&RQRFR3KLOOLSV $ODVND,QFIRUZHOO.58/37'WRH[WHQGWKHFRQGXFWRU 6XPPDU\&RQGXFWRUKDVVXEVLGHGRUZHOOKDVJURZQa´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´ :LWKDSSURYDOWKHFRQGXFWRUH[WHQVLRQZLOOUHTXLUHWKHIROORZLQJJHQHUDOVWHSV 5HPRYHODQGLQJULQJIURPFRQGXFWRULIQHFHVVDU\ ([WHQGWKHFRQGXFWRUWRVWDUWHUKHDG )LOHZLWKWKH$2*&&SRVWUHSDLU &DVLQJ6WULQJV &DVLQJ'HVFULSWLRQ &21'8&725 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH + 7RS7KUHDG :(/'(' &DVLQJ'HVFULSWLRQ 685)$&( 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH / 7RS7KUHDG %7&02' &DVLQJ'HVFULSWLRQ 352'8&7,21[ # 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH / 7RS7KUHDG /7&02' 7XELQJ6WULQJV 7XELQJ'HVFULSWLRQ 78%,1* 6WULQJ0D« ,'LQ 7RSIW.% 6HW'HSWKIW« 6HW'HSWK79'« :WOEIW *UDGH / 7RS&RQQHFWLRQ (8(UG &RPSOHWLRQ'HWDLOV 7RSIW.% 7RS79' IW.% 7RS,QFO ,WHP'HV &RP 1RPLQDO ,'LQ +$1*(5 (8(UG)0&*HQ9KDQJHU 6/((9( &08:%;SURILOH /2&$725 /RFDWRUVXE 6($/$66< %$.(56($/$66< 3%5 %DNHU3%5 61$3/$7&+ $QFKRUDVVHPEO\ 3$&.(5 %DNHU6+\G3DFNHU 1,33/( ;/$1',1*1,33/( 29(56+27 3RRUER\RYHUVKRW 7XELQJ'HVFULSWLRQ 78%,1* 6WULQJ0D« ,'LQ 7RSIW.% 6HW'HSWKIW« 6HW'HSWK79'«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t9V-25Co • • ,t, WELL LOG TRANSMITTAL#902972130 To: Alaska Oil and Gas Conservation Comm. February 5, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100RECEIVED DATA LOGGED 2.2$'201 Co Anchorage, Alaska 99501F.EB 2�f� M.K.BENDER AOGCC RE: Pipe Recovery Records: 2L-307 Run Date: 12/8/2015, 12/11/2015, 12/15/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2L-307 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20284-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Di✓ce/2.ahov • AWTE OF ALASKA TARNDB 2L-307 KA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations FT Fracture Stimulate FT Pull Tubing F Operations Shutdown FT Performed: Suspend FT Perforate r Other Stimulate n Alter Casing r Change Approved Program FT Plug for Redrill FT Perforate New Pool F', Repair Well IF Re-enter Susp Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory fa 198-256 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20284-00 7.Property Designation(Lease Number): - 8.Well Name and Number: ADL 380051 KRU TARN 2L-307 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): . n/a Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 9727 feet Plugs(measured) None true vertical 5765 feet Junk(measured) None Effective Depth measured 9581 feet Packer(measured) 8695 true vertical 5684 feet (true vertical) 5179 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 0 0 SURFACE 2870 7 5/8 2905 2307 0 0 PRODUCTION 9676 5.5 x 3.5 9709 5755 0 0 Perforation depth: Measured depth: 9210-9240 RECEIVED True Vertical Depth: 5474-5491 SCANNEV EEO i 9 ,f,i AN 20201. AOGC Tubing(size,grade,MD,and ND) 3 1/2, L-80. 8800,5239 C Packers&SSSV(type,MD,and ND) PACKER-BAKER S HYD. PACKER @ 8695 MD and 5180 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: 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 shut-in Subsequent to operation waiting fac. Hookup 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory Development F Service ', Stratigraphic F', Copies of Logs and Surveys Run 16.Well Status after work: Oil F Gas FT WDSPL r-- Printed Printed and Electronic Fracture Stimulation Data r GSTOR FT WINJ FT WAG FT GINJ SUSP FT SPLUG 1- 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Travis Smith@265-6450 Email Travis.T.Smithconocophillips.com Printed Name vi T. Smit, Title Wells Engineer Signature ` Phone:265-6450 Date /11/1e7 / /9 Ai Form 10-404 Revised 5/2015 i RBDMS L\. .1" 2 1 2016 Submit Original Only • 2L-307• DTTM JOBTYP SUMMARYOPS 12/3/15 DRILLING SUPPO ATTEMPT DRIFT TBG W/2.77" &2.30" UNABLE TO PASS 216' SLM. DRIFT TBG TO 4000' SLM WITH 1.65" SCRATCHER. MEASURED BHP @ 6440' RKB ( 1872 PSI ) LRS HOT FLUSHED TBG WITH 60 BBLS HOT DSL. ATTEMPT TO DRIFT TBG WITH 2.83" UNABLE TO PASS 1048' SLM. DECISION MADE TO ABORT PULLING OV DUE TO TIME CONSTRAINTS. JOB COMPLETE. 12/4/15 RECOMPLETION Move office, shop and pit module from 3J pad to 2L pad. Connect and turn on communications. Move Rig sub from 3J pad to pull out, 2 miles past 2M pad. Wait for Rig 141 crew change. 12/5/15 RECOMPLETION Move Rig sub from 3J pad to 2L pad. Spot Rig over 2L-307 and rig up. Rig accepted at 13:00 hrs. Pick up Lubricator, test and pull BPV. Service Master valve, Swab valve and SSV so they would hold pressure. Lay down Lubricator. Rig up to reverse circulate through Rig choke manifold to kill well. 12/6/15 RECOMPLETION Bled off gas cap, kill well with 8.6ppg kill weight fluid and circulate until returns are clean. Set BPV, ND tree/ NU BOPE. Test BOPE 250/2500, all good. ND test equipment, MU landing joint and attempted to pull hanger free. No go. 12/7/15 RECOMPLETION Wait on slickline unit and equipment. Rig up slickline and make scratcher and gauge runs to make certain tubing is clear for e-line cut. Rig down slickline and begin picking up e-line. 12/7/15 DRILLING SUPPO CUT LIGHT PARIFFIN & RAN 2.54" GAUGE RING TO 6440' SLM, JOB COMPLETE. 12/7/15 DRILLING SUPPO**7ES JOB** FIRED 160 GR/FT STRING SHOT WITH MID SHOT AT 6350' MADE TUBING CUT WITH RCT 2000-200 AT 6350' 12/8/15 RECOMPLETION Made RCT cut at 6,350' RKB. Picked up and circulated sand out of hole, re-landed hanger to test BOPE for 2-7/8" drillpipe. POOH with 3-1/2"completion. 12/9/15 RECOMPLETION POOH remaining 3-1/2" completion to cut stub. PU spear and fishing BHA and RIH on 2-7/8"drill pipe to fish at 6,393'. Engage and pull jar licks until spear disengages. Begin POOH for fishing BHA#2. Daily fluid loss= 310 BBIs of sea water Cum. Fluid loss = 1177 BBL's 12/10/15 RECOMPLETION RIH with BHA#2, engage fish and jar for 4 hours until spear disengages for second time. No sign of movement from 3-1/2"tubing stub. TOOH and PU BHA#3 (G-Spear and jars on 2-1/16" stinger)to attempt to fish 2-3/8" patch. Begin TIH with BHA#3. 12/11/15 RECOMPLETION TIH and engage deployment sleeve of liner patch packer. Shear packer and TOOH with upper section of liner patch and RU e-line to make another cut of 3-1/2"tubing. 12/11/15 DRILLING SUPPO***RIG JOB, NABORS 7ES*** FIRE 160 GR/FT STRING SHOT FROM 8547.5 -8552.5'. RIH W/RCT 2000-200, TOOLSTRING HUNG UP ON DEBRIS, HAD TO ACTIVATE JARS TO FREE TOOLSTRING, TOOLSTRING WENT SHORT AFTER JARRING. POOH AND SWAP JARS. RBIH W/ RCT 2000-200, SUCCESSFULLY CUT 3.5"TUBING AT 8550'. LOG CORRELATED TO TUBING TALLY DATED 03 APR 1999. JOB COMPLETE. 12/12/15 RECOMPLETION Make RCT cut of tubing at 8550'. POOH and stand back e-line. RIH with drillpipe and engage top of tubing with spear, pick up clean and TOOH. Begin laying down 3-1/2"tubing. 12/13/15 RECOMPLETION Finish laying down 3-1/2"tubing. MU BHA#5 with re-dressed spear. RIH to 2,500' and set storm packer to test BOPs (waived by State), BOPE all test good. 12/14/15 RECOMPLETION Pulled storm packer from BOP test, continued TIH to 3-1/2"tubing stub. Spear tubing,jar for 2 hours with no movement. Release spear, TOOH and lay down spear. PU G-spear and RIH to retrieve next section of 2-3/8" patch. Engage and pull 2-3/8" patch, begin TOOH. 12/15/15 RECOMPLETION POOH with BHA#6. laid down 2 3/8 patch. and spear assembly. RU E-line RIH with string shot and RCT cutter. Made cut at 8755 ft. RD E-line. RIH with BHA#7 Spear assembly with 3.01 grapple. 12/15/15 DRILLING SUPPO***RIG JOB, NABORS 7ES***CUT TUBING AT 8755.2'WITH RCT-2000-200 CCL TO CUTTER 9.4' CCL STOP AT 8745.8' PRIOR TO CUT FIRED STRING SHOT WITH MID SHOT AT 8755' CCL TO MID SHOT 5.5 CCL STOP AT 8744.5' CREW ON STANDBY IN CAMP TRUCKS ON LOCATION WAITING FOR RIG TO TRIP PIPE AND PULL ON TUBING STUB 12/16/15 RECOMPLETION POOH with BHA#7. Recovered 255 ft of 3.5 8rd completion. RIH with BHA#8 Spear assembly. Engaged fish at 8792 ft RKB. engaged spear. Jarred for 3 hrs. @ 65 K over string. and pulling to 225 K with out any movement. Release spear. Slip and cut DL.POOH with BHA#8 Pick up BHA#9 12/17/15 RECOMPLETION RIH with 2.25 spear assembly. Pulled last of 2 3/8 patch from 3.5 Tbg. POOH lay down fish. RIH with test packer 12/18/15 RECOMPLETION test IA to 216Q psi for 15 min's at 8780.0 ft. lay down drile3e and remaining production tubing. Start in hole witlWrnpletion Cummulitive sea water loss= 2934 BBL's 12/19/15 RECOMPLETION Continue to RIH with completion. set packer @ 8696 ft. Test Tbg to 3000 psi and IA 2500 psi. Chart recorded. Spaced out well. Land hanger. Shear SOV. Install BPV and test from below to 1000 psi. Begin BWM on BOPE. Cumulative losses to well = 3020 BBL's sea water 12/20/15 RECOMPLETION Run Completion as designed. Pump corrosion inhibitor, Land completion. Begin BWM on the BOP stack. 12/25/15 DRILLING SUPPO SET BAITED PULLING TOOL ON B&R @ 8714'SLM. PULLED SOV FROM 8622' RKB, SET OV @ SAME. ATTEMPTED DD IA, TBG TRACKING. ATTEMPTED CHECK SET, UNABLE TO WORK PAST 8160' SLM. IN PROGRESS. 12/26/15 DRILLING SUPPO CONFIRMED OPEN POCKET @ 8622' RKB. PULLED CATCHER ASS'Y, AND BALL& ROD FROM 8710' SLM; RECOVERED DROPPED OV. SET OV @ 8622' RKB. PULLED DV @ 4979' RKB. IN PROGRESS. 12/27/15 DRILLING SUPPO SET GLV @ 4979' RKB. PULLED RHC PLUG BODY FROM 8743' RKB. MEASURED BHP @ 9141' RKB (2252 PSI). DRIFTED INTO 2 3/8" LINER W/ 1.75" BAILER, TAGGED @ 9174' SLM. COMPLETE. KUP D 2L-307 �/ \i Ct�rtt)CtyP�"11lis Well Attribut _ Max Angle D TD ♦ Wellbore API/UWI Field Nae Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) AtaSka`lr1 . m C.orwcePtdliips 501032028400 TARN PARTICIPATING AREA PROD 67.82 6,291.21 9,727.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2L-307,1/18/20163:55:24 PM SSSV:NONE 45 11/2/2014 Last WO: 12/20/2015 43.40 4/3/1999 vartualacbamahc.(actual) Annotation Depth(kKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,174.0 12/27/2015 Rev Reason:WORKOVER,GLV CIO lehallf 1/8/2016 HANGER;30.4-. 1',I'°1;. __ Casing Strings Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 115.0 115.0 62.58 H-40 WELDED , I Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftK6) Set Depth(ND)... Wt/Len(I...Grade Top Thread ' �$ SURFACE 75/8 6.875 34.7 2,905.0 2,307.2 29.70 L-80 BTC-MOD L. Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread L• PRODUCTION 5.523.5" 51/2 4.950 33.0 9,709.0 5,755.3 15.50 L-80 LTC-MOD ��I @ 8848' „a„,,,,„,n„,„„„,,,,,,,,,,,,,,,,,,,,,,,,,, ,pL Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(k..1 Set Depth(ND)(...Wt(Ib/k) Grade Top Connection TUBING 3 1/2 2.992 30.4 8,800.0 5,238.8 9.30 L-80 EUE 8rd Completion Details -4‘...-CONDUCTOR;35.0-115.0 Nominal ID Top OMB) Top(ND)(MB) Top Incl(°) Item Des Com (in) • 30.4 30.3 0.04 HANGER EUE 8rd FMC Gen V hanger 3.500 8,565.3 5,114.9 61.42 SLEEVE CMU W 2.812 BX profile 2.812 8,676.3 5,170.4 58.30 LOCATOR Locator sub 2.950 • 8,676.7 5,170.6 58.28 SEAL ASSY BAKER SEAL ASSY 3.020 8,679.7 5,172.2 58.18 PBR Baker PBR 4.000 SURFACE;34.7-2,905.0 8,693.3 5,179.4 57.71 SNAP LATCH Anchor assembly 3.000 II 8,694.9 5,180.3 57.66 PACKER Baker S Hyd.Packer 2.760 GAS LIFT,4,979.5 - 8,743.5 5,206.9' 56.07 NIPPLE X LANDING NIPPLE 2.750 8,792.8 5,234.7 55.19 OVERSHOT Poor boy overshot 3.630 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 8,796.9 8,847.4 5,266.2 9.30 L-80 EUE8rdMOD Completion Details SLEEVE;8,565.3 Nominal ID Top(RKB) Top(ND)(RKB) Top!min Item Des Com (in) 8,820.2 5,250.4 54.71 NIPPLE CAMCO D NIPPLE-MILLED TO 2.80"ON 8/3/2011 2.800 8,829.1 5,255.6 54.55 LOCATER BAKER LOCATOR 2.985 8,829.6 5,255.8 54.54 SEAL ASSY BAKER 80-40 CSG SEAL ASSEMBLY 2.985 cAs IJ FT.9,622.3 - Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(RKB) (RKB) (1 Des Com Run Date ID(in) 9,185.0 5,460.2 55.51 WHIPSTOCK 3.5 WEATHERFORD WHIPSTOCK 8 LATCH 9/17/2011 9,193.7 5,465.1 55.55 PACKER 3.5 WS-R-BB PACKER SET FOR WHIPSTOCK 9/16/2011 1.250 LOCATOR 8,876.3 BASE SEAL ASSY;8,676.7 ._ Perforations&Slots PBR;58797 I Shot SNAP LATCH.8,693.3 I OE Dens Top(ND) Btm(ND) (shots/ PACKER,8.8949 h. Top((KB) Btm((MB) (kKB) (RKB) Zone Date ft) Type Com Tubing-Pup;8,699.1 9,210.0 9,240.0 5,474.3 5,491.3 T-2,2L-307 4/26/1999 4.0 IPERF 180 DEG PHASE Mandrel Inserts Tubing-Pup;8,733.3 a t i n NIPPLE.8,743.5 N Top(ND) Valve Latch Port Size TRO Run Top(MB) (kKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 4,979.5 3,504.7 Camco KBG 1 GAS LIFT GLV INT 0.188 1,923.0 12/27/2015 111 2 8,622.3 5,142.8 Camco KBG 1 GAS LIFT OV INT 0.250 0.0 12/26/2015 OVERSHOT,8,792.8 I I Notes:General&Safety - End Date Annotation 10/24/2011 NOTE:ADDED LATERALS L1,L2,L2-01 1/8/2016 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;8,820.2 I LOCATER,8,829.1 alts SEAL ASSY,8,829.5 SLOTS;9,179.7-10,613.9 11 I! IPERF;9,187.0.9,192.0 WHIPSTOCK;9,185.0 LINER L1;9,178.9-10,624.0 PACKER;9,193.7 IPERF;9,210.0-9,240.0 PRODUCTION 5.53.5" 8648',33.0.9,709.0--. • l6r6 • 2..5Cs> GG WELL LOG TRANSMITTAL#902972130 To: Alaska Oil and Gas Conservation Comm. January 8, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 OD Anchorage, Alaska 99501 D2A t t2O1. K.BENDER RE: Pipe Recovery Record: 2L-307 Run Date: 12/8/2015, 12/11/2015, and 12/15/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2L-307 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20284-00 Pipe Recovery Record (Field Print) 1 color log-each 50-103-20284-00 SC/00U PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: • • 42:6 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 8, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2L-307 Run Date: 3/7/2012 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 2L-307 Digital Data(LAS), Digital Log file 1 CD Rom 50-103-20284-00 SCANNED 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.wood@halliburton.com Date: /22 /V2.. Signed: h,4442-- 110 19 2-S6 2{3`61 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 20, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Whipstock Setting Record: 2L-307 Run Date: 9/16/2011 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 2L-307 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20284-00 S,."H`Ea - l PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND;R TURNINGA COY 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.wood@halliburton.com Date: Signed: I .: • 4111 z.toos l9 V•2 5C WELL LOG TRANSMITTAL G� To: Alaska Oil and Gas Conservation Comm. September 15, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2L-307 Run Date: 8/28/2011 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 2L-307 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20284-00 SCANNED 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.wood@halliburton.com Date: 0--/S0/1 I Signed: Pag -i WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 6, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2L-307 Run Date: 8/23/2011 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 2L-307 • Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20284-00 SCANNED► 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.wood@halliburton.com Date: TL. Signed: L ,1 _. r---- WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. J q' Z ,95& Well History File f:I , Digital Data Added to LaserFiche File [I CO's - # 0 Yes I] No - IJ OVO's - # 0 Yes 0 No - IJ Diskettes - # 0 Yes [I No - Oversized Material Added to LaserFiche File [I Maps # IJ Yes 0 No - 0 Mud Logs # - IJ Yes [I No I] Other # IJ Yes 0 No - General Notes or Conunents about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other ("y" Install Patch Alter Casing r PUN Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program f Operat. Shutdow n "` Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ( Exploratory (-" + 198 -256 _ 3. Address: 6. API Number: Stratigraphic r Service "' 00 P. O. Box 100360, Anchorage, Alaska 99510 - 50 103 - 20284 - 00° 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380051 - . 2L - 307 9. Field /Pool(s): Kuparuk River Field / Tarn Oil Pool 10. Present Well Condition Summary: Total Depth measured 9727 feet Plugs (measured) None true vertical 5765 feet Junk (measured) None Effective Depth measured 9581 feet Packer (measured) 6455, 8609, 8804, 9194 true vertical 5684 feet (true vertucal) 4245, 5136, 5241, 5465 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16" 115' 115 SURFACE 2870 7.625" 2905' 2307' PRODUCTION 9676 5.5" x 3.5" 8848' x 9709' 5267' x 5755' RECEtvED 5k,kotkiEDIJF, 01 9 21)11 MIY A ',5tl Perforation depth: Measured depth: 9210' - 9240' True Vertical Depth: 5474' - 5491' Mika Oil & fia$ Cans. Commission Ancnor:iga Tubing (size, grade, MD, and TVD) 3.5, L -80, 8810 MD, 5244 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 35KB PACKER @ 6455 MD and 4245 TVD PACKER - BAKER 35KB PACKER @ 8609 MD and 5136 TVD PACKER - BAKER 35KB PACKER @ 8804 MD and 5241 TVD PACKER - 3.5 WS -R -BB PACKER @ 9194 MD and 5465 TVD NIPPLE - CAMCO DS NIPPLE @ 511 MD and 510 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 304 799 0 -- 212 Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development' ` Service r Stratigraphic t"` 15. Well Status after work: > Oil gro Gas r WDSPL r Daily Report of Well Operations XXX GSTOR WIND r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Jill Long as 263 -4093 Printed Name _1 Lon • , Title CTD Engineer �' 0 / Signature , , i ((— Phone: 263 -4093 Date c.w "J{ Form 10-404 Revised 1 o E V I S o v 2 20i f f` �8, Su • • ' Ori inal Only c KUP 2L 307 ConOCOtlps , _ , W �_f�". ma ",„, 1:: Wellbore APIlUWI 'Field Name Well Status Inc! (1 MD (ftKB) Act Bhn (ftKB) } Irk 501032028400 TARN PARTICIPATING AREA PROD 67.82 6,291 21 9,727.0 Comment H2S (ppn) Dab Annotatio End Date KB Grd ON Rig Release Date "' SSSV: NIPPLE 10 1/14/2010 Last WO: 43.40 4/3/1999 5056 sg 21a +Rk.' ,n�..r� . _ - - __ aa.A.y� ,..� notation Deptt h (ftKB) End Dal Annotation Last Mod...I End Date Last Tag: SLM 1 9,428.0 8/6/2011 Rev Reason: ADD SIDETRACKS nmam 1 1 11/4/2011 ... ... HANGER, s - I."''' -:- = Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 35.0 115.0 115.0 62.58 H-40 WELDED - _`._,...-___..... ■ - 6,1 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Deepth (TVD) ... String Wt... String ... String Top Thrd �::' SURFACE „ 7 5/8 6.750 _ 34.7 _ 2, 0 _ .2,307.2 29.70 L BTC MOD iiiSt Casing Description String 0... String ID ... Top (ftKB) Sat Depth (1... Set Depth (TVD) .. String Wt_. String ... String Top Thrd PRODUCTION 5 1/2 4.950 33 0 9,709.0 5,755.3 15.50 L-80 LTC MOD 5 5x3 5" Tubing Strings CONDUCTOR, _ Tubing Description String 0... String ID Top (ftKB) Set Depth (1... Set Depth (WD) String Wt... String !String Top Thrd 3s115 TUBING � 31/2 I 2992 1_ 152 1 8809.6 ! 52444 930 L y _ - EUE8rdMOD NIPPLE, 511 ;; ' Completion Details Top Depth (WD) Top Inel Nomi... Top (ftKB) (1K (1 Item Description Comment ID (in) g 15.2 15.2 -2.14 HANGER FMC GEN V TUBING HANGER 3.500 q i 511.0 510.2 3.57 NIPPLE CAMCO DS NIPPLE 2.875 8,680.2 5,172.5 57.20 SLEEVE -C BAKER CMU SLIDING SLEEVE w/2.813" CAMCO PROFILE (CLOSED 2.813 SURFACE, 7/12/2011) 35 - 2,905 w : �a_._. _..� _ - _ ____. - __ era: 8,782.4 5,229.0 55.38 NIPPLE CAMCO D NIPPLE MILLED TO 2.80" ON 8/3/2011 2.800 11: 8,791.3 5234.0 55.22 LOCATER BAKER LOCATOR 2.985 GAS LIFT _ as7s 8,791.8 5,234.3 55.21 SEAL ASSY BAKER 80 CSG SEAL ASSEMBLY 2.985 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... String String Top Thrd ■■ '" w STRADDLE ASSY 2 3/8 1 992 6,448 4 _ 8 850 0 5,267 9 4.40 1-80 Hydril 511 , r Completion Details , x , - a PACKER, 6,455 _ Top Depth (ND) Top Intl Nom... TooPo(B) ( B) (1 Item Description Commend _ 10 (in) 6,448.4 4,242.6 66.71 DEPLOY DEPLOYMENT SLEEVE 2.250 _ 6,454.5 4,245.0 66.64 PACKER BAKER 35K8 PACKER 1.810 8,600.6 5,132.3 60.52 SEAL ASSY NO GO IS 0.42' FROM TOP SEAL ASSEMBLY (MULE SHOE) w/ 2' 1.810 SPACEOUT SEAL ASSY," _ _. - 8,601 8,603.1 5,133. - �� 5 60.45 DEPLOY DEPLOYMENT SLEEVE 2.250 DEPLOY, 6,603_- -. ; ' . - _ 8,609.2 5,136.4 60.30 PACKER BAKER 35KB PACKER 1.810 _.`__ _ 4 . _ ... _. 1 II 8,794.4 5,235.8 55.17 Centralizer CENTRALIZER 1.992 SLEEVE 8,794.8 5,236.0 55.16 Centralizer CENTRALIZER 1.000 8.680 I 11 8,7952 5,236.2 55.15 SEAL ASSY NO GO IS 0.42' FROM TOP SEAL ASSEMBLY (MULE SHOE) w/ 2' 1.810 SPACEOUT GAS LIFT, _ - - 8,797.6 5,237.6 55.11 DEPLOY DEPLOYMENT SLEEVE 2.250 8.730 8,803.7 5,241.0 55.00 PACKER BAKER 35KB PACKER 1.810 ' 8,849.3 5,267.5 54 90 MULE SHOE MULE SHOE 1.810 Other In Hole (Wireline retrievable plugs, valves, pumps fish etc.) Top Depth NIPPLE,8,782 1 rti.k- OW) Topincl Top B) (ftKB) (^) Descnption Comment Run Date ID (in) LOCATER, 9,185 5,460.2 55.51 WHIPSTOCK 3.5 WEATHERFORD WHIPSTOCK & LATCH 9/17 /2011 , , 9194 5465.1 s 7e, e 55.55 PACKER 3.5 WS R BB PACKER 9/16/2011 1.250 8 ]94 Centrauxer Slots 8,795 _ -- `� Perforations & SEAL ASSY, M.7 Top Shot DEPLOY, 8,798 -- 9,210 9240 Top (TVD) Btm (TVD) Dens SEALA - - -- TP ( ftKB ) Bbn ( ftKB ) (ftKB) (ftKB) Zone Date ( Type Comment 5.798 SA/3.7 5,491 0IT -2, 2L -307 4/26. 4 0 1PERF 180 DEG PHASE PACKER, 8,804 Notes: General & Safety End Date i Annotation 10/7/2010 NOTE View Schematic w/ Alaska Schematic9. 8/20/2011 NOTE: SUSPECT TUBING LEAK IS BETWEEN 8767 & 8749' RKB MULE SHOE, `111 .0. 8,849 WHIPSTOCK, - 9,185 PACKER, 9,194 IPERF,_ 9,210 -9,240 1 ✓ SLOTS, 9,139- 10,164 PRODUCTION 5.543.5', 1 ' . 33-9,709 TD (2L -307), , 9,727 SLOTS,_!' 9,180- 10,614 ' SLOTS, _ IF _ 9,602-10,206 \ ma4 ` -- LINER L2-01, 9,138-10,164 LMI LINER L2, 9,593- 10,218 'I - LINER L,, 'I - 9,119-10.624 __ . Mandrel Details a 68tl91i Top Depth Top Port i^"Y' ,. (TVD) Ind OD Valve Latch Size TRO Run Stn Top(NKB) (ftKB) (°) Make Model lin) Serf . typ. TYPn tin) (psi) Run Date Com... 1 1 4,978.5 3,504.1 55.69 CAMCO KBG-2 9 1 GAS LIFT OV INT 0.313 0.0 10/28/2011 10:30 2 8,729.8 5,1992 56.32 CAMCO KBG- 29 -_ - � GAS LIFT OPEN 0.000 0.0 7/1/2011 4:00 III • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 24, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT): 2L -307 Run Date: 8/9/2011 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 2L -307 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50 -103- 20284 -00 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.wood@halliburton.com a� Date: ��'�✓ Signed: L • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 22, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2L -307 Run Date: 8/19/2011 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 2L -307 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20284 -00 I 1 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.wood@halliburton.com r AL Date: a, l �,,- (, Signed: �� ct ?-ZP • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 22, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2L -307 Run Date: 8/15/2011 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 2L -307 Digital Data in LAS format, Digital Log Image file I 1 CD Rom 50 -103- 20284 -00 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.wood@halliburton.com Date: p 1 Signed: • • ...--.S. WELL LOG TRANSMITTAL I' PROAcrivE DiMiNOSTic SERViCES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue � Suite 100 ,;. UMW .' ,A li G fi I 201'i 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. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. RECEIVED Attn: Robert A. Richey 130 West International Airport Road AUG ). 9 2011 Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 - ON & Gas Cons. COMMISSIOR Anchorage 2 02 8q 1) Caliper Report 09- Aug-11 2L -307 1 Report / CD 50- 103 -2 -00 / �'� ? (� 9 2) Caliper Report 10 -Aug-11 2N -304 1 Report / CD 50-103 ,1u3$ Signed : „� _ .. �� Date : 20-1 0 4-v` � 6 l i Print Name: l'L)w0.-.. k- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245.8951 FAx: (907)245 -8952 E : PDSANCHORAGE(0)MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:Wrchives\MIT Archives \ 2011\ 08 - August\ 2L- 30TCPAI_Kup_Caliper_Template \CD_ Parts \ConocoPhillips Transmit.docx I CIS -02 510 1 0 • 1 IN Memory Multi- Finger Caliper �r S Log Results Summary I Company: ConocoPhillips Alaska Inc. Well: 2L-307 Log Date: August 9, 2011 Field: Tarn I Log No.: Run No.: 10259464 ZX70 State: Alaska 2 API No.: 50- 103 - 20284 -00 Pipet Desc.: 3.5" 9.3 Ib. L -80 Top Log Intvll.: Surface 1 Pipet Use: Tubing & Casing Bot. Log Intvll.: 9,270 Ft. (MD) Inspection Type : Pre CTD- Sidetrack Inspection 1 COMMENTS : This caliper data is correlated to tubing tally dated April 3, 1999. 1 This log was run to assess the condition of the tubing and liner with respect to internal corrosive and mechanical damage prior to CTD- Sidetrack operations. The caliper recordings indicate the 3.5" tubing and casing logged appears to be in good to poor condition, I with a possible hole recorded in joint 276 (8,636'). Outside the perforation intervals, a maximum cross - sectional wall loss of 18% is recorded in an area of corrosion in joint 174 (5,442'). The damage recorded appears mostly in the form of a wide line of corrosion (from —4,600 ft. to GLM 2), sometimes spread into general corrosion. No significant I.D. restrictions are recorded throughout the tubing and casing logged. I This is the second time a caliper has been run in this well and the 3.5" tubing has been logged. A comparison of the current and previous log (August 16, 2007) indicates an increase in corrosive damage I during the time between logs. A graph illustrating the difference in maximum recorded wall penetrations on a joint-by-joint basis between the current and previous log is included in this report. The summary report is an interpretation of data provided by Halliburton Well Services. 1 3.5" TUBING & CASING - MAXIMUM RECORDED WALL PENETRATIONS : Possible Hole ( 94 %) Jt. 276 @ 8,636 Ft. (MD) I Line Corrosion (82 %) Jt. 203 @ 6,343 Ft. (MD) Line Corrosion ( 79 %) Jt. 216 @ 6,777 Ft. (MD) Line Corrosion (79 %) Jt. 196 @ 6,146 Ft. (MD) Line Corrosion ( 77 %) Jt. 213 @ 6,680 Ft. (MD) 1 3.5" TUBING & CASING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : Corrosion ( 18 %) Jt. 174 @ 5,442 Ft. (MD) II Corrosion ( 17 %) Jt. 166 @ 5,206 Ft. (MD) Corrosion (17 %) Jt. 172 @ 5,381 Ft. (MD) Line Corrosion ( 17 %) Jt. 269 @ 8,424 Ft. (MD) Corrosion ( 17 %) Jt. 172 @ 5,381 Ft. (MD) 1 3.5" TUBING & CASING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded in the interval logged. 1 1 ProActive Diagnostic Services, Inc.,! P.U. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (251) 565 -1369 E -mail: PDS:a�memorylog,com 1 Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 ' • • Mandrel Orientation ' 2L -307 Joint No. Tool ConocoPhillips Deviation Alaska, Inc. Tarn August 9, 2011 Mandrel No. Latch Orientation 159.2 57 1 10:30 ' 278.2 55 2 4:00 I t 1 ' ( Field Engineer: J. Conrad Analyst: HY. Yang Witness: B. Boehme ProActive Diagnostic Services, Ir. :::ox 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 I • • Correlation of Recorded Damage to Borehole Profile ■ Pipe 1 3.5 in. (-8.8' - 9262.8') Well: 2L -307 Field: Tarn I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 9, 2011 I I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 1 -- -6 25 770 • 1 50 1543 75 2321 I 100 3102 I 125 3879 150 —�� h I 4655 Q I GLM 1 175 5 466 E c I Z 200 6247 a 225 —=� 7030 1 250 7814 I GLM 2 275 k 8589 I 294 9263 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) I ' I I Bottom of Survey = 294 I I I • • I I 1113".. Maximum Recorded Penetration �. Comparison To Previous I Well: 2L -307 Survey Date: August 9, 2011 Field: Tarn Prey. Date: August 16, 2007 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 Ext. No. 10000429 Country: USA Tubing: 3.5" 9.3 lb L -80 EUE 8rd MOD I Overlay Difference I Max. Rec. Pen. (mils) Diff. in Max. Pen. (mils) 0 50 100 150 200 250 - 300 - 200 - 100 0 100 200 300 0.1 0.1 I 5 - 5 15 15 24 __ 24 34 34 I 44 44 ' 54 54 64 —_ 64 I 74 _ 74 84 — 84 94 — 94 I 104 104 114 114 1 124 - 124 E 134 E 134 e 144 .3 144 b 154 ' y S 154 161 . ! 161 I 171 171 i 181 181 191 191 201 201 1 211 211 221 221 231 - 231 241 ! 241 2 51 251 261 ! 261 I 271 I 271 278 I I I 278 1 -75 -50 -25 0 25 50 75 August 9, 2011 ■August 16, 2007 Approx. Corrosion Rate (mpy) I 1 I I • • I PDS Report Overview I Body Region Analysis Well: 2E-307 Survey Date: August 9, 2011 Field: Tarn Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) I Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8rd MOD Analyst: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. I 3.5 in. 9.3 ppf L -80 EUE 8rd MOD 2.992 in. 3.5 in. 6.0 in. 6.0 in. I Penetration(% wall) Damage Profile (% wall) 200 MINN Penetration body rrrr Metal loss body ---- 0 50 100 I 0 _- 150 -_ 100 I 50 45 r- I 0 -y 0 to 20 to 40 to over 20% 40% 85% 85% 95 I Number of joints analysed (total = 307) 175 9 120 3 I 145 Damage Configuration (body) GLM 1 150 193 ■ _ 100 .. ' 50 243 I 0 Isolated General Line Other Hde/ Pitting Corrosion Corrosion Damage Pos. Hole GLM 2 I Number of joints damaged (total = 133) 13 17 102 0 1 Bottom of Survey = 294 288 I I I I I • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf L -80 EUE 8rd MOD Well: 2L -307 I Body Wall: 0.254 in. Field: Tarn Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA .Survey Date: August 9, 2011 I Joint Jt. Depth Penn. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 -9 0 0.02 9 0 2.93 Pup 1 6 0 0.03 12 3 2.89 • 1.1 26 0 0.03 11 3 2.90 Pup • 1.2 32 0 0.03 11 2 2.92 Pup I 1.3 38 0 0.02 7 1 2.92 Pup 1.4 44 0 0.03 11 3 2.88 Pup ■ 1.5 48 0 0.03 11 0 2.91 Pup ■ 2 50 0 0.03 11 3 2.92 • I 3 82 0 0.03 12 2 2.92 • 4 114 0 0.02 9 2 2.92 ■ 5 145 0 0.03 10 2 2.91 • 6 176 0 0.03 12 2 2.92 ■ I 7 207 0 0.03 12 2 2.91 an 237 0 0.03 10 2 2.92 ■ 9 268 0 0.03 11 2 2.91 IN 10 298 0 0.03 10 2 2.91 ■ I ll 330 0 0.03 12 2 2.94 IN 361 0 0.03 10 2 2.91 ■ 13 392 0 0.03 12 2.92 • 14 424 0 0.03 12 3 2.92 • I 15 455 0.03 0.03 11 1 2.93 ' 15.1 486 0 0 0 0 2.88 Camco DS Nipple 16 488 0 0.03 10 2 2.92 • 17 519 0 0.03 10 2 2.92 18 550 0 0.02 9 2 2.92 I 19 582 0 0.04 17 2.91 Shallow Line of Pits. • 20 613 0 0.03 11 2 2.91 • ■ 21 644 0 0.03 11 2 2.91 • 22 676 0 0.03 11 2 2.92 ■ 1 23 707 0 0.03 11 2 2.91 24 738 0 0.02 9 2 2.92 25 770 0 0.03 12 2 2.92 • 26 801 0 0.03 10 2 2.93 IN 27 832 0 0.03 12 2 2.92 ■ I 28 863 0 0.03 10 2 2.90 29 895 0 0.02 9 2 2.94 30 926 0 0.03 12 3 2.93 • 31 957 0 0.03 10 2 2.93 • I 32 988 0 0.03 12 2 2.91 • 33 1017 0 0.03 11 2 2.91 • ■ 34 1048 0 0.02 9 2 2.91 • 35 1079 0 0.03 12 2 2.92 I 36 1110 0 0.02 9 2 2.93 37 1141 0 0.03 11 2 2.93 • 38 1173 0 0.03 12 3 2.93 • 39 1203 0 0.02 8 2 2.90 40 1233 0 0.03 10 2 2.92 ■ I 41 1265 0 0.03 12 2 2.93 ■ 42 1295 0 0.03 11 2 2.92 43 1325 0 0.02 9 2 2.92 Pratio Meta l Loss n Body Page 1 I I • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf L -80 EUE 8rd MOD Well: 2L -307 I Body Wall: 0.254 in. Field: Tarn Inc. Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Nominal I.D.: 2.992 in. Country: USA Survey Date: August 9, 2011 I Joint it. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 44 1356 0 0.02 9 2 2.93 45 1386 0 0.02 9 2 2.92 46 1418 0 0.03 12 2 2.91 47 1449 0 0.03 10 1 2.93 I 48 1480 0 0.02 8 2 2.94 49 1511 0 0.03 10 2 2.92 50 1543 0 0.03 12 4 2.92 51 1574 0 0.03 12 2 2.92 I 52 1605 0 0.03 12 3 2.92 53 1637 0 0.02 9 2 2.91 54 1668 0 0.03 10 1 2.92 55 1699 0 0.03 10 2 2.92 I 56 1729 0 0.03 12 1 2.91 57 1760 0 0.03 11 2 2.92 58 1791 0 0.03 10 2 2.91 in 1822 0 0.03 12 2 2.92 r I 60 1854 0 0.03 11 2 2.92 61 1885 0 0.03 12 2 2.93 IN 62 1916 0 0.03 12 2 2.91 63 1946 0.03 0.03 12 2 2.91 64 1978 0 0.03 12 1 2.92 I 65 2009 0 0.03 11 2 2.92 66 2040 0 0.03 10 2 2.90 67 2071 0 0.03 10 2 2.91 68 2102 0 0.02 8 1 2.91 I 69 2133 0 0.03 12 2 2.91 70 2165 0 0.02 8 2 2.91 71 2196 0 0.02 9 2 2.90 72 2227 0 0.03 11 2 2.90 I 73 2258 0 0.03 12 2 2.91 74 2289 0 0.03 12 2 2.91 75 2321 0 0.03 10 2 2.91 76 2351 0 0.02 9 2 2.91 77 2382 0 0.03 12 2 2.92 I 78 2414 0 0.03 12 2 2.92 79 2445 0 0.03 11 3 2.91 80 2475 0 0.03 10 2 2.93 81 2506 0 0.03 10 .. 2.91 82 2538 0 0.03 11 2.94 83 2569 0 0.03 11 2.93 84 2600 0 0.03 1 2.91 85 2632 0 0.03 12 2.90 I 86 2663 0 0.03 10 _ 2.91 87 2695 0 0.03 12 2 2.92 88 2726 0 0.03 10 2 2.91 89 2758 0 0.03 11 2 2.91 90 2788 0 0.03 11 2 2.91 I 91 2819 0 0.03 12 2 2.91 92 2851 0 0.02 8 1 2.91 93 2882 0 0.02 9 1 2.91 Penetration Metal Loss Body Page 2 I I I • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf L -80 EUE 8rd MOD Well: 2L -307 Body Wall: 0.254 in. Field: Tarn I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 9, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 94 2914 95 2945 0 0.03 12 2 2.91 0 0.02 9 2 2.91 • 96 2976 0 0.02 9 2 2.91 • 97 3008 0 0.02 9 2 2.91 I 98 3039 0 0.03 12 2 2.90 99 3071 0 0.03 10 2 2.91 100 3102 0 0.03 10 2 2.91 101 3133 0 0.03 11 4 2.90 ■ I 102 3163 0 0.03 12 2 2.91 103 3195 0 0.02 9 2 2.92 U 104 3226 0 0.03 10 2 2.91 105 3257 0 0.03 11 3 2.91 I 106 3289 0 0.03 11 1 2.91 107 3320 0 0.02 9 2 2.91 108 3351 0 0.03 11 2 2.90 109 3381 0 0.02 7 2 2.93 B 110 3412 0.04 0.03 10 3 2.89 I 111 3443 0 0.02 8 2 2.90 112 3474 0 0.03 11 2 2.89 113 3505 0 0.02 9 2 2.91 114 3536 0 0.03 12 2 2.91 I 115 3567 0 0.03 11 3 2.90 116 3598 0.05 0.03 10 3 2.90 117 3630 0 0.02 9 2 2.90 118 3661 0 0.02 9 2 2.89 • I 119 3693 0 0.02 9 3 2.91 120 3723 0 0.03 12 2 2.91 121 3754 0 0.03 11 2 2.91 122 3786 0 0.02 9 2 2.91 I 123 3817 0 0.03 10 3 2.91 124 3848 0 0.03 12 2 2.91 125 3879 0 0.02 9 1 2.91 126 3911 0 0.03 10 2 2.89 127 3942 0 0.03 12 2 2.89 I 128 3971 0 0.03 11 2 2.91 129 4002 0 0.03 10 1 2.90 130 4034 0.03 0.03 12 2 2.89 131 4065 0.03 0.02 9 2 2.91 I 132 4094 0 0.03 12 3 2.91 133 4125 0 0.03 12 2 2.91 134 4157 0 0.03 12 1 2.91 135 4188 0.03 0.03 12 2 2.91 I 136 4218 0 0.02 9 2 2.90 137 4249 0 0.03 10 2 2.90 138 4281 0 0.03 12 2 2.91 139 4313 0 0.02 7 2 2.92 1 140 4343 0 0.03 10 2 2.90 I 141 4375 0 0.02 9 2 2.91 142 4406 0 0.03 12 2 2.90 143 4437 0.t)3 0.03 10 3 2.90 I Penetration Bo Metal Loss Body Page 3 I I I • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf L -80 EVE 8rd MOD Well: 2L -307 Body Wall: 0.254 in. Field: Tarn Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 9, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 144 4468 0 0.04 15 1 2.91 Shallow Pitting. 145 4500 0 0.03 12 2 2.90 a 146 4530 0 0.03 12 0 2.89 147 4562 0 0.02 8 0 2.90 I 148 4593 0 0.04 14 1 2.91 Shallow Pitting. ■ 149 4624 0 0.03 12 1 2.90 ■ 150 4655 0 0.05 20 1 2.89 Line of Pits. ■ 151 4686 0 0.03 10 0 2.91 ■, I 152 4717 153 4749 0 0.05 20 1 2.91 Isolated Pitting. ■ 0 0.03 12 0 2.90 ■I 154 4780 0 0.05 20 0 2.88 Line of Pits. ■■ 155 4811 0.05 0.09 34 3 2.91 Line of Pits. 11! 156 4843 0 0.02 9 1 2.92 157 4874 0 0.07 29 1 2.89 Line of Pits. ■■ 158 4905 0.06 0.10 39 5 2.90 Line of Pits. u■ 159 4937 0 0.09 36 3 2.90 Line of Pits. ■■■ I 159.1 4968 0.08 0.09 36 4 2.94 Pup Line of Pits. III 4982 0 0 0 0 2.87 GI .M 1 (Latch 0 10 :30) 159.3 4989 0.17 0.15 59 9 2.94 Pup Line Corrosion. ■■■ 160 5004 0.04 0.12 46 9 2.95 Line Corrosion. i■■■ 161 5031 0.05 0.13 50 10 2.95 Line Corrosion. ■■■ I 162 5063 0.04 0.13 51 12 2.94 Corrosion. ■ ■■ 163 5093 0.06 0.14 55 14 2.93 Corrosion. ■■■ 164 5124 0.09 0.13 51 14 2.93 Corrosion. ■■■ 165 5155 0.08 0.13 50 15 2.94 Corrosion. ■■■ I 166 5186 0.09 0.13 52 17 2.94 Corrosion. i■■ 167 5217 0.08 0.12 49 10 2.93 Corrosion. ■■■ 168 5248 0.08 0.13 50 13 2.94 Corrosion. ■■■ 169 5279 0.07 0.12 47 12 2.95 Corrosion. ■■■ I 170 5311 0.08 0.12 49 19 2.96 Corrosion. i ■■ 171 5342 0.11 0.12 49 14 2.96 Corrosion. ■ ■■ 172 5373 0.09 0.13 52 17 2.95 Corrosion. m■■ 173 5404 0.08 0.11 44 10 2.96 Line Corrosion. ■■■ 174 5434 0.10 0.13 49 18 2.96 Corrosion. i■■ I 175 5466 0.09 0.12 46 11 2.96 Corrosion. ■■■ 176 5497 0.06 0.12 47 11 2.95 Line Corrosion. ■■■ 177 5527 0.06 0.11 42 9 2.96 , Line Corrosion. ■■■ 178 5558 0.10 0.15 59 14 2.95 Corrosion. ■■■ I 179 5590 0.09 0.12 47 13 2.96 Line Corrosion. ■■■ 180 5622 0.10 0.14 54 16 2.99 Corrosion. um 181 5652 0.10 0.13 49 12 2.96 Line Corrosion. ■■■ 182 5684 0.12 0.14 54 11 2.95 Line Corrosion. ■■■ I 183 5715 0.0') 0.13 51 10 2.96 Line Corrosion. mu 184 5746 0.0(1 0.13 51 12 2.94 Line Corrosion. mum 185 5778 0.08 0.13 51 11 2.96 Line Corrosion. ■■■ 186 5809 0.08 0.14 56 11 2.96 Line Corrosion. ■■■ 187 5840 0.1 1 0.17 65 10 2.94 Line Corrosion. ■■■ I 188 5872 0.11 0.16 64 9 2.95 Line Corrosion. ■■■ 189 5903 0.10 0.15 59 12 2.95 Line Corrosion. ■■■ 190 5935 0.13 0.17 66 14 2.96 Line Corrosion. _ Petrtion Metal a Loss Body Page 4 I I I • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf L-80 EUE 8rd MOD Well: 2L -307 Body Wall: 0.254 in. Field: Tarn Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 9, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 191 5966 0.07 0.14 54 15 2.95 Corrosion. mom 192 5998 0.1 1 0.18 72 12 2.94 Line Corrosion. ■om 193 6029 0.1 1 0.19 73 17 2.96 Line Corrosion. l■■■■ 194 6061 0.12 0.18 72 11 2.94 Line Corrosion. ■ ■ ■■■ I 195 6091 0.1 3 0.17 69 13 2.94 Line Corrosion. ■■■■■ 196 6123 U. 13 0.20 79 12 2.94 Line Corrosion. ■■■■■ 197 6153 0.10 0.18 69 13 2.95 Line Corrosion. ■■■■■ 198 6185 0.13 0.16 62 13 2.97 Corrosion. ■■■■1 I 199 6215 0.13 0.14 57 7 2.94 Line Corrosion. 'S... 200 6247 0.1 U 0.20 77 14 2.95 Line Corrosion. •■■■■ 201 6278 0.10 0.16 64 12 2.95 Line Corrosion. ■■■■ 202 6310 0.10 0.13 52 11 2.95 Line Corrosion. ■■im■• I 203 6341 0.16 0.21 82 14 2.95 Line Corrosion. 204 6372 0 0.14 54 8 2.93 Line Corrosion. ■■■■ i■■■ ■l 205 6404 0.14 0.15 61 7 2.94 Line of Pits. i■■■■■ 206 6435 0.15 0.16 64 9 2.94 Line Corrosion. ■■■■ I 207 6467 0.09 0.14 54 8 2.93 Line Corrosion. i■■■■� 208 6497 0.05 0.16 62 13 2.94 Line Corrosion. ■ ■■■■ 209 6529 0.09 0.17 67 14 2.93 Line Corrosion. ■■■■■ 210 6560 0.1:3 0.20 77 13 2.93 Line Corrosion. ■■■■■ 211 6591 0.08 0.16 64 10 2.95 Line Corrosion. ■■■■■ I 212 6623 0.09 0.20 77 13 2.93 Line Corrosion. 11111111•111M1 213 6654 0.14 0.20 77 14 2.94 Line Corrosion. ■■■■■ 214 6686 0.06 0.16 64 11 2.93 Line Corrosion. ■■■■ 215 6717 0.07 0.14 57 7 2.93 Line Corrosion. ■� u■■ I 216 6748 0.13 0.20 79 10 2.94 Line Corrosion. 217 6780 0.07 0.14 56 7 2.92 Line Corrosion. 218 6811 0.13 0.17 67 9 2.94 Line Corrosion. ■■■■ ■■■■� ■ ■■■ 219 6843 0.04 0.14 56 9 2.95 Line Corrosion. i■■■■� I 220 6874 0.17 0.18 72 13 2.92 Line Corrosion. ■ ■■■■ 221 6905 0.1 1 0.17 69 13 2.94 Line Corrosion. moms 222 6936 0.15 0.18 70 12 2.93 Line Corrosion. ■■■■■ 223 6967 0.08 0.16 64 10 2.95 Line Corrosion. ■■■■■ 224 6999 0 0.18 72 12 2.93 Line Corrosion. ■■■ •• I 225 7030 0.0:3 0.16 62 7 2.94 Line Corrosion. 226 7062 0.07 0.13 50 7 2.92 Line Corrosion. i■■■■ ,■■■■1 227 7093 0.12 0.19 74 1 1 2.94 Line Corrosion. ■■■ 228 7125 0.08 0.12 47 5 2.92 Line Corrosion. ■■■■ol' • I 229 7156 0.11 0.18 70 12 2.94 Line Corrosion. Nom 7188 0.13 0.19 76 1 1 2.94 Line Corrosion. ■■■■■ 231 7219 0.06 0.17 67 12 2.94 Line Corrosion. ■■■■■ 232 7251 0.14 0.16 64 9 2.93 Line Corrosion. i■■■■■ I 233 7282 0.04 0.16 62 8 2.94 Line Corrosion. imam 234 7314 0.07 0.18 72 10 2.94 Line Corrosion. mum 235 7345 0.1 1 0.15 61 9 2.93 Line Corrosion. i■■■■■ 236 7376 (1.12 0.17 65 10 2.95 Line Corrosion. ■■ ■■ 237 7407 0.14 0.15 59 9 2.94 Line Corrosion. ■■■■� I 238 7438 0.09 0.15 59 8 2.94 Line Corrosion. ism 7470 (1.1 1 0.17 67 10 2.94 Line Corrosion. ■■■■■ 240 7501 0.1 1 0.17 65 9 2.92 Line Corrosion. I Peneation Meta Loss Body Page 5 I I I 0 • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf L -80 EUE 8rd MOD Well: 2L -307 I Body Wall: Upset Wall: 0.254 in. Field: Tarn 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 9, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 241 7532 0.09 0.14 56 8 2.94. Line Corrosion. moms 7564 0.06 0.14 57 9 2.94 Line Corrosion. mum 243 7595 0.11 0.16 62 11 2.94 Line Corrosion. ■mmo 244 7626 0.1 1 0.16 62 11 2.94 Line Corrosion. ■ UNI I 245 7658 0.09 0.16 64 9 2.94 Line Corrosion. �� 246 7689 (3.10 0.15 59 11 2.93 Line Corrosion. wood 247 7720 0.09 0.17 67 13 2.94 Line Corrosion. mono 248 7751 0.10 0.15 61 9 2.94 Line Corrosion. ammo I 249 7782 0.08 0.17 69 9 2.92 Line Corrosion. �� 250 7814 0.11 0.17 69 10 2.93 Line Corrosion. Noon 251 7845 0.10 0.16 64 15 2.92 Line Corrosion. moo 252 7876 0.08 0.14 57 10 2.94 Line Corrosion. 11111111111111111 I 253 7906 0.10 0.17 65 10 2.94 Line Corrosion. �� 254 7934 0.12 0.16 64 11 2.93 Line Corrosion. mum 255 7965 0.14 0.17 69 13 2.95 Line Corrosion. ■ om 256 7997 0 0.16 62 13 2.94 Line Corrosion. ■mmo 257 8028 0.10 0.16 61 11 2.93 Line Corrosion. mower I 258 8060 0.09 0.16 61 11 2.94 Line Corrosion. ■mmo 259 8091 0.09 0.16 61 14 2.92 Line Corrosion. Noon 260 8122 0.11 0.17 67 11 2.91 Line Corrosion. ■mmo 261 8154 0.09 0.17 65 13 2.93 Line Corrosion. moms I 262 8185 0.07 0.18 71 12 2.92. Line Corrosion. KNEE 263 8216 0.10 0.17 66 12 2.93 Line Corrosion. Immo 264 8248 0.12 0.17 67 15 2.91 Line Corrosion. ■■o■ 265 8279 0.13 0.18 71 12 2.93 Line Corrosion. ■IM■ I 266 8310 0.11 0.17 67 12 2.93 Line Corrosion. Imm■ 267 8341 0.16 0.17 68 15 2.92 Line Corrosion. moo 268 8372 0.09 0.18 71 15 2.92 Line Corrosion. ■mom 269 8403 0.15 0.17 65 17 2.95 Line Corrosion. MEM I 270 8434 0.12 0.17 65 14 2.93 Line Corrosion. �� 271 8464 0.11 0.18 70 13 2.94 Line Corrosion. ammo 272 8496 0.13 0.17 67 13 2.94 Line Corrosion. ■mmo 273 8527 0.18 0.16 64 10 2.93 Line Corrosion. ••u• 274 8558 0.18 0.18 70 10 2.92 Line Corrosion. MUM I 275 8589 0.15 0.17 67 10 2.93 Line Corrosion. Nom= 276 8618 0.13 0.24 94 13 2.94 Possible Hole! ■... 277 8650 0.11 0.14 55 11 2.93 Line Corrosion. 277.1 8679 0 0 0 0 2.81 Baker CMU Sliding Sleeve (Closed 7/12/11) MINN I 278 8685 0.15 0.15 60 9 2.94 Line Corrosion. mono 278.1 8716 0.09 0.13 50 11 2.98 Pup Line Corrosion. 278.2 8731 0 0 0 0 2.92 GLM 2 (Latch C 4:00) 278.3 8737 0 0.03 12 2 2.93 Pup ■ I 279 8751 0.03 0.03 11 2 2.93 ' 279.1 8782 0 0 0 0 2.75 Camco D Nipple 279.2 8784 0 0.03 11 2 2.94 Pup 279.3 8789 0 0 , 0 0 2.98 Baker Locator / Baker Seal Assembly 279.4 8807 0 0 0 0 4.02 5.5" Casing I 279.5 8811 0 • 0 0 0 2.94 5.5" X 3.5" Cross-over 279.6 8812 (3 0.03 11 2 2.96 Pup Top of 3.5" Casing. ■ 280 8822 0 0.03 12 2 2.94 I I Penetration Body Metal Loss Body Page 6 I I • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf L-80 EUE 8rd MOD Well: 2L -307 Body Wall: 0.254 in. Field: Tarn I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 9, 2011 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (FL) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 281 8853 282 8884 0 0.03 11 3 2.92 0 0.03 12 2 2.93 283 8915 0.03 0.02 9 3 2.91 283.1 8947 0 0.02 8 1 2.91 Pup I 284 8951 0.04 0.02 9 2 2.92 285 8982 0 0.03 11 4 2.89 286 9013 0 0.03 12 2 2.92 287 9044 0 0.03 10 2 2.93 I 288 9076 0 0.03 12 2 2.92 289 9107 0 0.03 11 3 2.93 290 9138 0 0.02 9 2 2.93 • 291 9169 0.14 0.37 100 26 2.83 Perforations. Lt. Deposits. I 292 9200 0.33 0.27 100 8 2.85 Perforations. Lt. Deposits. 293 9231 {) 0.07 28 3 2.90 Line of Pits. 294 9263 0 0.01 3 0 2.91 _ Penetration Body I I I 1 Metal Loss Body I 1 I I I Page 7 I I • • I VS PDS Report Cross Sections I Well: 2L -307 Survey Date: August 9, 2011 Field: Tarn Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L -80 EUE 8rd MOD Analyst: HY. Yang I I Cross Section for Joint 276 at depth 8635.690 ft Tool speed = 55 I Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 90% / Tool deviation = 57° I I \ 1 ------- \ I \ � I \ NN t I Finger = 15 Penetration = 0.239 in. Possible Hole 0.24 ins = 94% Wall Penetration HIGH SIDE = UP I r I I I I • • I ca PDS Report Cross Sections I Well: 2L -307 Survey Date: August 9, 2011 Field: Tarn Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L -80 EUE 8rd MOD Analyst: HY. Yang I I Cross Section for Joint 203 at depth 6342.630 ft Tool speed = 50 I Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 90% _ Tool deviation = 69° i / �N i I 1 . I I I I �-/---_ Finger = 10 Penetration = 0.209 in. Line Corrosion 0.21 ins = 82% Wall Penetration HIGH SIDE = UP 1 1 I I I 0 • I _ PDS Report Cross Sections I Well: 2L -307 Survey Date: August 9, 2011 Field: Tarn Tool Type: UW MFC 24 Ext No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE 8rd MOD Analyst: HY. Yang I I Cross Section for Joint 174 at depth 5442.030 ft Tool speed = 51 I Nominal ID = 2.992 Nominal OD = 3.5 . Remaining wall area = 82% Tool deviation = 57° / I I / I / I i / I \ 1 _ I Finger = 24 Penetration = 0.095 in. Corrosion 18% Cross - Sectional Wall Loss HIGH SIDE = UP I I I I I • • I S PDS Report Cross Sections V„ I Well: 2L -307 Survey Date: August 9, 2011 Field: Tarn Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L -80 EUE 8rd MOD Analyst: HY. Yang I 1 Cross Section for Joint 166 at depth 5206.280 ft Tool speed = 51 I Nominal ID = 2.992 Nominal OD = 3.5 ftwo Remaining wall area = 83% Tool deviation = 56° / ` I I I i 1 I i i 1 \ / I ♦ / I Finger = 15 Penetration = 0.106 in. Corrosion 17% Cross - Sectional Wall Loss HIGH SIDE = UP I I I I I I . KUP 2L -307 ConocoPhillips Attributes millkgle & IND TD Alaska. Inc W ellbore APUUWI Field Name Well Status Intl (1 MD (MB) Act BM (Mal) ... �, 501032028400 TARN PARTICIPATING AREA PROD 67.82 6,291.21 9,727.0 I "' Comment H2S (ppm) Date Amotation End Date KB- .l (N) Rig Release Date Well conga: -2L -307 7/24/2011 dual 7:44:35 AM SSSV: NIPPLE 10 1/14 /2010 Last WO: 43.40 4/3/1999 Schematic- Actual Amaatlan Depth (RK End Date Amaation Last Mod ... End Date Last Tag: SLM 9,206.0 7/21/2011 Rev Reason: PULL VALVE, TAG, NOTE ninam 7/24/2011 Casing Strings ° �'��°�� String HANGER, 15 �wj '} Casing Description Sng 0... String ID ... Top FMB) Set Depth h... Set Depth (N String D)... Sng WE.. Stu String 11N ng... Sng Top T L ,j CONDUCTOR 16 15.062 35.0 1150 1150 62.58 H Welded l t Casing Description String 0... String ID ... Top (MB) Set Depth n... Set Depth (ND) ... String WE.. String ... String Top Thrd SURFACE 75/8 6.750 34.7 2,905.0 2,307.2 29.70 L-80 BTC-MOD Gating D escrip ti on Str O._ String ID ... Top (NB) Set Depth (L.. Set D epth (1VD) ... Strip WL Str ing... String 7hrd ` PRODUCTION 51/2 4.950 33.0 9,709.0 5,755.3 15.50 L-80 LTC -M Top 5.5x3.5" I Tubing Strings Tubing Description String 0... String ID ... Top (PPS) Set Depth (r... Set Depth (ND) ... String WE.. String... String Top Thrd TUBING 31;2 2.992 15.2 8,809.6 5,244.4 9.30 L-80 EUE8rdMOD Completion Details Top Depth I (ND) Top Ind Nola.. (M03) (fie) ( ° 1 Item Description Comment W M1 il 15.2 15.2 -2.14 HANGER FMC GEN V TUBING HANGER 3.500 i MEM 511.0 510.2 3.57 NIPPLE CAMCO DS NIPPLE 2.875 • CONDUCTOR, 8,680.2 5,172.5 57.20 SLEEVE -C BAKER CMU SLIDING SLEEVE w /2.813" CAMCO PROFILE (CLOSED 2.813 35 l . 7/12/2011) I 8,782.4 5,229.0 55.38 NIPPLE CAMCO D NIPPLE 2.750 NPR.E,511 8,791.3 5,234.0 55.22 LOCATER BAKER LOCATOR 2.985 8,791.8 5,234.3 55.21 SEAL ASSY BAKER 80-40 CSG SEAL ASSEMBLY 2.985 ' Perforations & Slots Shot Top (7Vq elm (1VD) Dens Top ( (roc ) EMI s) MKS) 1 W Zone Date (sh... type Comment 9,210 9,240 5,473.7 5,491.0 T -2, 2L -307 4/26/1999 4.0 IPERF 180 DEG PHASE fl Notes: General & Safety 11 l End Date Annotation I 10/7/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic 9.0 SICFAcE J 7/22 2011 NOTE: CONFIRMED TUBING LEAK@ 8730" WITH EUNE LDL pp l I GAS LFT, 4976 I - SLEEVE-C, •, , 8,680 GAS LIFT, a !30 I ■ NIPPLE, 8,782 I LOCATER, 6,791 SEAL ASSY, 8,792 I • • • I Mandrel Details Top Depth Top Port (TVD) In OD Valve Latch ate 1RO Mai Top (11 B) MKS) r) Make Mods M) sere Type Type ON IPA Run Date Can_ 1 4,978.5 3,504.1 55.69 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 4/3/1999 1 IOLAF, 2 8,729.8 5,199.2 56.32 CAMCO KBG -2 -9 1 GAS LIFT OPEN 0000 0.0 7/1/2011 1 9.2169240 I PRODUCTION 5.5X3.5'. 33 -9709 TD, 9,727 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 28, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 2L -307 Run Date: 7/22/2011 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 2L -307 Digital Data in LAS format, Digital Log Image file 1 q 8 1 CD Rom 50- 103 - 20284 -00 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.wood @halliburton.com Date: 1 Signed: �( g aak., - - EEI`~/EQ SEP 1 2 ?_007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons, Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q Jet Pump to GL Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ o• Exploratory ^ 198-256 " 3. Address: Strati ra hic g p ^ Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20284-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 2~ y.u-°7 2L-307 8. Property Designation: 10. Field/Pool(s): ADL 380051 ALK 4599 Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 9727' feet true vertical 5765' feet Plugs (measured) Effective Depth measured 9581' feet Junk (measured) true vertical 5684' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 2905' 7-5/8" 2905' 2307' , , PRODUCTION 8848' S-1/2" 8848' 5267' PRODUCTION 861' 3-1/2" 9709' 5755' Perforation depth: Measured depth: 9210' - 9240' true vertical depth: 5474' - 5491' ~~ ~0~ ~. ~ ~t1~7 ~~' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8848' M D. Packers &SSSV (type & measured depth) SEAL =Baker 80-40 Seal = 8791' SSSV= NIP SSSV= 510' -° °'~'"'~°""~_... 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A ~ l~F~, ~~~ `~ ~ Zd~~ 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 230 395 445 2215 239 Subsequent to operation 97 .r' 239 6 972 236 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: Oi10 ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob Christensen /Bob Buchholz Printed Name Rob rt W. B chholz Title Production Engineering Technician Signature i Phone 659-7535 Date D ~•2G - 0 7 Form 10-404 Revised 04/2004 O R { ~ ~ ~ ~ i~-{; ~ Submit Original Only i ~ 2L-307 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/31/07 PULL JET PUMP FROM 8680' RKB, CLOSE CMU SLIDING SLEEVE AT 8680' RKB. OBTAIN SBHPS AT 9206' SLM W/GRADIENT STOP AT 9000' SLM. MITxIA TO 3500#. GOOD TEST. MITIA pre T/I/0= 530/0/240. initial T/I/0= 550/3500/260. 15 min reading 550/3425/260. 30 min reading TJI/0= 550/34001260. (pass ) 08/15/07 SET CATCHER @ 8782' RKB, PULLED EXT PKG DV @ 8729' RKB. ATTEMPTED REPLACE DV WITH 5/16" OV, NO SUCCESS. IN PROGRESS. 08/16/07 LOGGED CALIPER FROM 8800' TO SURFACE, GOOD DATA. BRUSHED GLM @ 8729' RKB; SET 5/16" OV. TESTED TSG, PASSED. PULLED CATCHER SUB @ 8782' RKB. 08/19/07 WELL RETURNED TO PRODUCTION AS A GAS LIFTED OIL PRODUCER. `~` 08/22/07 TIFL (passed) T/I/0= 220/1000/250. SI lift gas and well, shot initial IA-FL @ 2850' (600 AV). 5879' above OV @ 8729' station # 2. Stacked out T with lift gas. Bled IA. Shot second IA-FL @ same location. Final T/I/0=800/350/240. i /yam-~...,, ~, ~ ~ C~~r~~~~iitl~s ~1~~a, Irt~. 2L-307 KRU 2L-307 APL 501032028400 Well T e: PROD An to TS: de SSSV Type: NIPPLE Orig 4/3/1999 Angle @ TD: 56 deg @ 9727 Com letion: Annular Fluid: DSLlSW Last W/O: Rev Reason: TAG, GLV C/O, PULL JET PUMP, CLOSE SLV Reference Lo Ref Lo Date: Last U ate: 8/18/2007 Last Ta : 9407 RKB TD: 9727 ftKB Last Tag Date: 8/15/2007 - -- M ax Hole Angle: 68 deq @ 6291 Casing String-ALL Descri lion Size To Bottom TVD Wt Urade Thread Conductor 16.000 0 115 115 62.58 H-40 Welded Surface 7.625 0 2905 2307 29.70 L-80 BTC-MOD Production 5.500 0 8848 5267 15.50 L-80 BTC-MOD Production 3.500 RR4R 9709. 5755 9.30 L-80 EUE 8rd _ Tubing String -Tubing T p ~ r-,d~ EThread 3500 O __ i ' 9.30_. L _ 8848 52f iiE 8rd Perforations Summary Interval TVD Zone _ _ Status R SPF Date ~TypN ~ Comment 9210-9240 i 5474-5491 '.!1 1 ~ f; 1~i=~~~ IPEI-F 1:_OD__La I'll'~SE Gas Lift Mandrels/Valves -_ ~ __ St MD .TVD Man Mfr Man Type V Mir V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 4978 3504 CAMCO KBG29 CAMCO DMY 1.0 INT 0.000 0' 4/3/1999 2 R729 5199. CAMCO KRG29 CAMCO r)V 1 0 INT 0.313 0 R/16/2007 'Other tugs, equip., etc.) -COMPLETION SLEEVE-C -- De th TVD T e (ssso-ssa1, 510 509 NIP CAMCO DS NIPPLE oo-4szo) _ ~ - 8680 5173 SLEEVEroC BAKER CMU SLIDING SLE 8782 5229 NIP CAMCO D NIPPLE - 8791 5234 SEAL BAKER 80-40 SEAL ASSY Gas Lift ~.. ;._ F' Mandrel/Valve j 2 ~ r (8729-8730, 1 (( t lVIP (8782-8783, OD:4.540) SEAL (8791-8792, OD:5.500) Perf (9210-9240) Production (8848-9709, OD:3.500, Wt:9.30) rn . . ~ ConocoPhillips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 August 20, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 5GANNED SEP () 6 2nD? 5" \ C{'ß- ~ Dear Mr. Maunder: 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 còIïrltictor. These voids were filled with a 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 between August 12-13,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. 4~~¿ M.J. Eoveland 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 8/13/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft Qat 2L-305 198-240 SF N/A N/A N/A 1.7 8/13/2007 2L-307 198-256 10" N/A N/A N/A 8 8/13/2007 2L-311 203-155 15" N/A N/A N/A 9 8/13/2007 2L-313 198-219 15" N/A N/A N/A 5.9 8/12/2007 2L-315 198-218 23" N/A N/A N/A 5.9 8/12/2007 2L-317 200-210 SF N/A N/A N/A 4.2 8/12/2007 2L-323 198-251 9" N/A N/A N/A 3.4 8/12/2007 2l-325 198-209 24" N/A N/A N/A 9.3 8/12/2007 2L-327 207-008 20" N/A N/A. N/A 6.8 . 8/12/2007 2L-329 198-225 24" N/A N/A N/A 6.8 8/12/2007 . . WELL LOG TRANSMITTAL 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(Ca/iper / MTr) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ; ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 Report / EDE 2L - 307 Caliper Report 16-Aug.07 SGA.~NED AUG 2 7 2007 (D¡ "0 - ;)'5"fo tt 15"3'-( I Signed: c- vL-- ~,=., R;E' !~ ¡I.- ;1 < ; 'J tl !.~; V t_~ ~ ¡:'-," Date : Æ\, 1 ~0 ') 3 nUL.. -~ ?íìnl t....... ., Print Name: (1 ~A(\~!-\íAR pA Q.lu...~ .DA_ i& Gas Cor]5. Cünii niS5!U! {~nGhorag€ PROAcTIVE DIAGNOSTIC SERVICES, INc., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANcHORAGE, AI< 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE : VWVW.MEMORYLOG.COM D:\Master _COPY- 00 ]DSANC-2OxxIZ _ Word\Dìstnlmlion\TransmittIlC SheetJ¡\Transmit _ Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska Inc. August 16, 2007 9506 1 3.5" 9.3 lb. L-80 Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 2L-307 Kuparuk Alaska 50-103-20284-00 Surface 8,764 Ft. (MD) Inspection Type: COMMENTS: Co«osive & Mechanical Damage Inspection This caliper data is tied into the GLM 2 @ 8.729' (Drillers Depth). . This log was run to assess the condition of the tubing with respect to intemal corrosive and mechanical damage. The caliper recordings indicate that the interval of 3.5" tubing logged is in good condition, with a maximum recorded penetration of 23% @ 6,336'. The damage recorded appears mostly in the form of isolated pitting with some general corrosion. There are no areas of significant Cross Sectional Wall loss or I.D. restrictions recorded throughout the interval of tubing logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report MAXIMUM RECORDED WALL PENETRATIONS: Corrosion Corrosion ( 23%) ( 21%) 203 @ 221 @ 6,336 Ft. (MD) 6,902 Ft. (MD) Jt. Jt. No other significant wall penetrations (>20%) are recorded in the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (>7%) are recorded in the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded in the interval legged. I Field Engineer: S. Carpenter Analyst: J. Thompson Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. ì P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 , q 'ð"' - é) sr... r-t=- 153<f( Correlation of Recorded to Borehole Profile I Pipe 1 3.5 in - 8750.0') Well: 2l-307 ReId: Kuparuk I ConocoPhillips Alaska inc Country: USA Survey Date: August 16, 2007 I I Approx. Tool Devia1ion Approx. Borehole Profile -33 I 25 745 50 1521 I 75 2301 I 100 3085 I '- 125 3865 () ..0 .¡.J E w... ::; .f: Z .,.., 150 4642 c GlM 1 'õ I 175 5456 200 6239 I 225 7025 I 250 7811 275 8587 GLM 2 279 8750 I 0 50 100 Damage Profile wail) I Tool Deviation (degrees) Bottom of Survey = 279 I I I ody Region Analysis Well: Field: Company: Country: 2l-307 Kuparuk ConocoPhillips Alaska Ille USA Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom'!D 2.992 ins I Tubing: Nom.oD 3.5 ins Weight 93 f Grade & Thread l-80 Penetration am:! Metal loss (% wall) metal loss body penetration 20 to 40 10 over 40% 85% 85% o o Damage Configuration ( body ) 80 GlM 1 60 40 20 o isolated general line ring hole I poss pitting corrosion corrosion corrosion ¡hIe hole GlM2 o Bottom of Survey = 279 I Analysis Overview page 2 August 16, 2007 MFC 24 No. 40665 1.69 24 J. Thorn Nom. Upset 3.5 ins Damage Profile (% wall) metal loss 50 100 I I I I I PDS REPORT JOINT TABULATION SH Pipe: 3.5 in 9.3 ppf L-80 Well: 2L-307 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConoeoPhillips Alaska Ine NominaII.D.: 2.992 in Country: USA Survey Date: August 16, 2007 joint jt. Depth Pen. Pen. Pen. 1;\.I1,21-al Min. )"m"cp Profile No. (Ft.) (:;:~E;I Body I.D. Comments (% wall) (Ins.) (Ins.) 0 50 100 1 -33 1°11 ~$ 1.1 -2 0 1.2 5 I 2. 1.3 11 I 2.93 PUP ~ 1.4 17 I 4 2.90 OenoSÎIs. 1.5 21 ¿ 2.94 i PUP Shallow cnrmsion. 2 23 0.05 ') 2.93 Shallow eorroflion. I t. Deoosils. 3 55 0.03 11 2.94 Shallow corrosion. 4 87 ikI 2.93 5 118 _I .92 Shallow nittina. '" 6 149 ( !III 7 181 0.02 8 !III 8 211 0.02 q ') 2.93 9 '/42 0.032 2.92 Shallow oifflrn1. 10 273 0.02 1 2.9? 11 304 0.02 1 ?.c¡4 t\ 12 335 0.02 &. 2.97 13 367 0.03 3 2 m "'~Jo- nittin<'. 14 398 0.02 15 429 0.03 15.1 461 0 I 2. OS NIPPLE 16 462 I 0.02 2.93 17 494 0 0.02 2.92 18 525 0 0.02 2.92 19 557 ¡ , 2.91 20 588 1 ') 2.91 21 1')20 11 > 2.94 22 651 0.03 10 .2 2.92 23 683 0.02 *i:' 7.91 24 714 0.03 ') ') C¡1 25 745 0.03 "1'"' 26 777 0.02 8 I 2.93 27 808 I 0.02 7 2.93 28 839 0.03 I)QO Lt. Deoosí Is. 2C¡ 871 I 0.03 :i.94 30 902 ( 0.02 2.93 31 933 t=# 0.03 ').92 32 965 0.02 2.92 33 994 J 0.03 2.90 34 1024 0.03 2.92 35 1056 0.03 2.93 36 1087 0.02 2.93 37 1118 0.02 ').92 38 1150 0.02 2.93 3q H8D 0.03 2.91 40 1210 0.02 2.93 Lt. Oeoosils. 41 1242 0.02 2.94 42 1272 ( 0.03 2 2.92 Shallow nittÎf!Il. 43 1302 ( 0.02 ::I.(n 44 1334 I 0.02 2.93 I I I I I I I I I I Body Meta! Loss Body Page 1 I I NT LATION SH I I Wail: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: 2L-307 ConocoPhmips Alaska ¡nc USA August 16, 2007 I Joint Jt Depth Pen Pen. Pen. ¡\¡Iela! Min. Profile No. (Ft) ~;) I.D. Comments wall) (Ins) (Ins.) 0 50 100 45 1364 n ~ 46 5 n 02 J- 47 7 48 1458 '--- 2.94 4q 1490 '-- :m 1521 1 1552 ¡; 2Q3 52 1584 ) 4: 2.93 '13 1615 54 1647 ~ 16711 ¡ 2~ij4 1708 j 2.g3 57 ~ 2.94 iUimil. '>8 1770 7.93 o;q 1801 I ? 2.94 60 1833 :>.93 It De>no<cits. fìl 1864 í1? 111< 6 0.01 63 19' 6 0.02 2. 3 6A. 19 7 If 2.92 65 19 9 r- 2.93 66 2020 f ~~ 67 2051 f Shallow nitl1rw 68 2082 f r- '"'iQ1 69 2114 70 2145 2.'n Shallow corrosion. 71 2176 0.02 1.92 7'} 2207 0.03 2.92 i'1 2239 003 2.93 i4 2270 0.03 2 75 2301 0.03 2 76 2332 ( 0.02 I 77 f 0.03 StJilllow nittín2. 78 0.03 Shallow corrosion. 79 0.03 4 80 it - 81 -1 f - 82 520 ;¡- 2.92 Shallow corrosion. 81 - 551 0])3 2.93 Shallow nittir'!:!. 84 2583 =Et ~ 2.93 85 291 86 .' 2646 ~M Shallow corrosion. 87 2677 0.03 88 2709 t 2.93 89 2740 q 2.93 90 2770 ·0.03 2.93 91 0/ í t; 2.93 92 :1 0 2.92 ShallowoiUirnz. q3 5 () 1 -ffi: 94 '896 0 I 0.03 if I I I I I I I I I I I Page 2 PDS REPORT JOINT TABULATION Pipe: 3.5 in 9.3 ppf 1.-80 Wen: 21.-307 Body Wan: 0.254 in Field: KuparuK I Upset Wall: 0.254 in Company: ConocoPhillips Alaska Inc NominaII.D.: 2.992 in Country: USA Survey Date: August 16, 2007 Joint Jt. Depth Pet Pen. PerL Metal Min. ¡;¡m;¡op Profile No. (Ft.) IJpset Body !.D. Comments ,,,70 on po wall} (Ins.) (Ins.) (Ins.) 0 50 100 I 95 i 2q 8 003# ' 2.94 96 29 9 1 0.D2 2 2.93 97 I o 031 2.9~ 98 3022 ! 0.02. I 99 3053 I ! 0.03 13 2.92 Shallow "iuiml. 100 3085 ( 0.02 9 2.93 101 3116 I 102 3147 ? 2.94 103 3178 .03 10 ¡ 2 2.92 I 104 3210 292 Sh;¡lIow niWnq. 105 3241 2.94 106 3273 2.92 107 3304 ì 2.92 108 3315 ) 2.93 109 3365 ì I 0.03 2.91 Sh;;¡lIow oitlinq. 110 3396 1 I 0.04 ;~ 2.93 Shallow corrosion. 111 3427 ~ I ò ~ 2.93 I 112 3458 ?91 113 3490 2.92 B 114 1521 ~ Shanow "iuin2. 115 3552 116 3584 o 0.03 11 .ì 2.93 117 3615 0.03 0 5 2.93 118 3646 0.02 2.94 119 3678 0.03 1.92 120 3708 0.03 2..94 121 3740 0.03 2.93 122 3771 0.03 2.93 123 3802 0.03 2.92 124 3833 i 0.02 2.93 125 3865 0.02 2.93 126 3896 I 2.93 127 3927 2.93 128 3957 2.93 129 3988 () 2.93 130 M!1q j 2.91 131 4050 2.92 Shallow niltinq. 132 4080 2.93 133 4111 0.D2 I 2.94 134 4143 ~ 2.93 135 4174 2.92 136 4205 ( 2.93 137 4236 ( 0.03 2.93 138 4267 ( 0.02 q 2.91 139 4299 !,tJ 2.92 Shanow oittinq. 140 4330 2.92 141 4361 2.92 142 4393 :192 Sh;;¡lInw oittin2. 143 4424 .Q2 "",,lInw nittin<>. 144 4455 () 0.02 I 2.93 I Body Body Page 3 I JOINT TABULATION SH Pipe: Body Wall: Upset Wal!: Nominal I.D.: 3.5 in 9.3 0.254 in 0.254 in 2.992 in L-80 Well: Field: 2L-307 Kuparuk ConocoPhiliips Alaska Inc USA August 16, 2007 Country: Survey Date: I Joint Jt. Depth PerL I~en. Pen. i ¡\!Ielal Min. ""v p,~ofile No. I(¡:~:(;I !.D. Commenls \ /0 wau! (Ins.) % (Ins.) 0 50 100 ~ 002 9\ 2.93 11I292 1 4549 +Shallow niUiru;¡. 148 4580 2.93 149 4h12 2.91 150 4642 .0313 2.92 Shallow oiUim!. 151 = 0.03 H) 2.93 152 4705 - 153 0.02 154 4768 rl= 0.02 155 4799 156 4831 157 4862 0.02 9 '2 158 4894 0.03 i¡ '2 2 93 = 002 7 2.92 om 2.92 PUP 159.2 N/A GLM 1 {latch @ \ ~ 159.3 4977 4 2.92 PUP Shallow niWn2:. 160 4992 0.03 2.92 Shallow oiWrm. 161 5020 0.03 1 2.92 162 5051 2.91 163 50fl2 0 2.90 It DeDosils. 164 5113 2.91 165 5143 2.92 Shallow nittirm. 161> 5175 2.91 167 5206 '2 2.91 Sha!Jow oittir¡¡z. 168 5238 2 292 169 5269 0.03 ! 1 2.92 170 5300 0.02 2.93 171 'i131 (101 ! 2.91 Shallow !Jittin~. 172 5363 0.03 ¡ 2.91 173 0. 2.93 Shallow corrosion. 174 , 1< o. ~ 175 )( O. '2 176 ~: ) 177 5517 2.92 178 5548 \ 2.91 179 5580 I 2.91 Shallow nitJirul. 180 5611 I 2.90 Shallow oittiml. U. Deoosils. 181 5643 2.92 Lt Deoosils. 182 5674 0.04 2.90 ¡Wnl!. 183 5706 0.03 ì2 2.91 Lt Deoosils. 184 571ft 111 2.91 185 ">768 2.92 Lt Deposits. 186 5800 1.R 291 187 5831 1.11 2.90 LL Denasits. 188 5863 [U2 2.91 U. Denosi Is. 189 5894 0 [1.)2 ) ~ 190 5926 0 lfH 13 Shalla n. 191 5958 0 0.03 II') ¡ 2.92 Shallow piWmz. Lt. Deoosils. I I I I netration Body Metal Lass Body Page 4 I Pipe: Body Wall: Upset Wall: Nominall.D.: PDS 3.5 in 9.3 ppf L-OO 0.254 in 0.254 in 2.992 in JOINT Joint No. Jt. Depth Pen, Pen. PerL' I,,¡elal (Ft.) I(:;:~(~I I 1 q2 193 194 195 196 197 198 199 200 201 202 203 204 205 6396 206 6428 207 6459 208 6490 209 6522 210 6553 211 6584 212 6616 213 . 1'>(;47 214 6679 215 6711 216 6742 217 6774 21R I 6006 219 . 6836 220 6868 221 6899 222 6930 223 6962 224 6993 225 7025 226 7056 227 7088 228 7119 229 7151 230 7182 231 7214 232 7246 233 77 234 09 235 7' 40 236 71 237 7402 238 74,4 239 746" 240 7497 241 7528 5989 6021 6052 6083 -lli~ =MZ:6 6207 6239 6270 6302 6333 I I I I 2.90 2 ;2 2 ! 5 I 2.91 Seo" mNcorrosion. 111 Sla owDitlimz. " ... ~;H; ,~ It. =t4! 2. Shallow mUm\!. U. DeDOsits. 6 2 ¡Will!. q) 2.92 ¡¡ q D D ,) ,( , C 0.04 'L.... 0.04 0.04 0.04 0.04 0.04 0.05 O.O? o (ì I ¡ 0.04 Ij, I 6 i§ ~' ~ g:g3 11 0.0313 0.03 3 4 0.04 0.04 0.0, Ii 0.041 ¡ ;2 Min. 1.0. (Ins.) 2.91 2.93 2.91 2.91 2(Jj 2.91 93 12 11 . 1 2. 1 2.91 Ii LATION Well: Field: Company: Country: Survey Date: 2L-307 Kuparuk ConocoPhmips Alaska Inc USA August 16, 2007 Comments Shallow oittin\!. Shallow corrosion. It. Deoosits. <;h",l!nw ! t Deposits. Shallow corrosion. Lt. Deposits. Shallow nittinQ. Shallow nittim!. Isolated nÎUÎn2. Lt. Deoosits. Sh",l!nw nitÛrm. Shallow nittinQ. Lt DeDosits. Lt DeDosits. ittinR:. It. DenŒits. Shallow corrosion. Corrosion. U. Deoosits. 2.90 2.91 2.89 Shallow oÎttinR:. 2.91 2.90 sn",Uow niWrm. 2~'.nittin2. 2.90nittin\!. 2.91 2.92 2.92 2.91 2.92 2.91 2.90 2.93 2.93 2.91 2.91 2.Q1 2.93 Shallow oittinlI. Shallow oittim;¡:. Shallow oittinlI. Shallow DitlÏm;¡:. ¡ t. Denosi ¡". Shallow oiUim!. Shallow oiWIlI!. Shallow corrosion. Shallow oittim!. 5 J",m"'!lf> Profile wall) o 50 100 I I I I I PDS JOINT LATION SH Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Well: 2L-307 Field: ConocoPhillips Alaska Inc Country: USA Date: August 16, 2007 I I Joint Jt. Depth Pen Pen. Pen. ¡vieta! Min. ".I",,,, No. (Ft.) Body LD. Comments wall) (II .) (Ins.) (Ins.) 0 50 100 :ì4:ì 7559 ) Shallow oiUiM. 241 75<H ~ 0.03 1 n ¡ Shallow oittim:!. 245 0.03 110 247 7716 2.91 "hallow nit!:im;¡. I 248 7748 2.91 249 7779 2.90 750 7811 '-- iRi ts. 251 7842 0.03 1 252 7873 0.04 1· 2.92 Shallow oittin2:. 253 7902 0.03 I i 2.90 Shallow oittim:i:. 254 W "-- =fit 255 7962 r=I "-- Shallow corrosion. 256 7994 2.91 257 ~5 2.91 I 258 7 0 ~ 8±91 Shallow oittímI. :ì<;9 Ii 11 90 260 () 0.03 ¡ 89 5 lallow oittin2:. 261 8 51 I 2.89 'tting, 262 iÙ 83 1 i 2.89 Sh;tl!ow corrosion. 263 8214 I 2.91 264 R/45 ( ~.'11 I Shallow corrosion. F; 8277 O. 8108 I O. 8339 ~ ¡Him.!. 268 8370 269 8401 0.03 270 8432 0.04 ~ Shallow nittim;¡. 271 8462 0 0.03 272 8494 ( 0.03 273 8525 ( 0.04 1 "2 2.90 ittir1!:!. 274 8556 I {) ()') I 2.91 iWnt!:. 275 8587 0.03 2.90 Shallow oittin¡;¡. 276 861£1 003 )~ 2.92 Shallow nittinŒ 277 8647 ( 0.04 2.90 Shallow nittimI. 277.1 8679 ( 0 2.81 SLIDING SLFEVE 278 8683 ( 0.04 4 2.93 Shallow oittiol:!. 278.1 8714 I. 0.02 2.96 I PUP 278.2 8729 I. 0 ( N/A 2 (latch @ ) 278.3 8738 ( ~ If! 2 2.92 I PUP 279 8750 I. z; 2 2.94 ?J!! I I Body Meta! loss Body I 6 - -- Well: Field: Company: Countty: TubJn : 2L·307 Kuparuk ConocoPhmlps Alaska Inc USA 3.5 ins 9.3 f L·80 for Tool "" 50 10 "" 2.992 Nominal OD'" 3.500 Remaining waIJ area'" 95 % Tool deviation'" 99 Q - depth 6 .. ---- - - S Report ross Sections Survey Date: Too! Type: Tool Size: No. of Anal st: 126 ft Finger 14 Penetration 0.059 Ins Corrosion 0.06 ins'" 23"/" Wall Penetration HIGH SIDE"" UP Cross Sections page 1 - - Well: Field: Company: Country: Tubin : - - - - - - - PDS Report Cross Sections 2l·307 Kuparuk ConocoPhiUips A!aska tne USA 3.5 ins 9.3 f L·80 Survey Date: Tool Type: Too! Size: No. of Fingers: Ana! st: for Joint 221 at depth 6901. 7 ft Too! = 49 Nomina! to = 2.992 Nominal 00 = 3.500 Remaining waU area = 95 % Tool deviation = 760 Finger 15 Penetration = 0.054 ins Corrosion 0.05 ins 21 % Wall Penetration HIGH SIDE = UP Cross page 2 I I Production (0-8848, 00:5,500, V\i!:15.50) I SLEEVE.o (8680-8681, 00:4.620) I NIP (8782-8783, 00:4.540) I SEAL (8791-8792, 00:5.500) I f'<>rf (9210-9240) I Production (8848·9709, 00:3.500, V\i!:9.30) g Sc~luIIb8Pgep NO. 4034 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NOV :I. 3 ZOOS G~~ Goo¡:;. (~~JffimìssiQ!1 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I"") -;.L:,· !'",'\.-. ,~;\~\\ -'. ìCf15' -c7~ ~l,¿"'~-- Field: Kuparuk Well Job# Log Description Date BL Color CD 1 R-26 11416225 INJECTION PROFILE 10/23/06 1 1R-22A 11416224 PROD PROFILE W/DEFT 10/22/06 1 2K.28 N/A INJECTION PROFILE 10/19/06 1 3G-09 11415642 PROD PROFILE WIDEFT 10/24/06 1 3G~16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J·101 11445123 GLS 11/06/06 1 2P-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE WIDEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE W/DEFT 11/05/06 1 1 R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28/06 1 1 D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N~305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 21.:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2K.27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 11/10/06 . . Re: .let Pumped Wells Subject: Re: Jet Punlped 'vVeJIs From: "NSK Problem \VeJI Supv" <n 1617(@eonocophillips.eom> Date: Sat, 7 Dee 2002 14:07:01 -0900 To: Tom l\'¡aunder <tom_maunder@'admin.state.ak.us> CC: "n 1611" <n 1617@:}conocophillips.eom> Tom: I requested a list of surface powered jet pump wells from our PEls. The following should be the current total for the Kuparuk area: West Sak wells: 1C-123 (PTD 2010840) was recently S1 for high watercut 1C-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: ~ 2L-307 (PTD 1982560) , 2 L - 3 13 ( PT 0 1 9 S 2 190 ) 2L-315 \PTD 1982180) 2L-321 (PTD 1982620) 2L-325 \PTD 1982090) 2 N - 3 03 ( PT 0 2 0 0 16 9 0 ) 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. I hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <'ï:J.))ï¡ m'-;jIH1cJ,:;-r';'\-'i.drfli..n.:3tatr-;'.'-:1k.us> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and or Jerry, I have some emails fro h'l b maw 1 e ack regarding the wells out there on Jet pumps. Ivould ~loU please provide an updated listing of the wells presently on jet pumps in greater KRU?? Thanks in advance. Tom Casing Detail 7.625" Surface Casing Iqg-)5 Þ WELL: TARN 2L-307 DATE: 3/26/99 1 OF 1 PAGES ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool6 RT to LR = 34.601 TOPS Above RKB 7 5/8" Landing Joint 34.60 .5 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.80 34.65 Jts 47-69 75/8",29.7#, L-80 BTC-mod (23 jts) 966.96 37.45 TAM 7 5/8" Port Collar 2.48 1004.41 Jts. 3-46 7 5/8", 29.7#, L-80 BTC-mod (44 its) 1811.12 1006.89 Gemeco Float Collar 1.28 2818.01 jts 1-2 75/8",29.7#, L-80 BTC-mod (2 jts) 84.28 2819.29 Gemeco Float Shoe 1.48 2903;-57 Casing shoe @ t--2905.05\ l J T.D. @ 29151 leavina 9.951 of rathole " _// 30 Gemeco Bow Sprina CENTRALIZERS Run centralizers in center of Jts. 1. 2. 46. 47. over stop collars and over casing collars on Jts. 3-12 and over collars of jts. 15, 18, 21, 24, 27, 30, 33, 36, 39, 42, 50 , 53 , 56 , 59 , 62. 65. Joints 70- 76 (7 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: K Up,140K On, 110k Blocks. Ran 69 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Pool 6 Drilling Supervisor: Dave Burley / Rick Overstreet .4~ ~" ARCO AI k C D 1 as a, nc. ementlng eta I S Well Name: 2L.307 Report Date: 03126/99 Report Number: 6 Ria Name: Pool6 AFC No.: AK9749 Field: Tarn Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 7.518 9-7/8 2905 2818 Centralizers State type used. intervals covered and spacing Comments: 30 Gemeco Bow Centralizers. In centers of jts. 1,2,46,& 47. Over collars of jts. 3 - 12. Over collars on jts 15, 18, 21,24,27, 30, 33, 36, 39, 42, 50, 53, 56, 59, 62, & 65. Mud Weight: PV(prior cond): PV(after con d): YP(prior cond): YP(after cond): Comments: 10.2 42 28 40 22 Gels before: Gels after. Total Volume Circulated: 17/38 8/14 900 Wash 0 Type: Volume: Weight: Comments: ARCO 20 bbls. 8.4 Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 40 bbIS./,\ 10.5 Lead Cement 0 Type: Mix wtr temp: Nt of sais: Weight: Yield: Comments: A5 III Lite 60 387 10.7 4.43 Additives: ~ Standard blend. Tall Cement 0 Type: Mix wtr temp: t. of sa) Weight: Yield: Comments: G 60 235 15.8 1.17 Additives: ~--- 1% 51, 0.2% D46, 0.3% D65. Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comments: 7 7 135 Reciprocation length: Reciprocation speed: Str. WI. Down: 25 15 fpm 125 Theoretical Displacement: Actual Displacement: Str. WI. in mud: 129.4 bbls 129.7 bbls Calculated top of cement: \! CP ~?\ Bumped plug: Floats held: Returns to surface. Date:3-26-99 yes yes Time:2024 hrs. Remarks:Circ and cond mud 7 bpm 650 psi, pumped 20 bbls of pre:~1t.QbbIS of spacer, 305 bbls of lead and 50 bbls of tail cement. Displaced with 20 bbls of wash up water and 109.7 bbls of mud, bumped plugs to 2000 psi. H 100 bbls 0 10.7 ppg cement returns to surface, reciprocated pipe until I 280 bbls of lead away, had full returns throughout. - Cement Company: Rig Contractor: Approved By: Dowell POOL RICK OVERSTREET ~.... ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. I Date RptNo I Rig Accept. hrs Days Since AccepVEst: 3.4 / 3 Rig Relase - hrs: AK9749 03126/99 6 03123/9902:00:00 PM Well: 2L.307 Depth (MD/TVD) 2915/2312 Prev Depth MD: 2915 Progress: 0 Contractor. POOL Daily Cost $ 173287 Cum Cost $ 574218 Est Cost To Date $ 500000 Rio Name: Pool 6 Last Cso: 7-518" @ 2905' Next Cso: 5-1/2" x 3-1/2" @ 9739'. Shoe Test: Operation At 0600: NU BOPE. Upcoming Operations: NU and Test BOPE. PU drill pipe and clean out cement. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL SPUD 1 N TST 03119/99 03114/99 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 10.2pDO 9-7/8 03115199 03117/99 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 82sqc HYC N SPACE 03118/99 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 28 / 22 MX1 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 4050 8/14/ A48ZC APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED. 1250 6.6 2915 03126/99 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 83 ml/30 min 115 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 12% 2800 2L-313 PERSONNELDA T A HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of -27 134bbl III 14.75/6.3 / 2L-307 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 7 22.5 1 121 I 5.20 2.0 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 450 8.5 5.515.51 I 80 . 134 600 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -42.82 10% 701701 I .595 Water Base Muds 817 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 2 50 I 1 I 101151151151 I I 1 1 I I 273 Diesel 86 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 31 $2371 1 I 1 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $37656 I I I 2131CTIA I I I 1176 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 8 BAROID 10.21 I I EIIIWTITD I I 1 2686 PERSONNEL TOTAL 46 tiME )1 EN.ö HOÜRS T QRS..ØØÖE..................I.. 8bbË;SECi' ....;..ÂHÃ§EQP§ I øR.êÞl@¡itløNsIFaöN1..ööÖöI4öööÖ . 12:00 AM 01 :30 AM 1.50 CIRC SURF Making Hole Pump high vis sweep and clrc clean. Monitor well, stable, pump dry job. 01 :30 AM 03:30 AM 2.00 TRIP_OUT SURF Trip Out POH, no problems. 03:30 AM 06:00 AM 2.50 BHA SURF WiperTrlp Handle BHA, surface check mwd, lay down mwd and motor. 06:00 AM 08:30 AM 2.50 RUN_CSG SURF Casing and RU to run surface casing, held prejob safety meeting with Cementing GBR Casers and rig crew. 08:30 AM 01 :30 PM 5.00 RUN_CSG SURF Casing and Run 7-5/8" casing, lay down fill up tool, pu landing joint Cementing and mu cement head. 01 :30 PM 03:30 PM 2.00 CIRC SURF Casing and Clrc and cond mud for cementing. Cementing 03:30 PM 05:30 PM 2.00 OTHER SURF Casing and Clean flowline and possum bellies. Cementing 05:30 PM 06:30 PM 1.00 CIRC SURF Casing and Circ and cond mud, held safety meeting with Dowell and rig CementIng crew. 06:30 PM 08:30 PM 2.00 CMT_CSG SURF Casing and Test lines to 3500 psi. Cement casing with 305 bbls of lead Cementing and 50 bbls of tall slurry. Plugs bumped had 100 bbls of 10.7 ppg cement returns to surface CIP @ 2024 hrs. 08:30 PM 12:00 AM 3.50 OTHER SURF Casing and Flushed surface lines and equipment Cementing remove cement head and lay down landing joint / running tools. Daily Drilling Report: 2L-307 03/26/99 Page 8 24.00 Supervisor: DAVE BURLEY I RICK OVERSTREET Daily Drilling Report: 2L-307 03/26/99 Page 9 CASING TEST and FORMATION INTEGRITY TEST Well Name: 2L-307 Date: 3/28/1999 Supervisor: Rick Overstreet Casing Size and Description: 75/8",29.7 ppf, L-80, BTC Casing Setting Depth: 2,905' TMD 2,307' TVD Mud Weight: 9.3 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 2,324' TVD 830 psi + 9.3 ppg EMW LOT= (0.052 x 2,307') = 16.2 ppg Fluid Pumped = 0.6 bbl Pump output = 0.0840 bps - -.- --.--- ~TIME LINE J I I ! I 1- ~ ,ONE MINUTE TICKS ! I I. . J . --'- ! I ,. . ! ' . ,. . i I J"P, . ~.I I I I 'r ~ ~I"I~' ï' I ¡ I I i Ii I I i I I I 1 11 ! I I I ! I I J I ¡ I I I , ! I ¡ 'F I 1 ¡ Iii : i Jí I I I I : I 1'1 ~ I I' I I " 11 1 ' ; I J I I I J I i i I I I 'F 1 I I i I J I I ~LEAK-OFFTEST I I J, I I I I -'lP-CASING TEST I ! ¡ I A.: ","" I I -"'*,,.. LOT SHUT IN TIME ! I I I:L , ! I~ I -.k-CASING TEST SHUT IN TIME ' I~I I J I -+-- TIME LINE I If II I I I I , I 11 I I 1'1 V I I , I I 11' I I i I I I IV! I I I 81 I I I I I I I I I I 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi W 1,400 psi a: 1,300 psi ~ 1,200 psi f3 1,100psi a: 1,OOOpsi Q. 900psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 56 60 62 64 66 66 70 72 74 76 78 60 82 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ¡-----ì--------!---------¡ r-----¡----õ-Si-ks---r---õpsT----l r-------r--1--ši-kš----1----7õ-psT---l ,---------I---2štkš----¡--27õ-p-sT--1 ~-------------~--------------+--------------I ! i 3 stks ¡ 380 psi ¡ ,------r---4 stkš--T---47š--ps¡--1 t-------!S-stks -r-6"õõ-ps¡"! ~-------i--------+--------------I ¡ ! 6 stks ! 710 psi! :-=--=-l=~~?!!~~=-1=!!~J?~f=1 r ~ -f~=-~=f=~~ ¡-----------1--------------t-------------1 !:-~=---t===~t==~ Ë~:===Ë:=-~~~:t======~ r ~==~~~:==~=t====~ !---------1---------------r-----------------1 L~_'!I!T IN TI_~j___----_2..'iI!_!.!~-~~~~~~E L__<2: 0 min_j____--__.___L_~9.Q_p.~J._j i 1.0 min ! ! 830 psi i ~--------------i-----------+---------------I i-~Q..~!~--.J------------L--~~-«!.P_~)--J L__~:O min -j----------L~~t?J?~--J i 4.0 min ¡ ¡ 820 psi ¡ C=_~:.~~in -=l==~=~~~=~=~~~~t=Ji~~~I~~J i-~9 mi~.L--------l---~~_?..p_~L_j i 7.0 min i i 805 psi! ¡---Ra min -¡---------------¡--ãõš--psr-1 ~-------~---------------+------------I i 9.0 min ¡ ! 805 psi ¡ L__1.<?0 m!~-1~~=~=-~-=~=~=~r-=~Õš-p.~I~~J CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r------------1-----------------'---------------1 ~------------------~----------------I--------------------I ! ¡ 0 stks ¡ 0 psi ¡ ~--------------------t-------------------...---------------.. ¡ I 1 stks ¡ 0 psi ¡ ~----------------t"-------------1-----------,;--1 I I 2 stks I 100 pSI I }-------------i----------------t----------------- ! ¡ 4 stks I 225 psi ¡ r---------------T---Ëištï<š----r--3ÕÕ-p-š¡--1 r------------¡-----ã-Šti<š-----1400.pš¡-¡ }------------------""-------------i--------------- i ¡ 10 stks ¡ 700 psi ¡ ¡~~~~~~~j~iïm~~fJ ¡ ¡ 15 stks ¡ 1,280 psi! t-------------t------------i-------------;--1 L_-----------i--__1!!!~~____L_1!~!!!!_p.~~_J i I 17 stks ¡ 1,500 psi! ~---------------~----------_.__._---'-----------------I ¡ ¡ 18 stks ! 1,600 psi ¡ r-----------T----19-štkš---T-1~7õõpsr-l r-------------¡----2Õ-Štï<š---I-~ãõõrjsn }---------------i----------------+----------------- ¡ ¡ 21 stks ¡ 1,900 psi ¡ ~~~~~=~~~~~==~~=r~=~~~~!~~~~~~~~~~~~Q~R~[~ i i -----------------i------------------I ! SHUT IN TIME! ¡ ¡ Qfji~~J~~~~~~~f~~i~~~ i 3.0 min i ! 1,900 psi ¡ EI~EE===~=¡1f~~=~~E ¡ 6.0 min ¡ I 1,900 psi! r-----------------T------------------r----------------" ¡ 7.0 min ¡ I 1,875 psi i t3fill[]=:=:==J~~n1;B i 10.0 min ¡ ¡ 1,875 psi ¡ t--------:----t-------------------i--------------;--1 L__1~Q_!!!~~----i------------------~-_.!!!!Z~_P.~.!_J ~---_?g;Q_!!!!~----¡------------------~.__!!!!Z~.p.~l_.J ¡ 25.0 min ¡ ! 1,875 psi! L~~~Q~~~[~~~I==~~~~~~~=~~=~~[~1~~r~¡~~] NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ~~ ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. I ¡Date Rpt No I :Rig Accept. hrs Days Since AccepVEst: 5.4 / 4.9 Rig Relase . hrs: AK9749 03128/99 8 03123/99 02:00:00 PM Well: 2L-307 Depth (MDITVD) 3920/2877 Prev Depth MD: 2915 Progress: 1005 Contractor. POOL Dailv Cost $ 103875 Cum Cost $ 795262 Est Cost To Date $ 710000 Ria Name: Pool 6 Last Csa: 7.518" @ 2905' Next Csa: 5.1/2" x 3-1/2" @ 9739'. Shoe Test: 16.2 DDa Operation At 0600: Drilling from 4465'. Upcoming Operations: Continue drilling production hole, wiper trip @ 5600'. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 3920 2 N TST 03/1 9/99 03127/99 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.30oa 110 63/4 03/15199 03/17/99 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 48sqc 125 HTC N SPACE 03/18/99 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 16 / 21 105 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 3825 7/6/ 15 1901317 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED. 830 6.6 20 03128/99 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 105 mll30 min 2800 2915 INJECTION USED. BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 6.0% 1500 1005 2L-313 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP of -42 152bbl 24001 I 1 6/1 I 2L-307 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 9 12.5 1 121 I 3-7 2.0 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 45° 9.5 5.515.511 75 - 324 700 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR OF -68.70 4.7% 89111 0.518 Water Base Muds 470 PIT VOL GPM 2 JETS JETS Fresh Water ARCO PERSONNEL 2 425 314111 1311311311311 11111 300 Diesel 96 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 31 $7424 III 0 . PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $53683 III III III 866 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 6 BAROID III III III 4775 PERSONNEL TOTAL 44 TIME T END IîÖ.Ui3s .... 1 QR$.0.öDE J HÖ.LE.SEOT .}ÞHASEQRS I . oÞê8ÄitliD&šËlåorvÜÖÖööŒÖöÖö . 12:00 AM 04:30 AM 4.50 BHA PROD Making Hole MU BHA #2, Scribe and Initialize tools, load sources and shallow test tools. 04:30 AM 05:30 AM 1.00 TRIP_IN SURF Casing and RIH tagged cement @ 2776'. Cementing 05:30 AM 07:00 AM 1.50 CIRC SURF Casing and Circ and cond cement contaminated mud. Cementing 07:00 AM 08:30 AM 1.50 PRB_EFC SURF Casing and Attempted to test casing, troubleshoot sending units and Cementing pressure gauges. 08:30 AM 09:30 AM 1.00 TEST_CSG SURF CasIng and Pressure test casing to 2000 psi, 30 min, blow down lines. Cementing 09:30 AM 10:00 AM 0.50 RIGS SURF Casing and Repair pressure sending units. Cementing 10:00 AM 12:30 PM 2.50 CLN_OUT SURF Casing and Clean out cement and float equipment, drilled 20' of new Cementing hole to 2935'. 12:30 PM 01 :00 PM 0.50 CIRC SURF Casing and Change well over to 9.3 ppg LSND mud. Cementing 01 :00 PM 03:30 PM 2.50 TEST SURF Casing and Performed FIT to 16.2 ppg EMW. Encountered pump Cementing problems on Initial attempts. 03:30 PM 12:00 AM 8.50 DRIL PROD Making Hole Drill from 2935' to 3920' ART=6 hrs. AST=1 hr. No problems through Camp sand 3353' to 3380'. Daily Drilling Report: 2L-307 03/28/99 Page 12 24.00 Supervisor: DAVE BURLEY I RICK OVERSTREET Daily Drilling Report: 2L-307 03/28/99 Page 13 Casing Detail 5-1/2" X 3-1/2" Production Casing WELL: TARN DATE: 4/2199 1 OF 1 2L-307 ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool6 RT to LDS = 33.00' TOPS 51/2", LANDING JT. 38.01 OVERALL LENGTH 33.00 5-1/2" GEN V CASING HANGER 3.10 33.00 Jts. 1-207 5-1/2",15.5#, L-80, LTC-MOD (207 joints) 8781.55 36.10 PUP 5-1/2",15.5#, L-80, MOD 10.42 8817.65 Baker Csg Seal Receptacle (CSR), SIZE 80-40,5-1/2" x 411 20.40 8828.07 XO 5-1/2" EUE Box x 3-1/2" 9.3# L-80 8rd EUE .59 8848.4 7 PUP 3-1/2" 9.3# L-80 EUE 8 rnd-mod 10.60 8849.06 jts.24-27 3-1/2" 9.3# L-80 EUE 8 rnd-mod (4 joints) 124.59 8859.66 MARKER 3-1/2" 9.3# L-80 EUE 8 rnd-mod 4.10 8984.25 Jts.4-23 3-1/2" 9.3# L-80 EUE 8 rnd-mod (20 joints) 623.94 8988.35 Weatherford Gemoco Float Collar 1.19 9612.29 Jts.1-3 3-1/2" 9.3# L-80 EUE 8 rnd-mod (3 joints) 94.38 9613.48 Weatherford Gemoco Float Shoe 1.17 9707.86 9709.03 Plug Catcher in the top of joint 4. MD 9580.60 (27) 3-1/211 x 6-1/211 spiral blade centralizers on jts 1-27 (12) 5-1/211 x 6-3/411 Gemoco centralizers over collars on Jts. 1-12. (18) 5-1/211 x 6-1/211 centering guides on Jts 152, 155, 158,161,164,167,170,173,176,179,182, 185,188,191,194,197,200,203. I REMARKS: String Weights with Blocks:185k Up, 110K On, 70K Blocks. Ran 207 Joints 5-112" and 27 joints 0 3-1/211 casing. Drifted 5.5" (4.825") & 3.5" (2.867") casing with plastic rabbit. Used Artie grade API modified No Lead thread compound on all connections. Casing is non-coated. Pool 6 Drilling Supervisor: Dave Burley / Scott Reynolds .4~ ...." ARCO AI k C f D t 1 as a, nc. emen InQ e als Well Name: 2L-307 Report Date: 04103199 Report Number: 2 Rig Name: Pool6 AFC No.: AK9749 Field: TARN Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: % washout: 3-1/2" x 5-1/2" 6-314" nIa 9708 Centralizers State type used. intervals covered and spacing Comments: (27) "3-1/2 X 6-1/2" SpIral & Straight blade cent. on jts 1-27; (12) 5-1/2" x 6-314" Gemoco cent on jts 1-12 of 5-1/2" csg; (18) 5-1/2" 0 x 6-1/2" centering guides on jts 152,155.158,161,164.167.170.173,176,179,182.185,188, 191. 194, 197,200. & 203. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 9.6 20 16 22 14 Gels before: Gels after: Total Volume Circulated: 8/11 4/6 680 bbls Wash 0 Type: Volume: Weight: Comments: ARCO 20 bbls 8.5 ppg Spacer 0 Type: Volume: Weight: Comments: ARCO B45 40 bbls 12 ppg Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: G 70 deg F 253 15.8 1.2 Additives: 2 gps D600, 0.1 gps D135. 0.2 gps D-47, 3% D53, 0.75% D65, 0.08% D800. Tall Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: Additives: Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comments: 4bpm 2bpm 185k Reciprocation length: Reciprocation speed: Str. WI. Down: 30' 15'/mln 110k Theoretical Displacement: Actual Displacement: Str. WI. in mud: ", ', ',',' 217 bbls 217.5 Calculated top of cement: CP: Bumped plug: I Floats held: 8348' Date:04l03/99 yes yes Time:01 :50 Remarks:Staged Pumps to 4.5 BPM @ 700 psI. Conditioned Mud. Pump 10 bbls preflush, 40 bbls spacer, 54 bbls cmt. Displace with 20 bbls HIVls spacer & 197.5 bbls Seawater. Full returns during circulating and pumping cmt job. Reciprocated csg until last 30 bbls of displacement. Bump plugs to 2200 psI. Cement Company: Rig Contractor: I Approved By: DS POOL Scott Reynolds ...~ ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. [Date Rpt No I Rig Accept - hrs Days Since AccepVEst: 10.4/10.2 Rig Relase - hrs: AK9749 04102199 13 03123/9902:00:00 PM Well: 2L-307 Depth (MDITVD) 9727/5765 Prev Depth MD: 9727 Progress: 0 Contractor. POOL Dailv Cost $ 188518 Cum Cost $ 1394936 Est Cost To Date $ Ria Name: Pool 6 Last Csa: 7-518" @ 2905' Next CSQ: 5-112" x 3-112" @ 9739'. Shoe Test: 16.2000 Operation At 0600: NU BOPE Stack Upcoming Operations: LD DP, run 3-112" completion. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 2 N TST 04101/99 03127/99 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6DDa 63/4 03115199 04102199 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 42sqc HTC N SPACE 03130199 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 16/14 STR554 GELS A VG DRAG SERIAL NO SER IAL NO VOLUME FUEL USED 3698 4/6/ 1901317 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 976 6.8 9727 04102199 BBLS HTHP WL TRO BTM DEPTH IN DEPTH IN POTABLE WATER 88 ml/30 min 2915 INJECTION USED - BBLS SOLIDS TRO OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8.5% 6812 2L-313 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP of -9 216bbl 3200 II I 47.1/10.9 / 2L-307 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 8 12.5 1121 I 2 - 10 2 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 225° 8.5 5.515.511 90 . 324 750 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -25.93 7.4% 891 I I 0.518 Water Base Muds 752 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 3 0 3161 I 1 131131131131 1 1 1 1 I 1 103 Diesel 49 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 34 $3052 1 125140 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $91818 I 170011000 013wtls 1 1 I 904 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 9 BAROID I 19.619.6 x 11/161 no I td 1 1 I 9310 PERSONNEL TOTAL 51 mIMe.. ;I)...'.'\'...EN.D liIø0IRS il. . ØRSQQDE II 8îi5Uè"$SOT ;IFlfflASê'øês, Ii . . .' Oglil!tli%illidl(iJs'RaoM'ööööi@ÖöÖÕ.' 12:00 AM 01:00 AM 1.00 PREP PROD Other Clean floor to LD BHA. 01 :00 AM 02:30 AM 1.50 BHA PROD Other Retrieve sources & download tools. 02:30 AM 03:30 AM 1.00 BHA PROD Other LD BHA 03:30 AM 05:30 AM 2.00 PREP PROD Casing and Pull wear bushlng- RU to run 3.5x5.5 csg. Cementing 05:30 AM 07:30 AM 2.00 CASG PROD Casing and Run 27 jts 3-1/2" csg. Cementing 07:30 AM 09:00 AM 1.50 CASG PROD Casing and RU to run 5-1/2" csg. Cementing 09:00 AM 11:30 AM 2.50 CASG PROD Casing and Run 85 joints of 5.1/2" csg to 4510'. Cementing 11:30 AM 01 :00 PM 1.50 CIRC PROD Casing and Break circulation @ 4 bpm & 700 psI. Cementing 01 :00 PM 03:30 PM 2.50 CASG PROD Casing and Run 61 jts 5-112" csg. Cementing 03:30 PM 05:00 PM 1.50 CIRC PROD Casing and Break clrc @ 3 bpm & 400 psi. Cementing 05:00 PM 07:30 PM 2.50 CASG PROD Casing and Run 5-1/2" csg to TD. Total of 207 jts. Cementing Daily Drilling Report: 2L-307 04/02/99 Page 18 07:30 PM 08:00 PM 0.50 PREP 08:00 PM 11:30 PM 3.50 CIRC 11:30 PM 12:00 AM 0.50 CMT_CSG 24.00 PROD PROD PROD Casing and Cementing Casing and Cementing Casing and Cementing RD franks fill up tool & RU cmt head. CBU & condition mud to 9.6 ppg In/out @ 42 vis. PJSM. Break circulation w/Dowell- test lines to 3500 psl- pump 20 bbl ARCO preflush. Daily Drilling Report: 2L-307 04/02/99 I Supervisor: DAVE BURLEY I SCOTT REYNOLDS Page 19 .4~ ~~ ARCO Alaska, Inc. Daily Drilling Report AFC No. I~ate RptNo I :ig Accept. hrs Days Since AccepVEst: 11.4 / 11.2 Rig Relase . hrs: AK9749 04103199 14 03123/99 02:00:00 PM Well: 2L-307 Depth (MD/TVD) 9727/5765 Prev Depth MD: 9727 Progress: 0 Contractor: POOL Daily Cost $ 180926 Cum Cost $ 1575862 Est Cost To Date $ 1700000 Ria Name: Pool 6 Last Csa: 7-518" @ 2905' Next Csa: 5-112" x 3-112" @ 9739'. Shoe Test: 16.2 ppg Operation At 0600: ND BOPE. Upcoming Operations: NU & test tree, Release Rig. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOPIDRILL N TST 04101/99 03127/99 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL PPQ 03/15199 04102199 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL sqc N SPACE 03/30199 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER / GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 3375 / / APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED. 715 04103/99 BBLS HTHP WL TRO BTM DEPTH IN DEPTH IN POTABLE WATER 115 ml/30 min INJECTION USED - BBLS SOLIDS TRO OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & % 2L-313 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of -20 Obbl III / / 2L-307 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 7 III 2 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 1350 III 750 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR OF -34.89 % I I I Water Base Muds 1250 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 3 0 I I I I I I I I I I I I I 273 Diesel 42 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 34 $525 I I I 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $92343 I I I I I I I I I 1565 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 8 BAROID I I I I I I I I I 10875 PERSONNEL TOTAL 50 :mNIE il«i.END HOORS 1 øBS',Qdps il HOGS/SECT .':::I:RHÆS@.ØR$ :I. ØRËSAItêNSJFlffiøM'öööö+.ÖõöÖ . 12:00 AM 02:00 AM 2.00 CMLCSG PROD Casing and PJSM. Pump 20 bbl preflush, 40 bbls 12 ppg spacer, 54 Cementing bbls 15.8 ppg class G cement, 20 bbl hivis spacer, 190 bbls seawater. plugs bumped/floats held. CIP @ 1 :55. 02:00 AM 03:30 AM 1.50 CMT_CSG PROD Casing and RD Dowell & GBR. Flush out stack. Cementing 03:30 AM 05:00 AM 1.50 PRB_BOPE PROD Other Attempt to fish forlegn object out of BOP stack. Unable to fish. 05:00 AM 06:30 AM 1.50 PRB_BOPE PROD Other ND BOP stack and retrieve junk. Junk was 4"x4" piece of 7-5/8" rubber cementing plug. 06:30 AM 07:30 AM 1.00 PRB_BOPE PROD Other NU BOP stack. 07:30 AM 09:00 AM 1.50 TEST PROD Other Install packoff. Test flange and packoff to 5000 psi for 10 min. 09:00 AM 12:00 PM 3.00 OTHER PROD Other LD DC's & 9 Its of DP. 12:00 PM 01 :00 PM 1.00 OTHER PROD Other Continue to LD 4" DP. Pull test plug. 01 :00 PM 10:00 PM 9.00 RUN_COMP COMP Completion RU & run 3-112" tubing. 10:00 PM 12:00 AM 2.00 CIRC COMP Completion Establish circulation @ 15 spm & 200 psi. Pressure Increase to 500psl when first set seals stabbed into CSR. Bleed off pressure and tag up on CSA locator. RU to test csg t/3500 psi. 24.00 Daily Drilling Report: 2L-307 04/03/99 Page 20 CASING TEST and FORMATION INTEGRITY TEST Well Name: 2L-307 Date: 3/31/1999 Supervisor: Scott ReynoldslDave Burley Casing Size and Description: 75/8",29.7 ppf, L-80, BTC Casing Setting Depth: 2,905' TMD 2,307' TVD Mud Weight: 9.4 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 4,936' TVD 810 psi + 9.4 ppg EMW LOT= (0.052 x 2,307') = 16.2 ppg Fluid Pumped = 5.8 bbl Pump output = 0.0846 bps w ~ 600 psi t.n t.n ~ 500 psi a. 1,100 psi I ! ! rill I I I T I I I I I I! II [TIME LINE I, I I i I I I I I I ONE MINUTE 'I Ì'~ I ¡ I ,J- I I I '} I 'I I I I I I I '. I I ¡ " I' " I ~. I I Y ,\ I II//"I I I II I II I I I I III I j,J/ II I 111 J/I I I II ....... LEAK-OFF TEST I I í i I ~CASING TEST I i !~ Iii I! I! I -4;-- LOT SHUT IN TIME I ~ ' I I I I¡ -J,-CASING TEST SHUT IN TIME IllY I I I -+-TIME LINE I I 'II I I I . I kfl I I II~ . > ~ ' ^ I! 1,000 psi 900 psi 800 psi 700 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 26 30 32 34 36 38 40 42 44 46 46 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE I-------------r-------------r------l !------------!-------------~-----------J L------------j__~_stk!..__-.---Q.e~---j L_______.l_--~.!!~--¡___o..eSi ---j ~-----------+---~-~~~----- ---1~t~~i--1 1-----------+------------- ----_I!_----~ L______----_.l_---~_!!~--- --~~~'p~!_j ~----------------!-----~ stk~__- -- 30Q_~!_J [~~=~~=~~~~~=j~=-!~~rÊ~=f.c;-~~~;~_J L______-----!.-~~~~!..- - 1 ,OQ.QJ?-~.Li L-----------___.L__l 3 st~!_-- ~-Q.Q_J?:!!...~ L--------------+--_.J_~.!!~!-_- -_!t~Q.Q.J?_~!_-t L_-----______L.J_~..!'tk!_+___1-,!~.Q.J?!Ï.._~ L------------+--~~..!!~!..-~-_!t~Q.O psi -~ L------------.:.-..E stk!---k11.50Q.J?!Ï.....i L______--.L 18 S!~~___L_!t~Q.Q.'p-si 1 ~----------t-1~~~: -+- ~ :~~~~~--f "--------------T-----------r---------~---~ L----------.l-_~~_~.!ks ---L-!t~.Q-Q.J?_~!.J ¡ I 22 stks i 2,000 psi i I SHUT IN TIME ---------ŠttÜT IÑ PREŠSURE [=~9~Õ _~l~~t~~======r- 2~~ pšl_J ~--_!£.~-~---i"----------~-~-,.Q.Q.QJ?:!H ~-- 2.0 '!Iln --L--------------~-~.!.~.C?_P~-'-~ L--~:.g_Œ.1~--j-----------___~_..1.92~~-t L__i:.g__Œ.1~_.l_-------------~-j-,-~Q.QJ?:!!.J ~----~:.9- mi ~--t----------___~__1-,_~.Q.Q.p.:!!.J L__~:.9.._mi n ----~-------------+-_!t~_00 J?!Ï...! L_.?:.9_~l~_l.___-----------r-+-~-Q.Q_J?_~_J ~--_i3.:.Q.-~-~--¡-------------~__1-,_~75 J?_~!.-J ~---~g-_Œ.11_~---.L---------------__~___1-,_~_?§_J?_~!.-! L--!9. 0 _Œ.1J_~--1.--------------L_1-,_~.?.~J?_!Ï.....i L_~i:.9.._Œ.1l~_j___---------__~___1-,-~?~J?:!!.-t L--gQ.:.g__Œ.l.!n_-J-__--------~_1-,_~75 ps!...! L--g~:.Q._Œ.1Jn_.l-___--____+~1 ,875 P..~!.J L_1g.:.Q.!12!_~_L______-___L__11.~.75 J?.~!'j 1 ,875 psi NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE [==--==l--====I=~~==~-===I L----------L-_Q_~.!ks -L-~Æ..--j L_...J 5 stks L_100 psi_...j i i 10 stks i 300 psi I 1------+-----.-------1 L----- i 12 stks .l-~~«!.e~---l L_--------.J_!.4..~ks _.J__4..~QÆ~Lj i i 16 stks i 500 psi i ~----_._--+----I--------------I i---------J--!!..!~L 600 p~!_--.! L_____-.J-~ stk!..--L-_650_e~!__j ~---__--i-_.?2 !!!<.!.._~__~Q..e~_-t i i 24 stks ¡ 750 psi i r--------"1-"25- stksr-- 790 pSi-I '-----------'-26 stksT-Š10 pSl---l ¡--!~- stks t---810 pSl----! 1--- I .----~ L------J~!_st~!..-L-!!Q.p.!L..i L-__-1~0 stks _L__~10 e~_J ¡ ! 44 stks i 810 psi i I--------+------.-----------i L-------l-~ stks --1- 80«!.e~L-l ¡¡52 stks i 800 psi i r-----!---56 stk-Š-l-ãõõl)si-l I------i"--------I----------i L-----L!~ stks_-L-800 p-~-.! i ! 64 stks ! 800 psi! F==-------¡ 68 stks -F80Õ-~~_~ ~~!.!~ TI~_____~.!!~T IN r:~~~RE L9.:.9_min .i._-----_____--L_~OO e..~L_j i 1.0 min ! ! 750 psi i I----------+------------I-------------i L-?'O .Œ.1J_~-J-----L~Q.e..~--1 L_3.0_~in --j--------__L!°q_e~--l ~~Q._Œ.1JD__¡___---------~--_!OO_p.~-J L-§':'9_r1].i.Œ.-l-------___¡_~90 _P.~!---l L-~:Q.Œ.1JÐ--l--------j--~~!p"~ i 7.0 min ! ! 690 psi! '---ã1>-rñTñ--¡------¡ 69õ"j)s¡-1 1----------+--------1--------1 L-~.:9~iD-i.-____-----L..!.90 e~_L--1 L 10.0 min -1_----_L~~~.esi_j .. ~~ ~~ ARCO Alaska, Inc. Daily Drilling Report AFC No. I~ate Rpt No I :jg Accept - hrs Days Since Accept/Est: 8.4 / 8.2 Rig Relase - hrs: AK9749 03131/99 11 03123/9902:00:00 PM Well: 2L.307 Depth (MDITVD) 9727/5765 Prev Depth MD: 8146 Progress: 1581 Contractor. POOL Daily Cost $ 109468 Cum Cost $ 1116935 Est Cost To Date $ 1100000 Rio Name: Pool 6 Last Cso: 7-518" @ 2905' Next Cso: 5-112" x 3-112" @ 9739'. Shoe Test: 16.2 PPQ Operation At 0600: Slip and cut drilling line, no problems on wiper trip to shoe. Upcoming Operations: RIH to 9727' TD, cond mud, POH lay down drill pipe and BHA. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 9727 2 N TST 03119/99 03127199 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6ppg 135k 63/4 03115/99 03117/99 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 48sqc 175k HTC N SPACE 03130199 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 21 /22 120k STR554 GELS A VG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 4912 7/9/ 15k 1901317 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1639 4.8 40k 03131/99 BBLS HTHP WL TRQ BTM DEPTH IN OEPTHIN POTABLE WATER 89 ml/30 min 9000 2915 INJECTION USED - SBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8% 7500 6812 2L-313 PERSONNEL DATA HOLE VOLUME PUMP PRES AOT/AST ADT/AST SOURCE WELL TEMP OF -33 386bbl 3200 I I I 47.1/10.9 / 2L-307 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 6 15 1121 1 2 -10 2.0 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 135° 9 5.515.511 90 - 324 650 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -44.77 6.3% 891 I I 0.518 Water Base Muds 1150 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 2 500 3161 I I 131131131131 1 I I 1 I 1 303 Diesel 124 OAIL Y MUD SPS 1 BIT COST BIT COST CONTRACTOR 30 $14175 I 125140 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $87123 1 1700 11000 I 1 1 1 I I 1577 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 6 BAROID I 19.619.6 I 1 I 1 1 I 8394 PERSONNEL TOTAL 43 itìMe ....I.........ii.....elNi5 HôÜIâ$ it SRŠ.ØÖÖS V. H!ÔWËŠEØT . TRHh\SêitiR.$ . /1 . .ØPiSs@Wi(1¡t;;!ê.Fiffiørvï..øoõÖ'Aoöoõ 12:00 AM 01 :30 AM 1.50 WIPERTRP PROD WlperTrlp PJSM. POOH f/8146' t/5515', no problems. 01 :30 AM 02:30 AM 1.00 TEST PROD Other Perform LOT. EMW=12.6 ppg wI 9.4 ppg mud, TVD 4936'. 02:30 AM 04:00 AM 1.50 WIPERTRP PROD WiperTrlp RIH t/8146'. Hole took proper fill. 04:00 AM 12:00 PM 8.00 DRIL PROD Making Hole Drill f/8146' t/8656'. ART=2.25 hrs; AST=3.5 hrs. 12:00 PM 11:00 PM 11.00 DRIL PROD Making Hole PJSM. Drill f/8656' t/9727' TD. ART=8.0 hrs; AST=.45 hrs. 11:00 PM 12:00 AM 1.00 CIRC PROD Other Circulate Lo/HI vis sweep around. Prepare for short trip to shoe. 24.00 SupeNisor: DAVE BURLEY I SCOTT REYNOLDS Daily Drilling Report: 2L.307 03/31/99 Page 16 ~ if) rp òo Q- -- K 1 d' h h'd 12002 k d Al' A 1 D' uparu an plne nnu ar lsposa urzng t e t l~ quarter 0 h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-32 12701 100 0 12801 379 18636 31816 June 2002 July 2002 CD2-19, CD2- 23, CD2-41 CD2-50 31530 100 0 31630 370 0 32000 July 2002 Sept 2002 CD2-41, CD2-19, CD2-16, CD2-38 lC-18 27969 100 0 28069 379 4276 32724 June 2002 July 2002 1 C-1 04 CD2-39 1966 100 0 2066 379 27500 29945 Oct. 2001 Sept 2002 CD2-15, CD2-47, CD2-44 CD2-15 10459 100 0 10559 371 20722 31652 March Sept 2002 CD2-50, CD2-25, CD2-44 2002 CD2-26 13802 100 0 13902 380 0 14282 Sept 2002 Sept 2002 CD2-38, CD2-44, CD2-29 C k 1 1 ALD' 1 d' h h'd 12002 00 n et nnu ar lsposa urzng t e t l~ (" uarter 0 h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 52255 100 0 52355 0 14869 67224 January Sept 2002 Hansen #1 2002 ~ lVtl A l"fi h' hD' lA h 0 E . dd' h hOd 2002 ota 0 urnes lnto nnu 1 or W lC lsposa ut orzzatlon xplre urznl? t e t l~ quarter Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-24 33524 100 0 375 33999 Open, Freeze Protected July 2001 Oct 2001 CD2-33, CD2-39, CD2- 14, CD2-I5 lC-26 34160 100 0 0 34260 Open, Freeze Protected August September IC-123, IC-119, lC-102 2001 2001 2N -332 31453 100 0 325 31878 Open, Freeze Protected August 2001 Sept 2001 2N-348, 2N-350 1 C-16 32017 100 0 0 32117 Open, Freeze Protected Sept 2001 Oct 2001 1 C-l 02, 1 C-131, 1 C-125 R ECEIVED OCT 2 4 2002 SC¡-Ü~N[ED NOV n 5 200~? Alaska Oil& Gas Gons. Commission Anchorage 198-256-0 KUPARUK RIV U TARN 2L-307 50- 103-20284-00 PHILLIPS ALASKAINC Roll #1: Start: Stop Roll #2:. Start Stop MD 09727 TVD 05765 Completion~~. 573/99 Completed Status: 1-OIL Current: T Name D 933 2 SPERRY MPT/GR/EWR4/CNP/SLD OH L DGR/EWR4-MD y'~'qAL 2915-9727 OH 2/6 L DGR/EWR4-TVD /~lq'~' 2312-5765 OH 2/6 L DGR/SLD/CNP-MD ,...~,~L 2915-9727 OH 2/6 Interval Sent Received T/C/D · 9/9/99 9/14/99 9/16/99 9/21/99 9/16/99 9/21/99 9/16/99 9/21/99 L DGR/SLD/CNP-TVD ~AL 2312-5765 L FBHP/TEM SRVY /~I~L 100-9318.5 9/19/99 R SRVY RPT ~[~RY 0-9727. OH 2/6 9/16/99 9/21/99 CH 5 10/6/99 10/13/99 OH 4/12/99 4/13/99 Tuesday, May 01,2001 Page. 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, d,~/z:~ Commissioner Blair Wondzell, ~ P. I. Supervisor -~t'o~ FROM' John Crisp,q f~,/u,. C,, SUBJECT: Petroleum Irfspector DATE: July 20, 2000 Safety Valve Tests Kuparuk River Unit Tarn Field 2N & 2L Pads July 20, 2000: I traveled to Phillips Alaska's Kuparuk River Unit Tarn Field to witness the semi-annual Safety Valve System tests on Pads 2N & 2L. Testing went well with only one failure on 2L Pad witnessed. No failures were witnessed on 2N Pad. The AOGCC test report is attached for reference. SUMMARY: I witnessed the semi-annual SVS tests on KRU's Tarn Pads 2N & 2L. 2N Pad, 9 wells, 18 components tested. No failures. 2L Pad, 6 wells, 12 components tested. 1 failure. 8% failure rate. Attachments: SVS Tarn KRU 2N & 2L 7-20-00jc cc; NON-CONFIDENTIAL SVS Tam KRU 2N & 2L 7-20-00jc.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Ernie Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kupamk River, 2N Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2N-307 1990170 2N-308 1990100 94 70 65 P P OIL 2N-309 1990210 2N-313 1980910 ' '94 70! 70 P P OIL 2N-315 1981900 2N-317 1981430 94 70 70 P P OIL 2N-319 1981970 2N-320 1990010 94 70 65 P P OIL 2N-321A 1981730: I 2N-323 1980710! 94 70 70 P e OIL 2N-325 1981630 2N-329 1980670 94 70 70 e e OIL 2N-331 1981170 2N-335 1982040 94 70 70 P P OIL 2N-337A 1981220 2N-339 1981000 2N-341 1981030 94 70 65 P P OIL 2N-343 1980920, 2N-345 1981130 2N-347 2000630 94 70 60 P P OIL Wells: 9 Components: 18 Failures: 0 Failure Rate: 0.0% [-190 Day Remarks: 7/27/00 Page 1 of 1 SVS Tarn KRU 2N 7-20-00jc.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Emie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kuparuk River, 2L Separator psi: LPS ' 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2L-305 1982400 94 70 60 P 4 OIL '2L~'3'07 ' 1982560 94 70 70 P P OIL 2L-313 1982190 94 70 65 P P OIL 2L-315 1982180 94 70 70 P P OIL 2L-321 1982620 2L-323 1982510 2L-325 1982090~ 94 70 651 P P OIL 2L-329A 1982250 800 700 700 P' P GAS Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% [~ 90 Day Remarks: 7/27/00 Page 1 of 1 SVS Tam KRU 2L 7-20-00jc.xls 10/6/99 Scblumberger NO. 12843 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 2L-307 FBHP/TEMP SURVEY 990919 1 1 2N-321A ~ ~ RSTWATER FLOW LOG 990925 I 1 2N-325 t~A,I r.._ RST WATER FLOW LOG 990924 I 1 2N-343 ~..I ~ EST WATER FLOW LOG 990923 I 1 3G-26 .~L{ ~ 99346 AIT/GPIT 990816 1 3G-26 99346 AIT/GR/CCL 990816 I 1 3G-26 99346 CONTINUOUS SURVEY W/GPIT 990816 I 1 REC. EiVE Naska Oil & Gas Cons. Commisei0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. T~lj~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. C,~S Anchorage, Alaska 99501 September 16, 1999 RE: MWD Formation Evaluation Logs 2L-307, AK-MM-90100 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2L-307: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20284-00 1 Blueline 1 Folded Sepia 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20284-00 1 Blueline 1 Folded Sepia 2" x 5" MD Neutron & Density Logs: 50-103-20284-00 1 Blueline 1 Folded Sepia 2" x 5" TVD Neutron & Density Logs: 50-103-20284-00 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 September 9, 1999 MWD Formation Evaluation Logs ,L-o 07, AK-MM-90100 1 LDWG formatted Disc with verification listing. API#: 50-103-20284-00 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATYENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. ' .... Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 28, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2L-307 (Permit No. 98-256) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2L-307. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Drilling Team Leader AAI Drilling PM/skad ~- J STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [] Gas [] Suspended [] Abandoned [] Service [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 98-256 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20284 4. Location of well at surface 9. Unit or Lease Name 156' FNL, 602' FEL, Sec. 22, T10N, R7E, UM ':-"~ii'~'¥i'Fii~-~}i!i~iil~'- - .I ~ Kuparuk River Unit At Top Producing Interval~ ~,,~'! i,/:,'j7~;i~ ~llllIill41IIlIIll lO. Well Number 2631' FSL, 71' FWL, Sec. 24, T10N, RTE, UM .--%~.~/~ .. 2L-307 At Total Depth ; W~:.i~ii:~;::~ i . 11. Field and Pool 2228' FSL, 518' FWL, Sec. 24, T10N, R7E, UM 4 ,.- ~'-~-..' - - , Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. ~ 28 RKB feetI ADL 380051, ALK 4599 Tarn Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. J 15. Water Depth, if offshore 16. No. of Completions March 24, 1999 March 31, 1999 April 3, 1999 I N/A feetMSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9727' MD / 5765' TVD 9581' MD / 5684' TVD YES [] NO []'1 510' DS nipple feet MD 1231' (approx) 22. Type Electric or Other Logs Run GR/Res, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SE1-FING DEPTH MD J CASING SIZE WT. PER FT. GRADE TOP BOll-OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 115' 24" 9 cu yds High Early 7.625" 29.7# L-80 Surface 2905' 9.875" 387 sx AS IIIL & 235 sx Class G 5.5" x 15.5# L-80 Surface 8848' 6.75" 253 sx Class G 3.5" 9.3# L-80 8848' 9709' 6.75" (included above) _~4. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 8845' 8828' (CS R) 9210'-9240' MD 5474'-5491' TVD @ 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9210'-9240' 6.3 ppa on perfs, 97331# behind pipe 27. PRODUCTION TEST r~r~ I ~ ! ~ I A I Date First Production Method of Operation (Flowing, gas lift, etc.)~j ~ I ~ I I '~/~ L May 12, 1999 Flowin§ Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE :'t,I¢-:~IE~,~D~S 5/15/1999 29.0 Test Period > 2471 1828 55 100 / Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 325 psi 0 24-Hour Rate > 1745 1843 45 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved (Permit #98-256) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29 .... . 30. GEOLOGIC MARKERS Top of T-3 Top of T-2 NAME MEAS. DEPTH 8997' 9300' TRUE VERT. DEPTH 5353' 5525' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations and Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Paul Mazz~olinit~ 0 Title Drillinq Team Leader Date INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Fo rm 10-407 Date: 4/21/99 ARCO ALASKA INC. WELL SIIMMARY REPORT Page: 1 WELL:2L-307 WELL_ID: AK9749 TYPE: AFC: AK9749 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:03/24/99 START COMP: RIG:POOL 6 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20284-00 03/21/99 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 115' 115) PREP RIG TO MOVE FROM 2N TO 2L SUPV:FRED HERBERT / SCOTT REYNOLDS Prep rig for move to 2L pad. UPCOMING OPERATIONS:CONTINUE RIG MOVE TO 2L-307 03/22/99 D2) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 115' 0) RIGGING UP ON 2L-307 SUPV:FRED HERBERT / SCOTT REYNOLDS Move rig from 2N pad to 2L pad. UPCOMING OPERATIONS:RIG UP, NU DIVERTER, SPUD WELL. 03/23/99 (D3) MW: 10.0 VISC: 130 PV/YP: 50/49 APIWL: 9.6 TD: 115'( 0) PU BHA #1. SUPV:DAVE BURLEY / RICK OVERSTREET Move rig from 2N-309 and rig up on 2L-307. Accepted rig 1400 hrs. 3/23/99. NU diverter system and test. UPCOMING OPERATIONS:SPUD WELL AND DRILL TO CASING POINT. 03/24/99 (D4) MW: 10.0 VISC: 122 PV/YP: 32/34 APIWL: 6.2 TD: 690'(575) DRILLING 9-7/8" HOLE FROM 1370' SUPV:DAVE BURLEY / RICK OVERSTREET Held pre-spud meeting. Drill from 115' to 367' Change screens on scalper shakers. Drill from 367' to 551' Clean out plugged flowline and possum belly. Drill from 551' to 690' UPCOMING OPERATIONS:WIPER TRIP, DRILL TO CASING POINT ~ 2915' 03/25/99 (D5) MW: 10.2 VISC: 96 PV/YP: 42/40 APIWL: 5.2 TD: 2915' (2225) RU TO RUN SURFACE CASING. SUPV:DAVE BURLEY / RICK OVERSTREET Drill from 690' to 2030'. Maximum gas 1000 units @ 1450' Pumped high vis sweep and circ clean, monitor well, stable. Pumped dry job. Wiped hole to 374', no problems. Drill from 2030' to 2915'. Pumped high vis sweep and circ hole clean. Monitor well, stable, pump dry job. Wiped hole to 1846', no problems. UPCOMING OPERATIONS:RUN AND CEMENT 7-5/8" CASING, ND & NU. Date: 4/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 03/26/99 (D6) MW: 10.2 VISC: 82 PV/YP: 28/22 APIWL: 6.6 TD: 2915' ( 0) NU BOPE. SUPV:DAVE BURLEY / RICK OVERSTREET RU to run surface 'casing. PJSM. Run 7-5/8" casing. Cement casing. UPCOMING OPERATIONS:NU AND TEST BOPE. PU DRILL PIPE AND CLEAN OUT CEMENT. 03/27/99 (D7) MW: 9.3 VISC: 45 PV/YP: 14/18 APIWL: 6.4 TD: 2915'( 0) CIRC AND CONDITION CEMENT CONTAMINATED MUD. SUPV:DAVE BURLEY / RICK OVERSTREET ND diverter system. Install test plug and test BOPE to 250/3500 psi. UPCOMING OPERATIONS:TEST CASING, CLEAN OUT CEMENT, LOT, DRILL AHEAD. 03/28/99 (D8) MW: 9.3 VISC: 48 PV/YP: 16/21 APIWL: 6.6 TD: 3920'(1005) DRILLING FROM 4465' SUPV:DAVE BURLEY / RICK OVERSTREET RIH tagged cement @ 2776'. Circ and cond cement contaminated mud. Attempted to test casing, troubleshoot sending units and pressure gauges. Pressure test casing to 200 psi. Clean out cement and float equipment, drilled 20' of new hole to 2935'. Change well over to 9.3 ppg LSND mud. Performed FIT to 16.2 ppg EMW. Drill from 2935' to 3920'. UPCOMING OPERATIONS:CONTINUE DRILLING PRODUCTION HOLE, WIPER TRIP ~ 5600' 03/29/99 D9) MW: 9.3 VISC: 51 PV/YP: 20/24 APIWL: 5.6 TD: 5698' 1778) DRILLING ~ 6310' SUPV:DAVE BURLEY / RICK OVERSTREET Drilled from 3920'-5603' Wiped hole to 2887', back reamed from 3263' to 3451' Drilled from 5603' to 5698' UPCOMING OPERATIONS:PLA/lINED WIPER TRIP ~ 8085' 03/30/99 D10) MW: 9.4 VISC: 48 PV/YP: 18/22 APIWL: 5.8 TD: 8146' 2448) DRILLING FROM 8260' SUPV:DAVE BURLEY / SCOTT REYNOLDS PJSM. Drill from 5698' to 8146' Circulate lo/hi vis sweep. Monitor well, static. Pump dry job. UPCOMING OPERATIONS:DRILL TO TD, WIPER TRIP. 03/31/99 (Dll) MW: 9.6 VISC: 48 PV/YP: 21/22 APIWL: 4.8 TD: 9727'(1581) SLIP AND CUT DRILLING LINE, NO PROBLEMS ON WIPER TRIP TO SHO SUPV:DAVE BURLEY / SCOTT REYNOLDS PJSM. Perform LOT, EMW=12.6 ppg. Drill from 8146'-9727' UPCOMING OPERATIONS:RIH TO 9727' TD, COND MUD, POH LAY DOWN DRILL PIPE AND BHA. Date: 4/21/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 04/01/99 (D12) MW: 9.7 VISC: 49 PV/YP: 20/22 APIWL: 4.6 TD: 9727'( 0) RUN PRODUCTION CASING SUPV:DAVE BURLEY / SCOTT REYNOLDS Monitor well, static. Pump dry job. Pump lo/hi vis sweeps at TD. POOH. UPCOMING OPERATIONS:CEMENT CASING & RUN COMPLETION. 04/02/99 D13) MW: 9.6 VISC: 42 PV/YP: 16/14 APIWL: 6.8 TD: 9727' 0) NU BOPE STACK SUPV:DAVE BURLEY / SCOTT REYNOLDS Run 3.5" casing. Run 5.5" casing. UPCOMING OPERATIONS:LD DP, RUN 3-1/2" COMPLETION. 04/03/99 D14) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 9727' 0) ND BOPE. SUPV:DAVE BURLEY / SCOTT REYNOLDS PJSM. Pump cement. Attempt to fish foreign object out of BOP stack. Unable to fish. ND BOP and retrieve junk. NU BOP. Install packoff and test to 5000 psi. Run 3.5" tubing. UPCOMING OPERATIONS:NU & TEST TREE, RELEASE RIG. 04/04/99 (D15) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 9727'( 0) PREP TO MOVE SUB BASE TO 2M PAD SUPV:DAVE BURLEY / SCOTT REYNOLDS First attempt to test casing no good due to surface equipment leaks. Rig up to isolate surface equipment from casing test. Test 3.5" x 5.5" casing to 3500 psi. Good test. Freeze protect well. ND BOPE. NU tree and test to 250/5000 psi. Release rig ~ 1800 hrs. 4/4/99. UPCOMING OPERATIONS:CONTINUE RIG MOVE TO lC PAD ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '' K1(2L-307(W4-6)) WELL JOB SCOPE JOB NUI~IBER ' " 2L-307 DRILLING SUPPORT-CAPITAL 0410991525.1 DATE DAILY WORK UNIT NUMBER 04/26/99 PERFORATE 8345 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 NOI NO SWS-STEPHENSON ODELL FIELD AFC# CC# Signed ESTIMATE AK9749 35TN2L1 LL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 350 PSI 0 PSI 350 PSI 0 PSII 0 PSI 200 PSI DAILY SUMMARY I 6300'. REQUIRED PUMPING TOOLS DOWNHOLE.[Perf] RAN JEWELRY LOG, PERFORATED 9210'- 9240' MD, 4 SPF, 180 DEG PHASING +/- 90 DEG. HAD TROUBLE GETTING BELOW TIME 08:00 LOG ENTRY SWS ON LOCATION. SAFETY MEETING (RADIOS, SLICK SURFACES). RIG UP FOR PERFORATING. ARM GUN #1, GO TO RADIO SILENCE. 09:15 09:30 PT LUBRICATOR TO 3000 PSI, RIH W/GR/CCL/10' GUN, 2-12" HOLLOW CARRIER, 4 SPF, BIG HOLE CHARGES, 180 DEG PHASE, +/- 90 DEG ORIENATION/ROLLERS. 10:45 TOOLS SETTING DOWN AT 6300'. MAKE MULTIPLE A-I-I-EMPTS AT DIFFERENT SPEEDS TO GET DEEPER, UNSUCCESSFUL, PICK UP EACH TIME IS CLEAN. 11:30 CALL FOR PUMP TRUCK, NONE AVAILABLE. WILL USE UNIT FROM COILED TUBING WORKING ON PAD WHEN RELEASED FROM COIL WORK. 14:00 ATTEMPT TO GO DOWNHOLE AGAIN, WENT BY 6300' SMOOTHLY. RIH TO BOTTOM. 14:50 ON BOTTOM. TIE-IN W/GR TO OPENHOLE LWD. MAKE JEWELRY LOG. 15:25 PARK GUNS AT 9230'- 9240', BLEED TUBING TO 200 PSI. ATTEMPT TO FIRE GUNS, SURFACE INDICATIONS ARE NO SHOTS FIRED, POOH. 16:30 ON SURFACE WITH FIRST RUN, GUNS DID NOT FIRE. DETERMINE PROBLEM IS IN GR MODULE, REMOVE FROM TOOLSTRING. 17:15 RIH W/CCL/10' GUN/ROLLER. 18:00 SETTING DOWN AT 6300'. CAN NOT GET DEEPER AGAIN. LRS PUMP RELEASED FROM CTU, RIG UP TO PUMP DOWN TUBING, TAKE RETURNS FROM 7" TO WELL 2L-305 FLOWLINE. 19:20 PUMP 2 BPM & 1500 PSI DOWN TUBING, RETURNS FROM ANNULUS, TOOLS FALL PAST 6300' WITH NO PROBLEM. 19:50 ON BOTTOM, TIE-IN. PARK GUNS AT 9230'- 9240'. WHP 300 PSI. FIRE GUNS, 2-1/2" HOLLOW CARRIERS, 4 SPF, BH CHARGES, 180 DEG PHASE, +/- 90 DEG ORIENTATION. GOOD SURFACE INDICATION, POOH. TIME LOG ENTRY 21:00 OOH WITH GUNS, ALL SHOTS FIRED. DRILLING MUD STUCK ON TOOLSTRING. 21:30 RIH W/CCL/20' 2-1/2" HC, BHC, 4 SPF, 180 PHASE, +/- 90 ORIENATION/ROLLERS. WHP = 0 PSI. 22:20 ON BOTTOM, NO PROBLEMS THROUGH TIGHT SPOT AT 6300'. TIE-IN, PARK GUNS @ 9210' - 9230'. FIRE GUNS, GOOD SURFACE INDICATION. 22:45 TAG BOTTOM FOR CORRELATED TAG DEPTH. TAG AT 9575' MD REF LWD. BOTTOM CLEAN, NO EXTRA WEIGHT AT PICKUP. POOH. 23:55 OOH WITH RUN #2, ALL SHOTS FIRED. RIG DOWN SWS & LRS. 00:30 RIGGED DOWN, WELL SECURE. WHP = 0 PSI, IA = 0 PSI, OA = 200 PSI. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ,Y K1(2L-307(W4-6)) WELL JOB SCOPE JOB NUMBER 2L-307 DRILLING SUPPORT-CAPITAL 0410991525.1 DATE DAILY WORK UNIT NUMBER 05/04/99 FRACTURE STIMULATION DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 5 YES YES DS-YOAKUM ODELL FIELD AFC# CC# Signed ESTIMATE AK9749 35TN2L1 LL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 75 PSI 0 PSI 680 PSI 300 PSII 200 PSII 420 PSI DAILY SUMMARY IPUMPED FRACTURE TREATMENT, SCREENED OUT W/6.3 PPA ON PERFS, 97331 LBS BEHIND PIPE. LEFT 19749# PROPPANT IN WELLBORE, ALL TREESAVER RUBBERS RECOVERED. [Frac-Refrac] TIME LOG ENTRY 06:00 DS ARRIVE ON LOCATION, RIG UP 08:00 SAFETY MEETING, PRIME PUMPS, PT LINES TO 9500 PSI, SET TREE SAVER. 08:50 PUMP BREAKDOWN, 20# LINEAR GEL, 30 BPM. PRESSURE BROKE BACK AT 8500 PSI TO 5400 PSI. PERFORM SD TEST WS FRICTION =- 1300 PSI @ 20 BPM. ISIP = 848 PSi, FG = 0.6 PSI/FT. 09:10 PUMP 75 BBL 40# XL GEL, 1 PPA SCOUR STAGE, 20 BPM. FLUSH W/128 BBLS 20# LINEAR GEL. PERFORM SD TEST, XS FRICTION = 1000 PSi @ 20 BPM. ISIP = 893 PSI, FG = 0.6 PSI/FT. MONITO FOR CLOSURE, PC = 766 PSI. 09:45 PUMP 300 BBL DATA FRAC, 40# XL GEL, 20 BPM. ISIP = 1011 PSI, FG = 0.63 PSI/FT. PERFORM DECLINE ANLYSIS FOR PAD SIZING, CLOSURE TIME = 11.1 MINUTES, CLOSURE PRESSURE = 842 PSI. SET PAD SIZE AT 425 BBLS. 11:20 PUMP FRAC. 425 BBL PAD, 107 BBL 2 PPA STAGE, 346 BBL 2-5 PPA RAMP STAGE, 316 BBL 5-7 PPA RAMP STAGE, 26 BBL INTO THE 7-9 PPA RAMP STAGE SCREENED OUT WITH 6.3 PPA ON PERFS, 97,331# BEHIND PIPE. 117,125# PUMPED TOTAL, 19,749# LEFT IN WELLBORE. 12:35 FLUSH PUMPS AND SURFACE LINES, RIG DOWN DS. ALL TREESAVER CUPS RECOVERED. 15:00 DS RIGGED DOWN, WELL SECURED. Date 04/26/99 Well Na 2L-307 Service Type ELECTRIC LINE Desc of Work PERFORATE Supervisor ODELL Complet ~ Accident F- Injury I-- Spill I-- Summary Upcc~ing I-- Job Num 0410991525.1 Unit 8345 AFC AK9749 0 Prop 35TN2L1LL Uploaded to Sen Contractor Key Perso SWS-STEPHENSON Successful l-- Initial Tbg Press 350 Initial Int Csg Press 350 Initial Out Csg Press 0 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 200 RAN JEWELRY LOG, PERFORATED 9210' - 9240' MD, 4 SPF, 180 DEG PHASING +/- 90 DEG. HAD TROUBLE GEl-i-lNG BELOW 63 REQUIRED PUMPING TOOLS DOWNHOLE. [Pert] Date printed: 05112/99 at: 15:10:46 Date 05/04/99 Upc°r~ing Well Na 2L-307 Service Type PUMPING Desc of Work FRACTURE STIMULATION Supervisor ODELL Complet [~ Accident I-- Injury ~-- Spill l-- Summary Job Num Unit 0410991525.1 AFC AK9749 0 Prop 35TN2L1LI Uploaded to Sen Contractor Key Perso DS-YOAKUM Successful [~ Initial Tbg Press 75 Initial Int Csg Press 680 Initial Out Csg Press 200 Final Tbg Press 0 Final Iht Csg Press 300 Final Out Csg Press 420 PUMPED FRACTURE TREATMENT, SCREENED OUT W/6.3 PPA ON PERFS, 97331 LBS BEHIND PIPE. LEFT 19749# PROPPANT IN WELLBORE, ALL TREESAVER RUBBERS RECOVERED. [Frac-Refrac] Date printed: 05/12/99 at: 15:11:06 Arco Alaska Inc. Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2L, Slot 2L-307 2L-307 Job No. AKMM90100, Surveyed: 1 April, 1999 SURVEY REPORT 12 April, 1999 OSt6!NAL RECEIVED APR 1 ;5 1999 AlaSt~Oil &Gas Cons. Commission Your Ref: API-501032028400 Surface Coordinates: 5927688.53 N, 4610.05 E (70° 10' 09.5440"N, 153° 59' 21.1582"W) Kelly Bushing: 152.05ft above Mean Sea Level D R I L I-, I N I~ S ~ R V ! C E E~ Survey Ref: svy8475 Sperry-Sun Drilling Services Survey Report for 2L-307 Your Ref: API-501032028400 Job No. AKMM90100, Surveyed: 1 April, 1999 Arco Alaska Inc. Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -152.05 0.00 204.27 0.280 142.350 52,22 204.27 298.05 1.480 107.100 145.99 298.04 386.52 3.470 98.320 234.37 386.42 479,60 4.930 97.960 327.20 479.25 570.90 7.150 94.600 417.99 570.04 660.68 12.520 100.520 506.42 658.47 750.66 15.740 99,680 593.66 745,71 841.65 18.410 99,030 680.63 832.68 930.95 21.000 98,800 764.70 916.75 1020.65 22.520 98.990 848.00 1000.05 1111.06 24.480 99.250 930.91 1082.96 1205.19 26.690 98.580 1015.81 1167.86 1298.60 28.220 97.090 1098.69 1250.74 1393.39 31.440 96.460 1180.91 1332.96 1488.31 34.480 95.840 1260.55 1412.60 1582.49 38.390 96.270 1336.30 1488.35 1673.56 42.870 97.260 1405.40 1557.45 1770.86 46.910 97.940 1474.32 1626.37 1862.86 50.840 98.340 1534.82 1686.87 1958.16 52.480 98.460 1593,93 1745.98 2051.86 51.860 97.900 1651.40 1803.45 2142.74 51.790 97.990 1707.57 1859.62 2236.57 53.350 100.310 1764,60 1916.65 2331.76 53.200 100.870 1821.53 1973.58 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5927688.53 N 4610.05 E 0.40 S 0.30 E 5927688.12 N 4610.33 E 0,93 S 1.60 E 5927687.49 N 4611,59 E 1.66 S 5.34 E 5927686.53 N 4615.27 E 2.62 S 12.09 E 5927685.13 N 4621.95 E 3.62 S 21.64 E 5927683.50 N 4631.41 E 5.84 S 36,79 E 5927680.29 N 4646.38 E 9.68 S 58,42 E 5927675.05 N 4667.71 E 14,01 S 84.78 E 5927669.00 N 4693.73 E 18.67 S 114.52 E 5927662.40 N 4723.10 E 23,81S 147.37 E 5927655.12 N 4755.55 E 29.53 S 182.97 E 5927647,09 N 4790.69 E 35.82 S 223,12 E 5927638.18 N 4830.35 E 41.68 S 265.79 E 5927629.54 N 4872.54 E 47.23 S 312.60 E 5927620.94 N 4918,89 E 52.75 S 363.94 E 5927612.07 N 4969.76 E 58.65 S 419.55 E 5927602.54 N 5024.86 E 65,66 S 478.42 E 5927591.69 N 5083.15 E 74.76 S 546.47 E 5927578.16 N 5150.46 E 84.57 S 615.06 E 5927563.88 N 5218.25 E 95.49 S 689.00 E 5927548.14 N 5291.32 E 106.02 S 762.26 E 5927532.83 N 5363.73 E 115.90 S 833.01 E 5927518.35 N 5433.69 E 127.76 S 906.56 E 5927501.70 N 5506,30 E 141.78 S 981.56 E 5927482.80 N 5580.22 E Alaska State Plane Zone 4 Kuparuk 2L Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.00 0.137 O.43 1.345 1.84 2.283 5.57 1.569 12.16 2.461 21.35 6.079 36.18 3.586 57.60 2.942 83.58 2.902 112,81 1.696 145.09 2.171 180.11 2.368 219.57 1.795 261.17 3.413 306.48 3.222 355.94 4.160 409.50 4.970 466.48 4.181 532.74 4.284 599.77 1.724 672.17 0.813 743.78 0,110 812,84 2.573 885.24 0,497 959.81 Continued... 12 April, 1999 - 11:05 - 2 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2L-307 Your Ref: API-501032028400 Job No. AKMM90100, Surveyed: 1 April, 1999 Arco Alaska Inc. Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2423.24 52.760 100.100 1876.61 2028.66 2520.85 53.950 98.790 1934.87 2086.92 2613.81 55.600 100.810 1988.49 2140.54 2708.33 55.540 99.860 2041.93 2193.98 2801.65 54.960 101.060 2095.12 2247.17 2840.83 54.700 101.210 2117.69 2269.74 2954.64 53.530 101.510 2184.40 2336.45 3003.76 53.150 101.720 2213.73 2365.78 3095.88 55.310 100.420 2267.57 2419.62 3190.58 56.370 97.070 2320.76 2472.81 3286.14 56.320 96.950 2373.71 2525.76 3378.40 56.070 96.770 2425.05 2577.10 3471.68 55.860 98.310 2477.26 2629.31 3566.08 55.810 98.000 2530.27 2682.32 3659.64 56.100 98.200 2582.65 2734.70 3755.01 56.590 96.270 2635.50 2787.55 3848.22 55.000 97.430 2687.90 2839.95 3943.66 56.000 96.450 2741.96 2894.01 4036.89 55.320 94.810 2794.55 2946.60 4130.87 53.470 97.170 2849.27 3001.32 4224.22 53.690 98.010 2904.69 3056.74 4319.04 54.220 94.990 2960.50 3112.55 4412.78 52.420 97.820 3016.50 3168.55 4506~29 52.800 96.360 3073.28 3225.33 4598.66 52.530 96.130 3129.30 3281.35 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) 155.08 S 1053.38 E 5927464.83 N 5651.02 E 167.92 S 1130.63 E 5927446.96 N 5727.26 E 180.86 S 1205.45 E 5927429.15 N 5801.07 E 194.84 S 1282.14 E 5927410.17 N 5876,69 E 208.76 S 1357.54 E 5927391.35 N 5951,02 E 214,95 S 1388.97 E 5927383.12 N 5981.97 E 233.11S 1479,37 E 5927359.08 N 6070.99 E 241.04 S 1517.97 E 5927348.64 N 6108.98 E 255.38 S 1591.31 E 5927329.53 N 6181,23 E 267.28 S 1668.75 E 5927312.59 N 6257.72 E 276.98 S 1747.70 E 5927297.73 N 6335.87 E 286,14 S 1823.81 E 5927283.61 N 6411.22 E 296.28 S 1900.44 E 5927268.48 N 6487,02 E 307.36 S 1977.76 E 5927252.36 N 6563.44 E 318.28 S 2054.51E 5927236.44 N 6639.32 E 328.28 S 2133.25 E 5927221.31 N 6717.24 E 337.46 S 2209.79 E 5927207.13 N 6793.01 E 346,96 S 2287.86 E 5927192.54 N 6870.29 E 354.52 S 2364.47 E 5927179.99 N 6946.24 E 362.47 S 2440.45 E 5927167.08 N 7021,54 E 372.40 S 2514.91 E 5927152.30 N 7095.19 E 381.07 S 2591.07 E 5927138.67 N 7170.62 E 389.43 S 2665,76 E 5927125.43 N 7244.60 E 398.60 S 2739.49 E 5927111.46 N 7317.57 E 406.59 S 2812.50 E 5927098.70 N 7389.90 E Alaska State Plane Zone 4 Kuparuk 2L Dogleg Vertical Rate Section (°ll00ft) (ft) Comment 0.826 1031.16 1.627 1107.36 2.510 1181.34 0.831 1257.47 1.226 1332.37 0.734 1363.73 1,050 1454.11 0.846 1492.76 2.609 1565.94 3.134 1641.93 0.117 1718.47 0.316 1792.19 1.387 1866.76 0,277 1942.33 0.357 2017.32 1.761 2093.78 1.992 2167.90 1.347 2243.55 1.625 2317.10 2.836 2390.23 0.761 2462.71 2.635 2536.28 3.090 2608.38 1.305 2679.90 0,353 2750.30 Continued... 12 April, 1999 - 11:05 - 3 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2L-307 Your Ref: API-501032028400 Job No. AKMM90100, Surveyed: 1 April, 1999 Arco Alaska Inc. Prudhoe Bay Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4694.73 52.550 95.720 3187.73 3339.78 4789.49 54.280 99.030 3244.22 3396.27 4881.64 55.410 100.620 3297.28 3449.33 4976.12 55,670 100.630 3350.74 3502.79 5067,64 56.270 98.530 3401.96 3554.01 5161.91 55.090 100.370 3455.11 3607.16 5255.88 55.580 99.640 3508.56 3660.61 5349.23 55,780 102.940 3561.20 3713.25 5442.12 56.230 105.710 3613.15 3765.20 5534.55 57.450 107.990 3663.71 3815.76 5628.89 57.940 110.220 3714.13 3866.18 5723.38 58.420 112.890 3763.96 3916.01 5816.79 59.480 115.710 3812.14 3964.19 5910,47 60.920 119.730 3858.71 4010.76 6005.31 62.160 122.370 3903.91 4055.96 6101.38 63,170 125.120 3948.03 4100.08 6193.79 64,220 130.000 3989.00 4141.05 6291.22 67.820 132.390 4028.60 4180.65 6382.28 66.490 131.590 4063,95 4216.00 6476.65 66.370 131.420 4101.69 4253.74 6571,10 65.230 131.400 4140,40 4292.45 6666.31 65.160 131.960 4180.35 4332.40 6762,61 66.060 131.800 4220.11 4372.16 6856.58 66.290 132.710 4258.07 4410.12 6952.01 65.220 131.920 4297.26 4449.31 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 414.46 S 2888.35 E 5927085.88 N 7465.07 E 424.25 S 2963,78 E 5927071.18 N 7539.70 E 437.11S 3038.01E 5927053.48 N 7612.93 E 451.47 S 3114.58 E 5927034.14 N 7688.39 E 464.09 S 3189.36 E 5927016.65 N 7762.19 E 476.86 S 3266.16 E 5926998.88 N 7837.99 E 490.29 S 3342.27 E 5926980.50 N 7913.06 E 505.38 S 3417.86 E 5926960.49 N 7987.49 E 524.44 S 3492.46 E 5926936.59 N 8060.69 E 546.88 S 3566.51E 5926909.36 N 8133.11E 572.98 S 3641.84 E 5926878.38 N 8206.58 E 602.47 S 3716,51 E 5926844.06 N 8279,15 E 635.41 S 3789,42 E 5926806.42 N 8349,75 E 673.23 S 3861.35 E 5926763.98 N 8419.05 E 716.24 S 3932.77 E 5926716.38 N 8487.50 E 763.65 S 4003.72 E 5926664.43 N 8555.19 E 814.14 S 4069,35 E 5926609.76 N 8617.38 E 872.77 S 4136,30 E 5926546,86 N 8680.34 E 928.91 S 4198.67 E 5926486.76 N 8738.90 E 986.23 S 4263.44 E 5926425.32 N 8799,79 E 1043.21 S 4328.06 E 5926364.23 N 8860.53 E 1100,68 S 4392.60 E 5926302.66 N 8921.18 E 1159.23 S 4457.90 E 5926239.96 N 8982,51E 1217.04 S 4521.53 E 5926178.12 N 9042.21 E 1275,61S 4585.87 E 5926115.45 N 9102.58 E Alaska State Plane Zone 4 Kuparuk 2L Dogleg Vertical Rate Section (°/100ft) (fi) Comment 0.339 2823.27 3.346 2896.61 1.869 2970.02 0.275 3046.17 2.011 3120.00 2,041 3195.74 0.825 3271.11 2.927 3346.64 2.519 3422.80 2.451 3499.76 2.064 3579.32 2.454 3659.58 2,824 3739.56 4.028 3820.53 2.774 3903.03 2.752 3986.80 4.868 4066.87 4.321 4151.31 1.670 4230.56 0.208 4312.49 1.207 4394.14 0.539 4475.91 0.947 4558.80 0,919 4639.85 1.352 4721.86 Cont/nued. . . 12 April, 1999 - 11:05 - 4 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2L-307 Your Ref: API-501032028400 Job No. AKMM90100, Surveyed: 1 April, 1999 Arco Alaska Inc. Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 7046.72 65.150 130.380 4337.01 4489.06 7139.27 65.240 130.050 4375.84 4527.89 7233.37 65.960 130.520 4414.71 4566.76 7325.28 66.680 130.510 4451.63 4603.68 7418.91 65.170 130.640 4489.82 4641.87 7514.92 64.950 133.090 4530.31 4682.36 7610.26 65.710 132,650 4570.10 4722.15 7704.94 65.920 132.090 4608.89 4760.94 7798.59 66.430 132.670 4646.72 4798.77 7891.98 66.550 132.020 4683.98 4836.03 7984.75 66.530 131.680 4720.91 4872.96 8075.87 66.600 131.310 4757.15 4909.20 8169.23 66.740 131.680 4794.12 4946.17 8263.22 66.890 130.670 4831.13 4983.18 8357.59 65.530 128.780 4869.19 5021.24 8454.50 62.990 130.440 4911.28 5063.33 8548.03 61.860 131.930 4954.58 5106.63 8643.86 59.410 133.490 5001.57 5153.62 8738.54 56.160 132.960 5052.04 5204.09 8832.38 54.490 131.830 5105.42 5257.47 8926.71 54.830 130.910 5159.99 5312.04 9020.41 54.740 133.680 5214.03 5366.08 9115.40 55.190 131.370 5268.56 5420.61 9209.43 55.620 132.460 5321.95 5474.00 9302.38 55.320 132.480 5374.64 5526.69 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1332.18 S 4650.60 E 5926054.77 N 9163.46 E 1386.42 S 4714,75 E 5925996.45 N 9223,93 E 1441.83 S 4780.12 E 5925936.88 N 9285.53 E 1496.51S 4844.11E 5925878.12 N 9345.81E 1552.12 S 4909.04 E 5925818.39 N 9406,96 E 1610.21S 4973.87 E 5925756.18 N 9467.84 E 1669.15 S 5037.36 E 5925693.21 N 9527.34 E 1727.36 S 5101.17 E 5925630.95 N 9587.21E 1785.10 S 5164,46 E 5925569.19 N 9646.57 E 1842.78 S 5227.75 E 5925507.48 N 9705.96 E 1899.56 S 5291.14 E 5925446.68 N 9765.49 E 1954.95 S 5353.76 E 5925387.30 N 9824.35 E 2011.75 $ 5417.97 E 5925326.42 N 9884.71 E 2068.63 S 5483.00 E 5925265.41N 9945.88 E 2123.82 S 5549.41E 5925205.99 N 10008.53 E 2179.46 S 5616.66 E 5925146.07 N 10071,99 E 2234.05 S 5679.05 E 5925087.52 N 10130,68 E 2290.68 S 5740.42 E 5925026.99 N 10188.21E 2345.54 S 5798.78 E 5924968,43 N 10242.85 E 2397.57 S 5855.77 E 5924912,78 N 10296,31 E 2448.43 S 5913,51 E 5924858.25 N 10350.60 E 2499.93 S 5970,13 E 5924803.15 N 10403.72 E 2552.49 S 6027.45 E 5924746.95 N 10457.48 E 2604.20 S 6085.04 E 5924691.58 N 10511.57 E 2655.91S 6141.53 E 5924636.29 N 10564.54 E Alaska State Plane Zone 4 Kuparuk 2L Dogleg Vertical Rate Section (°/100ft) (ft) Comment 1.478 4803.45 0.338 4883.61 0.890 4965.35 0.783 5045.53 1.618 5126.93 2.325 5209.20 0.901 5290.58 0.583 5371.96 0.786 5452.68 0.651 5533.38 0.337 5613.82 0.380 5693.01 0.394 5774.22 1.001 5856.21 2.331 5938.81 3.041 6022.37 1.858 6101.04 2.924 6179.56 3.465 6254.61 2.037 6327.31 0.873 6400.25 2.417 6472.40 2.047 6545.61 1.058 6618.74 0.323 6690.85 Continued... 12 April, 1999 - 11:05 - 5 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2L-307 Your Ref: API-501032028400 Job No. AKMM90100, Surveyed: 1 April, 1999 Arco Alaska Inc. Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 9397.81 55.680 131.350 5428.69 5580.74 2708.44 S 6200.05 E 5924580.03 N 10619.50 E 9491.09 55.700 131.880 5481.27 5633.32 2759.61 S 6257.65 E 5924525.20 N 10673.63 E 9584.58 55.780 131.650 5533.90 5685.95 2811.08 S 6315.29 E 5924470.07 N 10727.77 E 9659.20 56.250 131,910 5575.61 5727.66 2852.30 S 6361,43 E 5924425.92 N 10771.11 E 9727.00 56.250 131.910 5613,28 5765.33 2889,96 S 6403.38 E 5924385.60 N 10810.51 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 24.353° (12-Apr-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 112.800° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9727.00ft., The Bottom Hole Displacement is 7025.32ft., in the Direction of 114.290° (True). Alaska State Plane Zone 4 Kuparuk 2L Dogleg Rate (°/100ft) Vertical Section (ft) Comment 1.046 0.470 0.221 0.693 0.00o 6765.16 6838.09 6911.17 6969.68 7022.94 PROJECTED SURVEY Continued... 12April, 1999-11:05 -6- DrillQueet Sperry-Sun Drilling Services Survey Report for 2L-307 Your Ref: API-501032028400 Job No. AKMM90100, Surveyed: 1 April, 1999 Arco Alaska Inc. Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2L Comments Measured Depth (ft) 9727.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5765.33 2889.96 S 6403.38 E Comment PROJECTED SURVEY 12 April, 1999 - 11:05 - 7 - DrlllQuest ri Ft I I_1_1 ~ G SEE I::t ~J I I-- ~ S 12-Apr-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2L-307 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 9,727.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, ./ William T. Allen Survey Manager Attachment(s) APR 1,3 1999 Oil & GasCons. Commission 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. Tarn Drill Site 2L 307 slot #307 Tarn Development Field North S1 ope, ~A1 aska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 307 Version #7a Our ref : prop3233 License : Date printed : 9-Mar-99 Date created : 2-Dec-98 Last revised : 9-Mar,99 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is n70 12 48.206,w150 18 50.890 Slot Grid coordinates are N 5927688.555 E 461048.882 Slot local coordinates are 156.15 S 601.99 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath Last revised 329A PMSS <2506 - 6190'),,329A,Tarn Drill Site 16-Nov-98 PMSS <0-11140>,,313,Tarn Drill Site 2L 15-Dec-98 PMSS <0-9210'>,,305,Tarn Drill Site 2L 15-Dec-98 PMSS <0-9200'>,,325,Tarn Drill Site 2L 19-Nov-98 315 PMSS <0-8236'>,,315,Tarn Drill Site 2L 29-Dec-98 323 PMSS <0-10400'>,,323,Tarn Drill Site 2L 29-Dec-98 PMSS <0-12403'>,,321,Tarn Drill Site 2L 11-Jan-99 Closest approach with 3-D Minimum Distance method Distance 328.8 89.9 15.5 270.1 120.5 239.5 208.9 M.D. Diverging from M.D. 322.2 322.2 200.0 8726.7 611.1 7060.0 100.0 100.0 0.0 8337.5 300.0 9738.6 311.1 8450.0 ARCO Alaska, Inc. Diverter SChematic Pool #6 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline ~ 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi wP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator El 1 F- / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP 3-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3'; 5,000 psi wP Shaffer GATE VALVE rd w/hydraulic actuator ;_~~ CHOKE LINE - 13-5/8" 5,000 psi WP DRILLING SPOOL L]i ~ wi two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, I HYDRIL MPL BOP wi pipe rams TON Y KNO WLE$, GO VEFINOFI ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 21, 1998 Paul Mazzolini Tam Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Kuparuk River Unit 2L-307 ARCO Alaska, Inc. Permit No: 98-256 Sur Loc: 156'FNL, 602'FEL, Sec. 22, T10N, R7E, UM Btmhole Loc. 2260'FSL, 525'FWL, Sec. 24, T10N, R7E, UM Dear Mr. Mazzolini: Enclosed is thc approved application for permit to drill thc above rcfcrenccd well. Annular disposal of drilling wastcs will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integri~' Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2L must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given m field inspector on the North Slope pager at 659-3607. David~/~ Jolfffston \ ' ~ Commiss~ BY ORDER OF THE COMMISSION dlf/Enclosures CC; Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conscn,ation w/o cncl. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 ~.d60 December 17, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re' Application for Permit to Drill KRU 2L-307 Surface Location: 156' FNL 602' FEL Sec 22 T10N R7E, UM Target Location: 2586' FSL, 155' FWL Sec. 24, T10N, R7E, UM Bottom Hole Location: 2260' FSL, 525' FWL Sec. 24, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application fOr Permit to Drill a development well in the Tarn area, KRU 2L-307, located approximately six miles southwest of the Kuparuk River'Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2L (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H~S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H~S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany David W. Johnstr'- Application for F... _nit to Drill Page 2 KRU 2L-307 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in Our Anchorage office, Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2L-307 Well File STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM'i~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 117' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380051 ,~LK 4599 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 156' FNL, 602' FEL, Sec.22, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2586' FSL, 155' FWL, Sec. 24, T10N, RTE, UM 2L-307 #U-630610 At total depth 9. Approximate spud date Amount 2260' FSL, 525' FWL, Sec. 24, T10N, R7E, UM 12/23/98 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) propertylineI 2L-305 9736' MD 155' @ Target feet 15.8' @ 611' feet 2560 5780' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 65.99° Maximum surface 1357 psig At total depth (TVD) 1610 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 2865' 28' 28' 2893' 2300' 330 Sx Arcticset III & 235 Sx Class G 6.75" 5.5" 15.5# L-80 LTC-M 8742' 28' 28' 8770' 5226' 300 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 966' 8770' 5226' 9736' 5780' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk(measured) 0 R I G ! I~.IA L true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor i"? i'~ ~"--' !.,. ii ~ ,¢ ~',; Intermediate Production Perforation depth: measured true vertical :.~ j.~._,,;¢.: . 20. Attachments Filing fee X Property plat ~ BOP Sketch X /~;'~Di~,~i't~¢~Sketch X Drilling program X Drilling fluid program X Time vs depth plot E~ Refraction analysis E~ Seabed report [~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~"~O..,~ ~"]~ Title Tarn Team Leader Date Commission Use Only Permit Number I APl number I Appr°val date/d;;~ ~'~'~/-- ~~-~ ~ ~:>- ,¢.~ ~'f.¢ 50-1,0~ ~.~'~.~ See cover letter for -- other requirements Conditions of approval Samples required F' Yes ~ No Mud logrequired ~,i Yes ,~ No Hydrogen sulfidemeasures E~ Yes ~. No Directional surveyrequired .~ Yes ~ No Required working pressure for BOPE ~,~ 2M E~ 3M r- 5M F, 10M ~ 15M Other: by order of Approved by F~ri.i.,~--, i r~;~,..~., ~ F,, Commissioner the commission Date Form 10-401 Rev. 7-24-89 gl,lal u,y,,~d Uy i)avid W. ,Johnston Submit in triplicate ARCO Alaska, Inc. GENERAL-'~RILLING AND COMPLETION PR~EDURE KUPARUK RIVER FIELD - PRODUCER KRU 2L 3O7 1. Move in and rig up Doyon 141. 2. Install divertersystem. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. , Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing _+!000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. . Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 7. Drill 6.75" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, su--Effi-6ient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). o Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. ]2. Secure well. Rig down and move out. :13. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. DRILLING'¥~LUlD PROGRAM, PRESSURE CA'~CULATIONS, AND DRILLING AREA RISKS Well KRU 2L-307 Drilling Fluid Properties' Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 4-10% Drill out to TD 8.5- 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Arete & Tarn 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70-0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be ,,-2,350 psi (0.50 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. Well Proximity Risks: The nearest well to 2L-307 is 2L-305. The wells are 15.8' from each other at a depth of 611' Drilling Area Risks' ARCO Alaska, Inc. The primary risk in the 2L-307 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8- 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-307 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-307 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling-plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe -I-VD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,100') + 1,500 psi Max Pressure = 2,810 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf)Grade Range Type Collapse Collapse Burst Burst 7-5/8"29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5½" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000Psi 5,950 psi 3½" 9.3I L-80 I'" '2 ARCO Alaska, Inc. Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ARCO Alaska, Inc. Diverter Schematic Doyon 141 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at $0' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS L, J b J 1 F- I I 3" 5,000 psi WP OCT MANUAL GATE VALVE~ ~'--J KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator Fi · J / BSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple D~I~ .0EP~-,'/§h.~. ~.(~¢sEi~,vE w/pipe rams on top and blind rams on bottom / ] 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator ~_~~ CHOKE LINE 13-5/8" 5,000 psi WP DRILLING SPOOL L_I ~ w/two 3" 5M psi WP outlets I~SiNGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams Created by f~nch For: LLOYD Dote plotted: 9-Mar-1999 Plot Ref~'ence ;I 507 Ver~o~ 1~7o. Coord;notea ore in feet r~lre~'lcl I~lOt 1~,.~07. True Vlr[iCOI Depiha ore r~lnce RKB (~ ~6). ARco Alaska, Inc. Structure : Tarn Drill Site 2L Well : 507 Fl®Id -' Torn Development Fleld Loooflon : Nor'th Slope, East (feet) -> 500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 i I I I I I I I I I I I I I I I I I I I I I I I I I I I I I SURFACE LOCATION: I ' ~ Az 0 I 157' FNL. 602' FEL 5:0]t ISEC' 22' TION' RTE I ..~~~ ~ V s.oo DES: 3.oo deg per 100 ft lO00J k21'00 Port Collar ' 112 ~27.00 Base Permafrost ~~ ~33 O0 Top West Sak VO~ ~soo~ X30-oo ...p~.~ of Pr ~000 X4s'°° ~51.00 End of Build ~ Base West Sak 2000~ ~ . . ~ qq ~ 2500 ~ · ~ ~ s/a Casing ' ~ c~o ~ooo ~ 55 DEC ' . ,0'% . ' C50 D~ SEC 24 TION RTE C50 ~~8.82 DLS: 5.00 deg per 100 ft I ' ' ' 4000 ~ . ~ne~ 62.27 . . 5000 60 DLS: 2.00 deg per 100 fi 5~00~ q . TD - Casing Pt I 6000 i 0 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 65~ 7000 7500 Vertical Section (feet)-> Azimuth 112.~0 with roforence 0.00 N, 0.00 E fromslot ~507 Crsoted by finch For: LLOYD Dote plotted : g-Mot-II99 Plo[ Reference ie 507 Version ~7a. Coordlnotee ore tn feel reference elot ~307. True Vertical Depths are r~erence RKB (Pool ~6). I~EQ [ARCO Alaska, ,ne. Sfrucfure: Torn Drill Sire 2L WoII: Fleld: Torn Development Field Looatlon : Nodh Slope, Alasko Point KOP Port Collar Base Permafrost Top West Sak End of Build Base West Sak 7 5/8 Casing Pt C80 Camp sst Begin Turn f.o TargetSgr C50 EOC C40 Begin Angle Drop End Angle Drop T5 - Top Bermuda Target - Mid Bermuda$ST T2 - Base Bermuda C55 TD - Casinq Pt PR MD 300.00 1016.70 1239.43 1289.70 2133.33 2216.21 2892.67 3241.35 3342.47 5233.33 5536.76 6261.05 '-~407.67 8244.89 8780.11 8980.11 9138.76 "9297.42 9438.64 9738.64 OFILE Inc 0.00 21.50 28.18 29.69 55.00 55.00 55.00 55.00 55.00 55.00 57.25 65.70 65.70 '65.70 55.00 55.00 55.00 55.00 55.00 55.00 COMMENT DATA Dir TVD North 98.00 300.00 0.00 98.00 1000.00 -18.50 98.00 1202.00 -31.51 98.00 1246.00 -34.90 98.00 1864.47 - 113.34 98.00 1912.00 -122.79 98.00 2300.00 -199.91 98.00 2500.00 -239.66 98.00 2558.00 -251.19 98.00 3642.55 -466.76 08.63 3812.00 -524.94 31.29 4160.67 -844.66 31.29 4221.00 -952.85 31129 4976.91 -2057..83 ._ 51.29 5241.28 -2544.32 51.29 5556.00 -2452.42 31.29 5447.00 -2538.18 51.29 5558.00 -2625.95 31.29 5619.00 -2700.27 51.29 5791.07 -2862.45 East 0.00 131.61 224 22 248 51 806 48 873 71 1422 44 17O5 29 1787 31 3321 14 5565.64 4108.35 4208.76 5466.95 5815.95 5939.03 6036.68 6154.55 6221.25 6405.91 V. Sect 0 O0 128 49 21891 242 42 787 37 853 01 1 388 73 1 664 88 1 744 96 3242 44 5490 57 4114.59 4241.33 5829.45 6269.94' 6425.32 6548.58 6671.83' 6781.55 7014.62 Deg/! ~1 O.=c 3.00 3.00 3.00 3.00~ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 0.00 0.00 0.00 0.00 0.00 ARCO Alaska,, Inc.I · i' c,,o~,~ ~y .,,~, For: LLOYD [ 9-Uor-1~9 I ..?. . .. ,. ~ot ~fmrsnce [s ~7 Vernon ~70. J ]~ : Tam ~lopment ~ld L~allon Nogh Slope, A~ka ' ' ~l~tm ~ in feet mf~n~ e~ol t~7. [ I :'?'' :" :~ .... '-" East (feet) -> 60 40 20 0 20 40 60 80 1'00 120 140 160 180 200 220 240 260 280 500 520 540 .t60 [ I I I I I ! I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 60 ,,,/~oo /1000 '/'/7/0'~ 40 / 900 / 600 /800 5oo. 0 9 ~j 0._0 _ 600 700 9 e_lOO -' ~ - ... 800 --- ~ ~ ~ ~-- ~ ~ 900 '" --- ...900 ~ 11 O0 '--.~oo "- -.-, ~ooo ..... 12oo 40 ~ ~. "' "' --- 1200 1100 ~ '- 800 . ----.. ~ ~ ~ ~ 1400 ~ "- ... '" ~ 1300 6o ~ 1200 ~ "' ~ 900 ' "- -" '-' '-' --- 00 1500 '-- '-.. '~ '"' --- ~._14~00 80 x x ~..1000 "" "-- .-.. 1...500 14oo ~ -.. '-'---... ~oo ~ ~''.. '--- -._,6....o0 '"" ' 0 , % "% '~' 'o''' ~o' 'o' ; ' do ............. ~ ' ' ' ~ ' ~ ........ 60' 4 2 0 2 4 6 100 120 140 160 180 200 2 0 240 2 0 2 0 ;500 520 540 560 East (feet) -> I V 80 6o , 40 2o (J) 0 40 60 1 O0 120 140 16O 180 580 c~o~e~ ~ f;.c. For: LLOYD Do~e ~oited: 9-Mcr-1999 Plot Reference /I .]07 Vlrlion J~7O. Coord;note~ o~e ;n felt. referencl elot DUI Vlrt;CQI Dlpthl ore rlflrlncl RKO (P<2ol ARCO Alaska, Inc.I Structure: Tarn DHII Slfe 2/ Well: 307 IFl~ld : Tarn Dlvilopment fi.id Lo¢atTon : North Slop.. &laskaI 400 300 200 lOO 100 200 300 V 400 500 600 700 800 900 East (feet) -> 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 I I I I t I I I I I I I I 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 8OO 1600 1700 1800 1900 2000 2100 1400-- ,-- __ __ ~__ 2200 -+ -- _ 2300 ~'9~-~ --' ~-000 31 O0 32 O0 5300 3400 '~3-~0~' 3600 3700 -'~' -- ~- 240'"0 ..... 2500 3800 3900 4000 4100 4200 4300 ~ ~ 4400 2600 ~ "-'~ ~ --,- L4001500 1600 · ----e ~ ~ ._. 1700 .1 ~ ~ ~ ~ 1800 6OO 1 900 -- .,. 1700 '"-' ~ ~ ~ 2000 "' ---o.~1800 ~ ~ ~ ---. ~ ~ 21 O0 1 "' ~ ~ ~ ~ ~ 2400 "~'"'-~900.1400 '" '" '-- -.,2100 ~ ~" ~ ~ ~ ~ 2600 -1,'~ "~-2000 -- ._ ~ ~ ~ --- ~ 2700 2900 %0: ,% '~. ---. 22 '~-. 7' 13oo -..~6o__o_. ,/J~. ~ '~ ~ ~" ... -" '- .-, 2700 . - O ,oo - . '-- .. 29...00 1900 . I I I I I I I I I [ I [ i i i i ! i i i ! ! ! i i i i i i i i i i i i i i i i i [ i i 300 400 500 600 700 800 gO0 1000 1100 1200 1300 1400 . 1500 1600 1700 1800 1 go0 2000 21 O0 2200 2300 2400 East (feet) -> 4OO 300/'" {~ 200 1 oo 1 oo 0 ¢- 200 300 400 ; ~ 5OO 600 70O 800 goo ICreotecl by f;nch For: ~.~OY'~ I ~t. ~ott~: g-~r-lggg J PlOt ~ference ;I ~7 ~lr~fon ~7o. I ~rd~t~ ~ ;n feet. mfemn~ ~lot ~7. ~ Tr~ Vlrt;~l ~pth. afl mflrincl RKB (~1 ~6~1 . . 100 1 O0 200 300 400 500 East (feet) -> 2200 2300 2400 2500 2800 2700 2800 2900 3000 51 O0 5200 3300 3400 3500 3600 3700 ;5800 ;5900 4000 4100 4200 4500 4400 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~-. 4...400 4500 ~ 4700 ~ 4800 --~5000 31 O0 ~ ,4900 ~ ~ ~ ~ 3200 3300 ~ 5000 3100 2900 3000 ~ e-... "' '~o...39 O0 3200 3100 4100 3800 3300 0 600 I V 700 800 900 1000 1100 ~....29._oo 3400 ~, 5100 I I / 32o0~ ? ~ ~ ~ 52oo. ~- ~oo ! / / / / / 3500 e...- 5600 -~ ~ ~ 3700 '" '-- ,..3800 ....4000 %4200 430C2%% I ~-.. "-" ~ 3900 1200 I 1 O0 100 200 2200 2300 2400 2500 2600 2700 2800 2900 3000 . 3100 3200 3300 3400 3500 ;5600 3700 3800 ;5900 4000 4100 4200 4300 4400 East (feet) -> 300 400 o -,4- 500 600 -4. 800 1000 1100 1200 Creot~cl ~ frn=h For: LLOYD Date ptoUud: 9-Mar-1999 Plot ~flrlKI M ~7 VerlFon 170. ~rd~ot~ ~ ;n feet ~er~ Tr~ Vlrt;~l Olpthl orb qflrlncl R~8 (~ ~6). ARCO Alaska, Inc. Struefurm: Tarn Drill Site 2L Well: 507 r'll d : Torn Deve opmenl Fleld Location : Norih $ ode, Alaska East (feet) -> 2800 5000 3200 3400 3600 .5800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 GO00 6200 6400 6600 6800 7000 7200 400 I I I I I I I I I I I I I i I I ¢ ) I I I I I I I I I I I I I I I I I I I I I I I I I 400 ~ ~ ~ 4300 600 ~ N. 41 O0 ~ 5~00 800 ~ ~3300 1 ooo ' ' ~ 3900 ~ ~5500 1200 ~ ~ .... ~ ~_ ~4100 . ~ ~~ 4300 xX ~ ~ ~-' ~ ~ ~ ~ ' 4500 ~ ' ' ~ ~ ........ ' ...... Sloo , ,oOol 1 2900~~ %4900 2000i 2200 ~ 310"'~ %,5100 2200 2%o . . oo ' % ~ %5500 2800' 0 O0 5000 ' ' % 5000 ~200 i m ) m m m m i t m ) i m m m ) ~ m ) m ~ ~ ~ m i ~ m m I ~ i m ~ m ) m m m ~ m m m ~ ~200 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 Eost {feet) 6OO ,," lOOO 1200 1400 0 1600 c" ,m 1800 "~ 2000 ?- C~o~,d Oy finch For: LLOYD Oot~ p4ott~d : 9--Yor--$999 ~ot ~f~n~ ~ ~7 Ve~ ~7o. IT~e V~I~I Dep~e are m~emnce RKB (~1 ~6). ARCO Alaska, Inc. S~ruafure : Tarn Drill $lle 2LWell : 307 Fie d: Tom Development field Leaatlon : Norlh Slope, Alaska 3O 320 310 34O TRUE NORTH 35~,~7oo 0 10 2O 3O 4O 5O 300 6O 290 7O 28O 270 260 500 + 8O 90. 100 250 240 \ 230 \ \ 220 Normal Plane Travelling Cylinder- \%2 \ \ % ,3~00 2.10 2 .0 x 190 \%5500 Fee~ 110 130 180 \ 150 140 ~ ~;o~o 1 60 ~70 \ \ All depths shown ore Meosured depths on Reference Well ,: CO Alaska, Inc. :aruk Unit Disbursement Account Box 102776 :horage, AK 99510-2776 THE )ER OF: ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE CHECK NUMBER 230092306 77-426 839 DECEMBER 2, 1998 0997587 VOID AFTER 90 DAYS *** First National Bank of Chicago-0710 Chicago, Illinois Payable Through Republic Bank Shelbyville, Kentucky EXACTLY ***********100 DOLLARS AND OO CENTS ~**********'100.00 : TRACE NUMBER: 230092306 ,'2500q2~Or~,' ~:Ofi~ON2r=2". · FIELD & POOL WELL PERMIT CHECKLIST WELl_ NAME ¥~,~t,.L, ,~].., - ~"? PROGRAM: exp [] devJ~redrll [] serv [] wellbore seg II ann. disposal para req,,~(' ADMINISTRATION 1. 2. 3 4 5. 6. 7. 8. 9. 10. 11. ,R 'I E 12. ENGINEERING COMPANY L~--~' Cr~ GEOL AREA ~ c/~ UNll"# I ~ t ~._~ .............. ON/OFF SHORE APPR DATE ( ~__.N t N CU ®U Y N ®U INITCLASS ~.~o..v /- C~,'L Pernfi! fee attached ....................... Lease number appropriate ................... Unique well name and number ................ Well Iocaled in a defined pool .................. Well Iocaled proper dislance from drilling unil boundary. . . Well Iocaled proper distance from other wells .......... Sufficient acreage available in drilling unil ............ If deviated, is wellbore plat included ............... Operalor only affected party ................... Operator has appropriate bond in force ............. Permil can be issued wilhoul conservation order ........ Pe[mil can be issued wilhout administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl' vol adequate to circulate on conductor & surf csg ..... 17. CM I' vol adequate to tie-in long string to surf csg ........ 18. CM r will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate...... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~O~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 33.32'31' Data presented °n p°tential °verpressure z°~'9'Q~ ~ Y N Seabed condi~fSeismic analysis of shallow~qAs_z~;mes':~-. ~ .0ff-shore) ............. '" ........ YY NN _~_ _/_,~ ...................... ...... ..................................................................... AIi',~? [)ATE 34. C~eklyprogress reports ....... Y N ANNULAR DISPOSAL 35. Wilt] proper cementing records, this plan .......... (A) will contain waste in a suitable receiving zone; ....... Y N A~-~- ~ g,~ IF-e.~,S ~,x6~,Pre, b l,~ F..I~N,,/::}~ ~ ~ _ APF'R DAlE ([3) will not contaminate freshwater; or cause drilling waste... Y N ._~.l_..N~l~,~b~C':f. ~_A3'"r~ F',~e,,ctTHis._..~:b_~- 1~1' ~ ~!'H~ .~ ?p~c~:) .~e.,~L. 0,,,3 to surface; 7A.-P^~, RF-.~o~,,ST /N f pgov',~ P'-g~ F,,~,z.-~ g~. oF' 7~i~ ~6_~.-z_.. __~.~_.~... .......... )_..z..1]_~) (C) will nol impair mechanical integrity of the well used for disposal; Y N (D) will nol damage producing formation or impair recovery from a Y N ...................................................................................................... .............................. pool; and (E} will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N RPC ~ Mcheldl:;t mv ()5/2919,~{ ENGINEERING: UIC/Annular JDH ~ COMMISSION: RNC <~7'~,/'~"",'""~ co Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not padicularly 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 Wed Sep 08 08:55:46 1999 Reel Header Service name ............. LISTPE Date ..................... 99/09/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/09/08 Origin ................... STS Tape Name ................ UNK/q0WN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific RJCelVE. D Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TAi~N POOL MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM- 90100 M. HANIK D. BURLY 2L-307 501032028400 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 08-SEP-99 22 I0N 007 156 602 .00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 152.10 117.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 118.0 9.875 7.625 2905.0 6.750 9727.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS,ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON (CTN), AND STABILIZED LITHO-DENSITY(SLD). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL FROM D. OF ARCO ALASKA, INC. ON 04/13/99. MWD DATA IS PDC. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9727'MD, 5765'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SH_A_LLOW 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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75" MUD WEIGHT: 9.3 - 9.6 PPG MUD SALINITY: 400-550 PPM CHLORIDES WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/09/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX PEF NCNT FCNT NPHI DRHO RHOB ROP $ Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 STAi~T DEPTH 2850.0 2895 0 2895 0 2895 0 2895 0 2895 0 2900 0 2900 0 2900 0 2900 0 2902 0 2902 0 2905 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 9671 0 9678 0 9678 0 9678 0 9678 0 9678 0 9649 5 9634 0 9634 0 9634 0 9649 5 9649 5 9725 5 EQUIVALENT UNSHIFTED DEPTH .... BIT RUN NO MERGE TOP MERGE BASE 2 2915.0 9727.0 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 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD API 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 NPHI MWD PU-S 4 1 68 RHOB MWD GM/C 4 1 68 DRHO MWD GM/C 4 1 68 PEF MWD BARN 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 0 4 8 12 16 20 24 28 32 36 4O 44 48 52 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name Min Max Mean Nsam DEPT 2850 9725.5 6287.75 13752 GR 44.05 236.61 124.58 13643 RPD 0.49 2000 5.91633 13567 ROP 11.73 2607.44 219.985 13642 FET 0.1231 66.9067 0.771825 13567 RPX 1.01 53.01 4.40853 13567 RPS 1.03 2000 4.8185 13567 RPM 1.08 2000 5.95424 13567 NPHI 13.5 53.42 34.0281 13469 RHOB 1.63 2.95 2.35066 13496 DRHO -0.23 0.74 0.0798155 13496 PEF 1.38 12.05 3.0332 13500 FCNT 125.68 988.38 269.171 13469 NCNT 14143.6 32769.2 19622.5 13469 First Reading 2850 2850 2895 2905 2895 2895 2895 2895 2900 2902 2902 2900 2900 2900 Last Reading 9725.5 9671 9678 9725.5 9678 9678 9678 9678 9634 9649.5 9649.5 9649.5 9634 9634 First Reading For Entire File .......... 2850 Last Reading For Entire File ........... 9725.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/09/08 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 ....... 99/09/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE N-UMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2850.0 FET 2895.0 RPD 2895.0 RPM 2895.0 RPS 2895.0 RPX 2895 0 PEF NCNT FCNT NPHI DRHO RHOB ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 10.87 2900 2900 2900 2900 2902 2902 2905 SURFACE SOFTWARE VERSION: DOWNI~OLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE ~ CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS STOP DEPTH 9671 0 9678 0 9678 0 9678 0 9678 0 9678 0 9649 5 9634 0 9634 0 9634 0 9649 5 9649 5 9725 5 31-MA_R-99 INSITE 3.2. (UPGRADE 3) CIM 5.46,SP4 5.16,SLD MEMORY 9727.0 2915.0 9727.0 52.4 67.8 TOOL NUMBER P1274GR4 P1274GR4 P1274GR4 P1274GR4 6.750 6.8 MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAi~DOFF (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 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LEND -9.60 50.0 9.0 500 5.4 5.000 2. 816 4.500 3.200 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 FET MWD 2 HOUR 4 1 68 24 7 ROP MWD 2 FT/H 4 1 68 28 8 NPHI MWD 2 PU-S 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 GM/C 4 1 68 44 12 DRHO MWD 2 GM/C 4 1 68 48 13 PEF MWD 2 BAR/q 4 1 68 52 14 52.2 First Name Min Max Mean Nsam Reading DEPT 2850 9725.5 6287.75 13752 2850 GR 44.05 236.61 124.58 13643 2850 Last Reading 9725.5 9671 RPX 1.01 53.01 4.40853 13567 RPS 1.03 2000 4.8185 13567 RPM 1.08 2000 5.95424 13567 RPD 0.49 2000 5.91633 13567 FET 0.1231 66.9067 0.771825 13567 ROP 11.73 2607.44 219.985 13642 NPHI 13.5 53.42 34.0281 13469 FCNT 125.68 988.38 269.171 13469 NCNT 14143.6 32769.2 19622.5 13469 RHOB 1.63 2.95 2.35066 13496 DRHO -0.23 0.74 0.0798155 13496 PEF 1.38 12.05 3.0332 13500 2895 2895 2895 2895 2895 2905 2900 2900 2900 2902 2902 2900 9678 9678 9678 9678 9678 9725.5 9634 9634 9634 9649.5 9649.5 9649.5 First Reading For Entire File .......... 2850 Last Reading For Entire File ........... 9725.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/09/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/09/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/09/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File